GE Multilin 745 Instruction Manual Download Page 240

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745

Motor Management Relay

http://www.GEindustrial.com/multilin

GE Multilin

FlexCurve™

................................................................... 5-50

EU DECLARATION OF CONFORMITY

................................... 8-2

EVENT CAUSES

................................................................ 6-15

FACTORY SERVICE

.......................................................... 5-97

FAULT VALUES

................................................................ 5-94

FAX NUMBERS

................................................................... 1-1

FIRMWARE

upgrading via enerVista PQMII setup software

............. 4-21

FLEXCURVES™

equation

....................................................................... 5-50

setpoints

....................................................................... 5-34

FLEXLOGIC™

example

............................................................... 5-87, 5-88

gates

............................................................................ 5-87

input types

................................................................... 5-86

introduction

.................................................................. 5-86

output types

................................................................. 5-86

rules

............................................................................. 5-87

FREQUENCY

commissioning

.............................................................. 7-31

setpoints

....................................................................... 5-66

FREQUENCY DECAY

setpoints

....................................................................... 5-68

testing

.......................................................................... 7-35

FRONT PANEL

.................................................................... 4-1

FRONT PANEL PORT

......................................................... 3-14

GROUND INDICATOR

......................................................... 4-3

GROUND INSTANTANEOUS OVERCURRENT

setpoints

....................................................................... 5-60

testing

................................................................. 7-25, 7-26

GROUND OVERCURRENT SETPOINTS

.............................. 5-59

GROUND TIME OVERCURRENT

setpoints

....................................................................... 5-59

testing

.......................................................................... 7-23

HARDWARE REVISION

..................................................... 6-17

HARMONIC DERATING

correction

..................................................................... 5-55

setpoints

....................................................................... 5-77

testing

.......................................................................... 7-39

HARMONIC INHIBIT

......................................................... 5-44

HARMONICS

........................................................... 5-33, 5-75

HI-POT TESTING

............................................................. 3-15

see DIELECTRIC STRENGTH TESTING

HOTTEST-SPOT LIMIT

setpoints

....................................................................... 5-79

testing

.......................................................................... 7-37

IAC CURVES

constants

...................................................................... 5-53

description

.................................................................... 5-53

trip times

...................................................................... 5-53

IEC CURVES

constants

...................................................................... 5-52

description

.................................................................... 5-52

trip times

...................................................................... 5-52

IED SETUP

......................................................................... 4-9

IEEE CURVES

.................................................................. 5-51

IN SERVICE INDICATOR

.................................................... 4-2

INDICATORS

see LEDs and entries for individual indicators

INPUTS

AC voltage

.....................................................................3-10

commissioning

............................................................... 7-6

specifications

................................................................. 2-4

INSERTION

....................................................................... 3-3

INSPECTION CHECKLIST

................................................... 1-1

INSTALLATION

setpoints

................................................................1-7, 5-2 9

INSTANTANEOUS DIFFERENTIAL

setpoints

.......................................................................5-48

testing

...........................................................................7-17

INSULATION AGING

.........................................................7-37

setpoints

.......................................................................5-78

INVERSE CURVE 1

...........................................................5-73

IRIG-B

.............................................................................3-15

KNEEPOINT

......................................................................7-15

LEDs

alarm

.............................................................................. 4-3

description

..................................................................... 4-2

differential blocked

........................................................ 4-2

ground

........................................................................... 4-3

in logic diagrams

...........................................................5-40

in service

....................................................................... 4-2

load-limit reduced

.......................................................... 4-3

LOCAL

............................................................................ 4-2

message

......................................................................... 4-2

phase A

.......................................................................... 4-3

phase B

.......................................................................... 4-3

phase C

.......................................................................... 4-3

pickup

............................................................................ 4-3

self-test error

................................................................. 4-2

setpoint group 1

............................................................. 4-3

system status

................................................................. 4-3

test mode

....................................................................... 4-2

transformer de-energized

.............................................. 4-3

transformer overload

..................................................... 4-3

trip

................................................................................. 4-3

LOAD-LIMIT REDUCED INDICATOR

................................... 4-3

LOCAL INDICATOR

............................................................ 4-2

LOCAL RESET MODE

........................................................7-12

LOGIC

..............................................................................5-40

LOGIC INPUTS

........................................................ 3-10, 5-3 8

commissioning

............................................................... 7-5

LOSS-OF-LIFE

..................................................................5-78

LOSS-OF-LIFE LIMIT

............................................... 5-81, 7-3 8

MANEUVERING

.................................................................. 1-2

MEASUREMENT UNITS

.....................................................5-40

MESSAGE INDICATOR

....................................................... 4-2

MINIMUM OPERATING CURRENT

......................................7-39

MINIMUM PICKUP

.......................................... 7-12, 7-17 , 7-3 8

NAMEPLATE

....................................................................... 1-1

NEGATIVE SEQUENCE INSTANTANEOUS OVERCURRENT

setpoints

.......................................................................5-66

testing

...........................................................................7-30

NEGATIVE SEQUENCE OVERCURRENT

..............................5-64

NEGATIVE SEQUENCE TIME OVERCURRENT

setpoints

.......................................................................5-65

testing

...........................................................................7-28

NEUTRAL INSTANTANEOUS OVERCURRENT

setpoints

.......................................................................5-58

testing

.................................................................. 7-22, 7-2 3

Summary of Contents for Multilin 745

Page 1: ...ms 814768AH CDR IN SERVICE LOCAL SETPOINT GROUP 2 LOAD LIMIT REDUCED TRIP SELF TEST ERROR SETPOINT GROUP 3 TRANSFORMER DE ENERGIZED ALARM PICKUP TEST MODE TRANSFORMER OVERLOAD SETPOINT GROUP 1 PHASE A PHASE B PHASE C GROUND MESSAGE PROGRAM PORT SETPOINT 7 8 9 4 5 6 1 2 3 0 HELP MESSAGE VALUE ACTUAL ESCAPE ENTER RESET NEXT DIFFERENTIAL BLOCKED 745 STATUS SYSTEM STATUS CONDITIONS SETPOINT GROUP 4 IS...

Page 2: ......

Page 3: ... Using the HELP Key 1 5 Numerical Setpoints 1 5 Enumeration Setpoints 1 5 Text Setpoints 1 6 Security Installation 1 7 Changing the Passcode 1 7 Disabling and Enabling Passcode Security 1 8 OVERVIEW Introduction Description 2 1 Protection Features 2 2 Order Codes 2 3 Specifications Applicability 2 4 Inputs 2 4 Protection Elements 2 5 Outputs 2 6 Miscellaneous 2 7 INSTALLATION Drawout Case Case Des...

Page 4: ...tic Messages 4 6 Flash Messages 4 6 enerVista Software Interface Overview 4 7 Hardware 4 7 Installing the enerVista 745 Setup Software 4 8 Connecting enerVista 745 Setup to the Relay Configuring Serial Communications 4 11 Using the Quick Connect Feature 4 12 Configuring Ethernet Communications 4 13 Connecting to the Relay 4 14 Working with Setpoints and Setpoint Files Engaging a Device 4 15 Enteri...

Page 5: ...ad Tap Changer 5 33 Harmonics 5 33 FlexCurves 5 34 Voltage Input 5 34 Ambient Temperature 5 35 Analog Input 5 36 Demand Metering 5 36 Analog Outputs 1 to 7 5 37 S3 Logic Inputs Description 5 38 Logic Inputs 1 to 16 5 38 Virtual Inputs 1 to 16 5 39 S4 Elements Introduction to Elements 5 39 Setpoint Group 5 41 Differential Element 5 41 Instantaneous Differential 5 48 Phase Overcurrent 5 49 Neutral O...

Page 6: ...Changer 6 10 Voltage 6 10 Demand 6 10 Ambient Temperature 6 11 Loss of Life 6 12 Analog Input 6 12 Power 6 12 Energy 6 12 A3 Event Recorder Event Data Clear 6 13 Event Records 6 14 A4 Product Information Technical Support 6 16 Revision Codes 6 17 Calibration 6 17 Target and Flash Messages Target Messages 6 17 Self Test Errors 6 19 Flash Messages 6 21 COMMISSIONING General Introduction 7 1 Testing ...

Page 7: ...ntaneous Overcurrent 2 7 23 Ground Time Overcurrent 7 23 Ground Instantaneous Overcurrent 1 7 25 Ground Instantaneous Overcurrent 2 7 26 Restricted Ground Fault Polarity Test 7 26 Restricted Ground Fault Element Test 7 27 Negative Sequence Time Overcurrent 7 28 Negative Sequence Instantaneous Overcurrent 7 30 Frequency 7 31 Overexcitation 7 36 Insulation Aging 7 37 Tap Monitor Failure 7 38 Auxilia...

Page 8: ...Table of Contents 745 Generator Management Relay http www GEindustrial com multilin viii GE Multilin ...

Page 9: ...ruction Manual GE enerVista CD includes software and relay documentation mounting screws registration card attached as the last page of the manual Fill out the registration form and mail it back to GE Multilin include the serial number located on the rear nameplate For product information instruction manual updates and the latest software updates please visit the GE Multilin website at http www GE...

Page 10: ... levels are entered by pressing the MESSAGE or ENTER key When inside a submenu the MESSAGE or ESCAPE key returns to the previous sub menu The MESSAGE and MESSAGE keys are used to scroll through the settings in a sub menu The display indicates which keys can be used at any given point Using the Relay Menu Navigation Press the MENU key to access the header of each menu which will be displayed in the...

Page 11: ...st actual values page and then the MESSAGE or MESSAGE key to scroll through pages until the A2 METERING DATA page appears 3 Press the MESSAGE or ENTER key to display the first sub page heading for the Metering Data actual values page Pressing the MESSAGE or MESSAGE keys will scroll the display up and down through the sub page headers Pressing the MESSAGE or ESCAPE key at any sub page heading will ...

Page 12: ...s the following key press sequence 1 Press the MENU key until the setpoints header appears on the display 2 Press MESSAGE or the ENTER key and then MESSAGE key until the S4 ELEMENTS message is displayed 3 Press the MESSAGE or ENTER key to display INSULATION AGING message 4 Press the MESSAGE or ENTER key to display AGING FACTOR LIMIT message 5 Press the MESSAGE or ENTER key to reach the AGING FACTO...

Page 13: ...vailable 1 0 to 9 and the decimal key The relay numeric keypad works the same as that of any electronic calculator A number is entered one digit at a time The left most digit is entered first and the right most digit is entered last Pressing the ESCAPE key before the ENTER key returns the original value to the display 2 VALUE and VALUE The VALUE key increments the displayed value by the step value...

Page 14: ... the use of the decimal ENTER VALUE and ESCAPE keys For example 1 The name for Output Relay 3 should be more descriptive than the default value For this example let us rename output relay as INST DIFF TRIP Press the decimal key and an underscore _ will appear at the first character position 2 Press VALUE keys until the character I is displayed in the first position then press the decimal key to st...

Page 15: ...d SETPOINT ACCESS Read Only or passcode security is disabled SET POINT ACCESS Read Write Each relay is shipped from the factory with set point access allowed The passcode is also defaulted to 0 which disables the passcode security feature entirely 2 Press the MESSAGE key once 3 Press the VALUE or VALUE key once 4 Press the ENTER key to begin the procedure of changing the passcode The dis played me...

Page 16: ...d press ENTER The dis played message will change as shown 3 Enter the current passcode and press the ENTER key This flash message indi cates that the keyed in value was accepted and that passcode security is now disabled 4 This message will appear after a few seconds Now that setpoint access is enabled the ALLOW ACCESS TO SETPOINTS message has been replaced by the RESTRICT ACCESS TO SETPOINTS mess...

Page 17: ...economical package The relay provides a variety of adaptive relaying features Adaptive Harmonic Restraint which addresses the problem of false tripping during inrush Adaptive Time Overcurrent elements which will adjust their pickup settings based on the calculated transformer capability when supplying load currents with high harmonic content Multiple Setpoint Groups which allow the user to enter a...

Page 18: ... Restricted Ground Fault AN 1 Analog Input Level 1 1THD Total Harmonic Distortion Level AN 2 Analog Input Level 2 1AD Current Demand Insulation Aging Aging Factor Hottest Spot Limit and Total Accumulated Life Tap Changer Monitor Symbol Winding 2 Protection Element Symbol Winding 3 Protection Elements 250 46 Negative Sequence Instantaneous Overcurrent 350 46 Negative Sequence Instantaneous Overcurr...

Page 19: ...ding 2 5 A P51 Winding 1 5 A Winding 2 1 A P115 Winding 1 1 A Winding 2 1 A Winding 3 5 A P151 Winding 1 1 A Winding 2 5 A Winding 3 1 A P155 Winding 1 1 A Winding 2 5 A Winding 3 5 A P511 Winding 1 5 A Winding 2 1 A Winding 3 1 A P515 Winding 1 5 A Winding 2 1 A Winding 3 5 A P551 Winding 1 5 A Winding 2 5 A Winding 3 1 A Ground current input ratings G1 Winding 1 2 1 A Winding 2 3 1 A G5 Winding ...

Page 20: ...5 A secondary Relay input 1 A or 5 A specified at order Burden less than 0 2 VA at rated load Conversion range 0 02 to 46 CT Accuracy at 4 CT 0 25 of 4 CT 0 01 CT at 4 CT 0 5 of 46 CT 0 2 CT Overload Withstand 1 second at 80 times rated current 2 seconds at 40 times rated current continuous at 3 times rated current VOLTAGE INPUTS Source VT 2 to 600 kV 60 to 120 V Source VT ratio 1 to 5000 in steps...

Page 21: ... B C programmable curves IAC Extreme Very Inverse Short Curve multiplier 0 5 to 30 for ANSI IAC and FlexCurves in steps of 0 1 s 0 05 to 100 00 for IEC curves in steps of 0 01 Reset type Instantaneous or Linear Level accuracy Per current input Timing accuracy 3 of trip time or 20 ms whichever is greater at 1 03 pickup PHASE NEUTRAL GROUND NEGATIVE SEQUENCE INSTANTANEOUS OVERCURRENT Pickup level 0 ...

Page 22: ...ltage pickup 0 10 to 0 99 VT in steps of 0 01 Pickup level 1 00 to 4 00 V Hz in steps of 0 01 Curve shapes Definite Time 0 1 sec base curve IEC Curve A B C Time delay 0 00 to 600 00 s in steps of 0 01 Reset delay 0 0 to 6000 0 s in steps of 0 1 Signal source Voltage Range 10 to 65 Hz Level accuracy 0 02 V Hz Solid state output operate time at 1 10 pickup 165 to 195 ms Relay outputs 2 to 5 operate ...

Page 23: ...torage temperature 40 C to 80 C ambient Humidity up to 90 non condensing Altitude 2000 m Pollution degree II CASE Drawout Fully drawout unit automatic CT shorts Seal Seal provision Door Dust tight door Panel Panel or 19 rack mount Weight case and relay 18 lbs 6 oz IP class X0 PRODUCTION TESTS Thermal Operational test at ambient then increasing to 60 C Dielectric Strength per IEC 255 5 and ANSI IEE...

Page 24: ...lative Humidity Cyclic 55 C at 95 RH IEC 60068 2 38 Composite Temperature Humidity 65 10 C at 93 RH IEC 60255 5 Dielectric Strength 2300 V AC IEC 60255 5 Impulse Voltage 5 kV IEC 60255 21 1 Sinusoidal Vibration 2 g IEC 60255 22 1 Damped Oscillatory Burst 1 MHz 2 5 kV 1 kV IEC 60255 22 2 Electrostatic Discharge Air and Direct 15 kV 8 kV IEC 60255 22 3 Radiated RF Immunity 10 V m IEC 60255 22 4 Elec...

Page 25: ...nnections to external equipment Where required case connectors are fitted with mechanisms such as automatic CT shorting to allow the safe removal of the relay from an energized panel There are no electronic components in the case FIGURE 3 1 Case Dimensions Panel Cutout A 745 can be mounted alone or adjacent to another SR series unit on a standard 19 rack panel Panel cutout dimensions for both cond...

Page 26: ...its case as described in the next section From the front of the panel slide the empty case into the cutout To ensure the front bezel sits flush with the panel apply pressure to the bezel s front while bending the retaining tabs 90 These tabs are located on the sides and bottom of the case and appear as shown in the illustration After bending all tabs the case will be securely mounted so that its r...

Page 27: ...pply strong force in the following step or damage may result To remove the unit from the case 1 Open the cover by pulling the upper or lower corner of the right side which will rotate about the hinges on the left 2 Release the locking latch located below the locking handle by pressing upward on the latch with the tip of a screwdriver FIGURE 3 5 Press Latch to Disengage Handle 3 Grasp the locking h...

Page 28: ...e until the guide pins on the unit have engaged the guide slots on either side of the case 4 Grasp the locking handle from the center and press down firmly rotating the handle from the raised position toward the bottom of the unit 5 When the unit is fully inserted the latch will be heard to click locking the han dle in the final position To prevent unauthorized removal of the drawout unit a wire l...

Page 29: ...t in features that allow for a broad range of applications As such it is not possible to present connections for all possible schemes The information in this section covers the important aspects of interconnections in the general areas of instrument transformer inputs other inputs outputs communications and grounding Rear Terminal Layout FIGURE 3 9 Rear Terminal Layout ...

Page 30: ...iliary Relay Common B7 External RS485 F7 Output 7 Auxiliary Relay NO B8 IRIG B F8 Output 7 Auxiliary Relay NC B9 IRIG B F9 Output 8 Auxiliary Relay Common B10 RTD 1 Hot F10 Output 9 Service Relay NO B11 RTD 1 Compensation F11 Output 9 Service Relay NC B12 RTD 1 Return F12 Ground Winding 2 3 CT Logic Inputs 9 to 16 and VT Input CT Inputs and 745 Grounding C1 Logic Input 9 G1 Phase A Winding 1 CT C2...

Page 31: ...rate for unbalanced conditions In addition depending on which winding the VT is on the power flows and vars displayed may be opposite in direction to the actual system flow e g in the case of a generator step up transformer depending on the relay winding assignments and which side of the transformer the VT is connected to the power may be negative when the generator is producing positive MW This c...

Page 32: ...Typical Wiring 745 Transformer Management Relay Installation http www GEindustrial com multilin 3 8 GE Multilin FIGURE 3 11 Typical Wiring for Three Winding Transformer MULTILIN ...

Page 33: ...pe is Delta 2 The G1 2 ground input is associated with the first Wye or Zig Zag type winding from a two winding transformer it is never associated with Winding 3 from a three winding transformer setup 3 The G2 3 ground input is associated with the second Wye or Zig Zag type wind ing from two or three winding setup it is never associated with Winding 1 The G2 3 ground input is associated with Windi...

Page 34: ...s the 32 V DC voltage rail The other side is connected to the required logic input terminal When a dry contact closes a 2 2 mA current flows through the associated circuit A wet contact has one side connected to the positive terminal of an external DC power supply The other side is connected to the required logic input terminal In addition the negative side of the external source must be connected...

Page 35: ... markings for correct operation Both terminals are clamped to within 36 volts of ground with surge protection As such common mode voltages should not exceed this limit Shielded wire with only one end of the shield grounded is recommended to minimize noise effects The A2 terminal must be connected to the A5 Analog Output Common terminal at the 745 Tap Position Input Terminals A3 and A4 are provided...

Page 36: ...p Output A high speed solid state SCR output is also provided This output is intended for applications where it is necessary to key a communications channel Analog Outputs The 745 provides 7 analog output channels whose full scale range can be set to one of the following ranges 0 to 1 mA 0 to 5 mA 0 to 10 mA 0 to 20 mA and 4 to 20 mA Each analog output channel can be programmed to represent one of...

Page 37: ...s from noise the use of shielded twisted pair wire is recommended Correct polarity should also be observed For instance the relays must be connected with all B1 terminals labeled COM1 RS485 connected together and all B2 terminals labeled COM1 RS485 connected together Terminal B3 labeled COM1 RS485 COM should be connected to the common wire inside the shield To avoid loop currents the shield should...

Page 38: ... Program Port A 9 pin RS232C serial port is located on the front panel for programming through a PC This port uses the same Modbus protocol as the two rear ports The enerVista 745 Setup software required to use this interface is included with the relay Cabling for the RS232 port is shown below for both 9 pin and 25 pin connectors FIGURE 3 18 RS232 Wiring ...

Page 39: ...cations can also be synchronized FIGURE 3 19 IRIG B Function Dielectric Strength Dielectric strength test was performed on the 745 relay at the manufacturer It is not necessary to perform this test again at the customer site However if you wish to perform this test follow instructions outlined in Dielectric Strength Testing on page 7 4 No special ventilation requirements need to be observed during...

Page 40: ...Typical Wiring 745 Transformer Management Relay Installation http www GEindustrial com multilin 3 16 GE Multilin ...

Page 41: ...isplay LED status indicators control keys and program port The display and status indicators update alarm and status information automatically The control keys are used to select the appropriate message for entering setpoints or displaying measured values The RS232 program port is also provided for connection with a computer running the enerVista 745 Setup software FIGURE 4 1 745 Front Panel View ...

Page 42: ...ly if all of the following conditions are met The S1 745 SETUP INSTALLATION 745 SETPOINTS setpoint is set to Programmed The S6 TESTING OUTPUT RELAYS FORCE OUTPUT RELAYS FUNCTION setpoint is set to Disabled The S6 TESTING SIMULATION SIMULATION SETUP SIMULATION FUNCTION setpoint is set to Disabled No self test errors which have an effect on protection have been detected Code programming mode is inac...

Page 43: ... on when any output relay selected to be of the Trip type has operated ALARM The Alarm LED is on when any output relay selected to be of the Alarm type has operated PICKUP The Pickup LED is on when any element has picked up With this indicator on the front panel display is sequentially displaying information about each element that has picked up PHASE A C The Phase A C LED is on when Phase A C is ...

Page 44: ...This includes resetting latched output relays latched Trip LEDs breaker operation failure and trip coil failure The MESSAGE and MESSAGE keys scroll through any active conditions in the relay Diagnostic messages are displayed indicating the state of protection and monitoring elements that are picked up operating or latched When the Message LED is on there are messages to be viewed with the MENU key...

Page 45: ... or the SETPOINT ACCESS setpoint may be changed to Restricted The passcode cannot be entered until terminals C1 and C2 access terminals are shorted When setpoint access is allowed the Setpoint Access LED indicator on the front of the 745 will be lit Setpoint changes take effect immediately even when transformer is running However changing setpoints while the transformer is running is not recommend...

Page 46: ... time a new setpoint is successfully stored a message will flash on the display stating NEW SETPOINT HAS BEEN STORED 7 Press the 4 8 9 keys then press ENTER The following flash message is dis played and the display returns to 8 Press ESCAPE or MESSAGE to exit the subgroup Pressing ESCAPE or MESSAGE numerous times will always return the cursor to the top of the page Diagnostic Messages Diagnostic m...

Page 47: ...he device in real time This no charge software provided with every 745 relay can be run from any computer supporting Microsoft Windows 95 or higher This chapter provides a summary of the basic enerVista 745 Setup software interface features The enerVista 745 Setup help file provides details for getting started and using the software interface With the enerVista 745 Setup running on your PC it is p...

Page 48: ...n 4 0 or higher required libraries 128 MB of RAM 256 MB recommended Minimum of 200 MB hard disk space A list of qualified modems for serial communications is shown below US Robotics external 56K Faxmodem 5686 US Robotics external Sportster 56K X2 PCTEL 2304WT V 92 MDC internal modem After ensuring these minimum requirements use the following procedure to install the enerVista 745 Setup software fr...

Page 49: ...e Launch Pad window 5 In the enerVista Launch Pad window click the Add Product button and select the 745 Transformer Management Relay from the Install Software window as shown below Select the Web option to ensure the most recent software release or select CD if you do not have a web connection then click the Add Now button to list software items for the 745 ...

Page 50: ...ring the downloading process 7 Select the complete path including the new directory name where the enerV ista 745 Setup software will be installed 8 Click on Next to begin the installation The files will be installed in the directory indicated and the installation program will automatically create icons and add enerVista 745 Setup software to the Windows start menu 9 Click Finish to end the instal...

Page 51: ...dow and click the Add Site button to define a new site 3 Enter the desired site name in the Site Name field If desired a short description of site can also be entered along with the display order of devices defined for the site In this example we will use Transformer Station 1 as the site name Click the OK button when complete 4 The new site will appear in the upper left list in the enerVista 745 ...

Page 52: ...ns Using the Quick Connect Feature The Quick Connect button can be used to establish a fast connection through the front panel RS232 port of a 745 relay The following window will appear when the Quick Connect button is pressed As indicated by the window the Quick Connect feature quickly connects the enerVista 745 Setup software to a 745 front port with the following settings 9600 baud no parity 8 ...

Page 53: ...e OK button when complete 4 The new site will appear in the upper left list in the enerVista 745 Setup window 5 Click the Add Device button to define the new device 6 Enter the desired name in the Device Name field and a description optional of the site 7 Select Ethernet from the Interface drop down list This will display a number of interface parameters that must be entered for proper Ethernet fu...

Page 54: ...n the Front Panel settings window as shown below FIGURE 4 4 Main Window After Connection 4 The Front Panel settings window will open with a corresponding status indicator on the lower left of the enerVista 745 Setup window 5 If the status indicator is red verify that the serial cable is properly connected to the relay and that the relay has been properly configured for communications steps describ...

Page 55: ...ntering of setpoints In this example we will be changing the current sensing setpoints 1 Establish communications with the relay 2 Select the Setpoint System Setup Transformer menu item This can be selected from the device setpoint tree or the main window menu bar 3 Select the LOAD LOSS AT RATED LOAD setpoint by clicking anywhere in the parameter box This will display three arrows two to increment...

Page 56: ...to the Settings List tree New files will be automatically added to the tree which is sorted alphabetically with respect to settings file names Using Setpoints Files a Overview The enerVista 745 Setup software interface supports three ways of handling changes to relay settings In off line mode relay disconnected to create or edit relay settings files for later download to communicating relays Direc...

Page 57: ...st 3 Select the File Read Settings from Device menu item to obtain settings information from the device 4 After a few seconds of data retrieval the software will request the name and destination path of the setpoint file The corresponding file extension will be automatically assigned Press Save to complete the process A new entry will be added to the tree in the File pane showing path and file nam...

Page 58: ...oftware Revision for the new setpoint file 3 Configure the Installed Options as shown 4 For future reference enter some useful information in the Description box to facilitate the identification of the device and the purpose of the file 5 To select a file name and path for the new file click the button beside the File Name box 6 Select the file name and path to store the file or select any display...

Page 59: ...he current setpoint file revision is 4 00 change the setpoint file revision to 4 0X as shown below 6 When complete click Convert to convert the setpoint file to the desired revision A dialog box will request confirmation See Loading Setpoints from a File on page 4 20 for instructions on loading this setpoint file into the 745 f Printing Setpoints and Actual Values The enerVista 745 Setup software ...

Page 60: ... device list and selecting the Print Device Information option g Loading Setpoints from a File An error message will occur when attempting to download a setpoint file with a revision number that does not match the relay firmware If the firmware has been upgraded since saving the setpoint file see Upgrading Setpoint Files to a New Revision on page 4 18 for instructions on changing the revision numb...

Page 61: ...E Multilin website at http www GEindustrial com multilin Saving Setpoints To A File Before upgrading firmware it is very important to save the current 745 settings to a file on your PC After the firmware has been upgraded it will be necessary to load this file back into the 745 Refer to Downloading and Saving Setpoints Files on page 4 17 for details on saving relay setpoints to a file Loading New ...

Page 62: ...ed loading the file Carefully read any displayed messages and click OK to return the main screen Cycling power to the relay is recommended after a firmware upgrade After successfully updating the 745 firmware the relay will not be in service and will require setpoint programming To communicate with the relay the following settings will have to be manually programmed SLAVE ADDRESS COM1 COM2 FRONT B...

Page 63: ...A maximum of 64 cycles can be captured and the trigger point can be adjusted to anywhere within the set cycles A maximum of 16 waveforms can be buffered stored with the buffer cycle trade off The following waveforms can be captured Phase A B and C currents Ia Ib and Ic Differential A B and C currents Idiffa Idiffb and Idiffc Ground currents Ig Phase A N B N and C N voltages Va Vb and Vc Digital da...

Page 64: ...he trigger point of the relay 6 The date and time of the trip is displayed at the top left corner of the window To match the captured waveform with the event that triggered it make note of the time and date shown in the graph Then find the event that matches the same time and date in the event recorder The event record will provide additional information on the cause and the system conditions at t...

Page 65: ...ttributes available for use Trending Data Logger The trending or data logger feature is used to sample and record up to eight actual values at an interval defined by the user Several parameters can be trended and graphed at sampling periods ranging from 1 second up to 1 hour The parameters which can be trended by the enerVista 745 Setup software are Currents Voltages Ia Ib Ic In and Ig currents fo...

Page 66: ...channel description 4 Select the Sample Rate through the pull down menu 5 If you want to save the information captured by trending check the box besides Log Samples to File The following dialog box will appear requesting for file name and path The file is saved as csv comma delimited values file which can be viewed and manipulated with compatible third party software Ensure that the sample rate no...

Page 67: ...s can be stored where E40 is the most recent event and E01 is the oldest event E01 is overwritten whenever a new event occurs Refer to Event 01 to Event 40 on page 6 26 for additional information on the event recorder Use the following procedure to view the event recorder with enerVista 745 Setup 1 With enerVista 745 Setup running and communications established select the Actual Event Recorder ite...

Page 68: ... Communications Guide for additional information on the User Map 1 Select a connected device in enerVista 745 Setup 2 Select the Setpoint User Map menu item to open the following window EVENT LISTING Lists the last 128 events with the most recent displayed at top of list EVENT SELECTION Select an event row to view event data information which will be displayed in the window to the right CLEAR EVEN...

Page 69: ...o the following list 1 System Status The status of the logic inputs and virtual inputs outputs Targets The status of the output relays Any self test errors 2 Metering Data Instantaneous current measurements including phase neutral and ground currents for each winding along with differential restraint positive sequence negative sequence zero sequence and ground restraint currents Harmonic metering ...

Page 70: ...r downloading tool Selecting an actual values window also opens the actual values tree from the corresponding device in the site list and highlights the current location in the hierarchy For complete details on actual values refer to Chapter 6 To view a separate window for each group of actual values select the desired item from the tree and double click with the left mouse button Each group will ...

Page 71: ... 2 Ensure that the 745 device has been properly configured for either serial or Ethernet communications see previous sections for details 3 Click the Viewpoint window in enerVista to log into enerVista Viewpoint At this point you will be required to provide a login and password if you have not already done so FIGURE 4 10 enerVista Viewpoint Main Window 4 Click the Device Setup button to open the D...

Page 72: ...munications error occurs ensure that communications values entered in the previous step correspond to the relay setting values 10 Click OK when complete 11 From the enerVista main window select the IED Dashboard item to open the Plug and Play IED dashboard An icon for the 745 will be shown FIGURE 4 12 Plug and Play Dashboard 12 Click the Dashboard button below the 745 icon to view the device infor...

Page 73: ...former Management Relay Interfaces http www GEindustrial com multilin 4 33 GE Multilin FIGURE 4 13 enerVista Plug and Play Screens Example For additional information on enerVista viewpoint please visit the enerVista website at http www enerVista com ...

Page 74: ...Using enerVista Viewpoint with the 745 745 Transformer Management Relay Interfaces http www GEindustrial com multilin 4 34 GE Multilin ...

Page 75: ...ftware and not connected to a relay you may have to select the File Properties menu item and set the correct options for your relay SETPOINTS S1 745 SETUP PASSCODE See page 5 24 MESSAGE PREFERENCES See page 5 24 MESSAGE COMMUNICATIONS See page 5 25 MESSAGE RESETTING See page 5 27 MESSAGE CLOCK See page 5 27 MESSAGE DEFAULT MESSAGES See page 5 27 MESSAGE SCRATCHPAD See page 5 28 MESSAGE INSTALLATIO...

Page 76: ...35 MESSAGE ANALOG INPUT See page 5 36 MESSAGE DEMAND METERING See page 5 36 MESSAGE ANALOG OUTPUTS See page 5 37 MESSAGE END OF PAGE S2 SETPOINTS S3 LOGIC INPUTS LOGIC INPUTS See page 5 38 MESSAGE VIRTUAL INPUTS See page 5 39 MESSAGE END OF PAGE S3 SETPOINTS S4 ELEMENTS SETPOINT GROUP See page 5 41 MESSAGE DIFFERENTIAL See page 5 41 MESSAGE INST DIFFERENTIAL See page 5 48 MESSAGE PHASE OC See page...

Page 77: ... CURRENT DEMAND See page 5 83 MESSAGE XFORMER OVERLOAD See page 5 84 MESSAGE TAP CHANGER FAILURE See page 5 85 MESSAGE END OF PAGE S4 SETPOINTS S5 OUTPUTS OUTPUT RELAYS See page 5 88 MESSAGE TRACE MEMORY See page 5 90 MESSAGE VIRTUAL OUTPUTS See page 5 91 MESSAGE TIMERS See page 5 91 MESSAGE END OF PAGE S5 SETPOINTS S6 TESTING OUTPUT RELAYS See page 5 92 MESSAGE ANALOG OUTPUTS See page 5 92 MESSAG...

Page 78: ...ot Programmed when the relay leaves the factory The SETPOINTS HAVE NOT BEEN PROGRAMMED diagnostic message appears until the 745 is put in the programmed state Messages may vary somewhat from those illustrated because of installed options Also some messages associated with disabled features or optional features which have not been ordered are hidden These messages are shown with a shaded message bo...

Page 79: ...00 133 166 MVA 220 kV nominal 500 1 CT ratio Winding 2 100 133 166 MVA 69 kV nominal 1500 1 CT ratio onload tap changer 61 to 77 kV in 0 5 kV steps 33 tap positions Aux Cooling two stages of forced air The following sections will illustrate auto configuration principles using this example Dynamic CT Ratio Mismatch Correction a Use of Standard CT Ratios Standard CT ratios CT2 CT1 V1 V2 Tapped relay...

Page 80: ...anger at position 33 the Winding 2 CT ratio must be 1428 6 1 to be perfectly matched In this case the mismatch factor is 1428 6 1500 0 952 The 745 allows monitoring of the tap changer position via the tap position input With this input the 745 dynamically adjusts the CT ratio mismatch factor based on the actual transformer voltage ratio set by the tap changer Tap changers are operated by means of ...

Page 81: ...e phase sequence of 1 2 3 is connected to transformer windings labeled 1 2 and 3 respectively IEC standard 60076 1 1993 states that the terminal markings of the three phases follow national practice The phase relationship among the windings is shown as a specified notation on the nameplate and there may be a phasor diagram In this standard the arbitrary labeling of the windings is shown as I II an...

Page 82: ...elta winding have not changed The transformer nameplate phase relationship information is only correct for a stated phase sequence It may be suggested that for the ACB sequence the phase relationship can be returned to that shown on the transformer nameplate by connecting source phases A B and C to transformer terminals A C and B respectively This will restore the nameplate phase shifts but will c...

Page 83: ...hree winding transformer types Table 5 1 Transformer Types on page 5 11 provides the following information about each transformer type As shown in the Y d30 entry of the table of transformer types the phase angle correction or phase shift introduces 30 lag in Winding 1 This lag is described in Table 5 2 Phase Shifts on page 5 23 This table provides the following information about each phase shift ...

Page 84: ...erential element for transformers having an in zone grounding bank on the Delta side and the Wye connected CTs on the same side Traditionally this problem is solved by insert ing a zero sequence current trap in the CT circuitry The 745 automatically removes zero sequence current from all Delta winding currents when calculat ing differential current Where there is no source of zero sequence current...

Page 85: ...3 180 lag 0 Y d30 1 WYE gnd 1 2 30 lag 2 DELTA 30 lag 0 Y d150 1 WYE gnd 1 2 150 lag 2 DELTA 150 lag 0 Y d210 1 WYE gnd 1 2 210 lag 2 DELTA 210 lag 0 Y d330 1 WYE gnd 1 2 330 lag 2 DELTA 330 lag 0 D d0 1 DELTA 0 2 DELTA 0 0 D d60 1 DELTA 60 lag 2 DELTA 60 lag 0 D d120 1 DELTA 120 lag 2 DELTA 120 lag 0 D d180 1 DELTA 180 lag 2 DELTA 180 lag 0 D d240 1 DELTA 240 lag 2 DELTA 240 lag 0 D d300 1 DELTA ...

Page 86: ...0 Y z330 1 WYE gnd 1 2 330 lag 2 ZIG ZAG gnd 2 3 330 lag 0 Table 5 1 Transformer Types Sheet 3 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift D z0 1 DELTA 0 2 ZIG ZAG gnd 1 2 0 lag 0 D z60 1 DELTA 60 lag 2 ZIG ZAG gnd 1 2 60 lag 0 D z120 1 DELTA 120 lag 2 ZIG ZAG gnd 1 2 120 lag 0 D z180 1 DELTA 180 lag 2 ZIG ZAG gnd 1 2 180 lag 0 D z240 1 DELTA 240 lag 2 ZIG ZAG gnd 1 2 240 lag...

Page 87: ...WYE gnd 2 3 0 330 lag 3 DELTA 330 lag 0 Table 5 1 Transformer Types Sheet 5 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift Y y180 d30 1 WYE gnd 1 2 30 lag 2 WYE gnd 2 3 180 lag 210 lag 3 DELTA 30 lag 0 Y y180 d150 1 WYE gnd 1 2 150 lag 2 WYE gnd 2 3 180 lag 330 lag 3 DELTA 150 lag 0 Y y180 d210 1 WYE gnd 1 2 210 lag 2 WYE gnd 2 3 180 lag 30 lag 3 DELTA 210 lag 0 Y y180 d330 1 WY...

Page 88: ... 30 lag 2 DELTA 30 lag 0 3 DELTA 150 lag 240 lag Table 5 1 Transformer Types Sheet 7 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift Y d30 d210 1 WYE gnd 1 2 30 lag 2 DELTA 30 lag 0 3 DELTA 210 lag 180 lag Y d30 d330 1 WYE gnd 1 2 30 lag 2 DELTA 30 lag 0 3 DELTA 330 lag 60 lag Y d150 y0 1 WYE gnd 1 2 150 lag 2 DELTA 150 lag 0 3 WYE gnd 2 3 0 150 lag Y d150 y180 1 WYE gnd 1 2 150 ...

Page 89: ...2 150 lag 2 DELTA 150 lag 0 3 DELTA 330 lag 180 lag Table 5 1 Transformer Types Sheet 9 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift Y d210 y0 1 WYE gnd 1 2 210 lag 2 DELTA 210 lag 0 3 WYE gnd 2 3 0 210 lag Y d210 y180 1 WYE gnd 1 2 210 lag 2 DELTA 210 lag 0 3 WYE gnd 2 3 180 lag 30 lag Y d210 d30 1 WYE gnd 1 2 210 lag 2 DELTA 210 lag 0 3 DELTA 30 lag 180 lag Y d210 d150 1 WYE...

Page 90: ...2 330 lag 2 DELTA 330 lag 0 3 WYE gnd 2 3 180 lag 150 lag Table 5 1 Transformer Types Sheet 11 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift Y d330 d30 1 WYE gnd 1 2 330 lag 2 DELTA 330 lag 0 3 DELTA 30 lag 300 lag Y d330 d150 1 WYE gnd 1 2 330 lag 2 DELTA 330 lag 0 3 DELTA 150 lag 180 lag Y d330 d210 1 WYE gnd 1 2 330 lag 2 DELTA 330 lag 0 3 DELTA 210 lag 120 lag Y d330 d330 1...

Page 91: ... 240 lag 2 DELTA 0 240 lag 3 DELTA 240 lag 0 Table 5 1 Transformer Types Sheet 13 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift D d0 d300 1 DELTA 300 lag 2 DELTA 0 300 lag 3 DELTA 300 lag 0 D d0 y30 1 DELTA 0 2 DELTA 0 0 3 WYE gnd 2 3 30 lag 330 lag D d0 y150 1 DELTA 0 2 DELTA 0 0 3 WYE gnd 2 3 150 lag 210 lag D d0 y210 1 DELTA 0 2 DELTA 0 0 3 WYE gnd 2 3 210 lag 150 lag D d0 y...

Page 92: ...A 60 lag 300 lag 3 WYE gnd 2 3 210 lag 150 lag Table 5 1 Transformer Types Sheet 15 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift D d120 d0 1 DELTA 120 lag 2 DELTA 120 lag 0 3 DELTA 0 120 lag D d120 d120 1 DELTA 120 lag 2 DELTA 120 lag 0 3 DELTA 120 lag 0 D d120 d180 1 DELTA 120 lag 2 DELTA 120 lag 0 3 DELTA 180 lag 300 lag D d120 y150 1 DELTA 0 2 DELTA 120 lag 240 lag 3 WYE gn...

Page 93: ...A 0 2 DELTA 180 lag 180 lag 3 WYE gnd 2 3 150 lag 210 lag Table 5 1 Transformer Types Sheet 17 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift D d180 y330 1 DELTA 0 2 DELTA 180 lag 180 lag 3 WYE gnd 2 3 330 lag 30 lag D d240 d0 1 DELTA 240 lag 2 DELTA 240 lag 0 3 DELTA 0 240 lag D d240 d60 1 DELTA 240 lag 2 DELTA 240 lag 0 3 DELTA 60 lag 180 lag D d240 d240 1 DELTA 240 lag 2 DELT...

Page 94: ...g 300 lag D y30 d240 1 DELTA 0 2 WYE gnd 1 2 30 lag 330 lag 3 DELTA 240 lag 120 lag Table 5 1 Transformer Types Sheet 19 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift D y30 y30 1 DELTA 0 2 WYE gnd 1 2 30 lag 330 lag 3 WYE gnd 2 3 30 lag 330 lag D y30 y210 1 DELTA 0 2 WYE gnd 1 2 30 lag 330 lag 3 WYE gnd 2 3 210 lag 150 lag D y150 d0 1 DELTA 0 2 WYE gnd 1 2 150 lag 210 lag 3 DEL...

Page 95: ...E gnd 2 3 330 lag 30 lag Table 5 1 Transformer Types Sheet 21 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift D y210 d0 1 DELTA 0 2 WYE gnd 1 2 210 lag 150 lag 3 DELTA 0 0 D y210 d60 1 DELTA 0 2 WYE gnd 1 2 210 lag 150 lag 3 DELTA 60 lag 300 lag D y210 d240 1 DELTA 0 2 WYE gnd 1 2 210 lag 150 lag 3 DELTA 240 lag 120 lag D y210 y30 1 DELTA 0 2 WYE gnd 1 2 210 lag 150 lag 3 WYE gnd...

Page 96: ... 2 WYE gnd 1 2 330 lag 30 lag 3 DELTA 300 lag 60 lag D y330 y150 1 DELTA 0 2 WYE gnd 1 2 330 lag 30 lag 3 WYE gnd 2 3 150 lag 210 lag Table 5 1 Transformer Types Sheet 23 of 24 Transformer Type Wdg Connection Voltage Phasors Phase Shift D y330 y330 1 DELTA 0 2 WYE gnd 1 2 330 lag 30 lag 3 WYE gnd 2 3 330 lag 30 lag Y z30 z30 1 WYE 30 lag 2 ZIG ZAG gnd 1 2 30 lag 0 3 ZIG ZAG gnd 2 3 30 lag 0 Y y0 y...

Page 97: ...or transformers connected to a system with a phasor rotation of ACB interchange all B b and C c designations Table 5 2 Phase Shifts Phase Shift Input Phasors Output Phasors Phasor Transformation 0 a A b B c C 30 lag a A C b B A c C B 60 lag a C b A c B 90 lag a B C b C A c A B 120 lag a B b C c A 150 lag a B A b C B c A C 180 lag a A b B c C 210 lag a C A b A B c B C 240 lag a C b A c B 270 lag a ...

Page 98: ...is allowed If there is no keypress within 30 minutes setpoint write access is automatically restricted As an additional safety measure the SELF TEST ERROR Access Denied message is generated when the passcode is entered incorrectly three consecutive times CHANGE PASSCODE Select Yes and follow directions to change the current passcode Changing the passcode to the factory default of 0 disables the pa...

Page 99: ...ed to use the front panel program port since only one relay can be connected at one time COM1 COM2 BAUD RATE Select the baud rates for COM1 the RS485 RS422 communication port or COM2 These setpoints cannot be changed via the communication ports All relays on the communication link and the computer connecting them must run at the same baud rate The fastest response is obtained at 19200 baud COM1 CO...

Page 100: ...end the frame if retries are still available DATA LINK CONFIRM RETRIES Select the maximum number of retries that will be issued for a given data link frame SELECT OPERATE ARM TIMEOUT Select the duration of the select operate arm timer WRITE TIME INTERVAL Select the time that must elapse before the 745 will set the need time internal indication IIN After the time is written by a DNP master the IIN ...

Page 101: ...ping for various relay features such as event and last trip data recording Without an IRIG B signal the current time and date must be entered in a new relay for any time and date displayed If not entered all message references to time or date will display Unavailable With an IRIG B signal only the current year needs to be entered DATE Enter the current date using two digits for the month two digit...

Page 102: ...s displayed The screen will display PRESS ENTER TO ADD AS DEFAULT Press ENTER again while this message is being displayed The message is now added to the default message list Default messages are removed from the default message list as follows 1 Allow access to setpoints by installing the setpoint access jumper and entering the correct passcode 2 Select the message under the section S1 745 SETUP ...

Page 103: ...log Input Output option and the Loss Of Life option is to be added then the ENABLE ANALOG I O setpoint and the ENABLE LOSS OF LIFE setpoint must be set to Yes The ENABLE RESTRICTED GROUND FAULT setpoint must be set to No ENABLE ANALOG I O Select Yes if the upgrade options set supports the Analog I O feature otherwise select No The default value for this setpoint reflects the current state of the o...

Page 104: ...signals contain significant amount of sub harmonic components it may be necessary to disable frequency tracking PHASE SEQUENCE Enter the phase sequence of the power system Systems with an ACB phase sequence require special considerations See Phase Shifts on Three Phase Transformers on page 5 7 for details TRANSFORMER NOMINAL FREQUENCY 60 Hz Range 50 Hz 60 Hz MESSAGE FREQUENCY TRACKING Enabled Rang...

Page 105: ...low voltage winding rating This selection affects the ranges of WINDING 1 3 NOM Ø Ø VOLTAGE WINDING 1 3 RATED LOAD MINIMUM TAP POSITION VOLTAGE and VOLTAGE INCREMENT PER TAP as shown in the table above RATED WINDING TEMP RISE Determines the type of insulation for use in the computation of insulation aging NO LOAD LOSS From the transformer data It is required for insulation aging calculations This ...

Page 106: ...rimary current rating of the current transformers connected in the Winding 1 3 neutral to ground path The CT secondary current rating must match the relay ground current input rating indicated This message will only appear if the transformer type setpoint shows that Winding 1 3 is a wye connected winding WINDING 1 3 SERIES 3 Φ RESISTANCE Enter the series three phase resistance of the winding that ...

Page 107: ...ng table RESISTANCE INCREMENT PER TAP Enter the resistance increment that the 745 will see for each tap increment The maximum resistance value for the top tap is 5 KΩ Harmonics PATH SETPOINTS S2 SYSTEM SETUP HARMONICS The 745 calculates the individual harmonics in each of the phase current inputs up to the 21st harmonic With this information it calculates an estimate of the effect of non sinusoida...

Page 108: ... 6 0 PU in steps of 0 1 and 6 5 to 20 0 PU in steps of 0 5 FLEXCURVE A DELAY AT n PU Enter the trip time for n 1 03 1 05 20 0 PU for FlexCurve A C The messages that follow sequentially correspond to the trip times for the various pickup levels as indicated above Voltage Input PATH SETPOINTS S2 SYSTEM SETUP VOLTAGE INPUT The 745 provides a voltage input for the purposes of energization detection fo...

Page 109: ...SSAGE AVERAGE AMBIENT TEMP FOR DECEMBER 20 C Range 50 to 125 C in steps of 1 Table 5 3 RTD Resistance vs Temperature Temperature 100 Ω Platinum 120 Ω Nickel 100 Ω Nickel 50 C 80 31 Ω 86 17 Ω 71 81 Ω 40 C 84 27 Ω 92 76 Ω 79 13 Ω 30 C 88 22 Ω 99 41 Ω 84 15 Ω 20 C 92 16 Ω 106 15 Ω 89 23 Ω 10 C 96 09 Ω 113 00 Ω 94 58 Ω 0 C 100 00 Ω 120 00 Ω 100 00 Ω 10 C 103 90 Ω 127 17 Ω 105 60 Ω 20 C 107 79 Ω 134 52...

Page 110: ... the ANALOG INPUT UNITS setpoint Demand Metering PATH SETPOINTS S2 SYSTEM SETUP DEMAND METERING This section assigns the demand setpoints for monitoring current demand on all three phases of each windings Current demand on the 745 is performed one of three ways Thermal Rolling Demand or Block Interval CURRENT DEMAND METER TYPE Select the method to be used for the current demand metering Select The...

Page 111: ...ng Demand Enter the time period over which the current demand calculation is performed The TIME INTERVAL is only displayed when Block Interval or Rolling Demand is selected for the CURRENT DEMAND METER TYPE Analog Outputs 1 to 7 PATH SETPOINTS S2 SYSTEM SETUP ANALOG OUTPUTS ANALOG OUTPUT 1 7 There are seven analog outputs on the 745 relay which are selected to provide a full scale output range of ...

Page 112: ...ent W1 3 ΦB Current W1 3 ΦC Current Select to monitor the RMS value at fundamental frequency of the Winding 1 3 Phase A B and C current inputs W1 3 Loading Select to monitor the Winding 1 3 load as a percentage of the rated load for that winding W1 3 ΦA THD W1 3 ΦB THD W1 3 ΦC THD Select to monitor the total harmonic distortion in the Winding 1 3 Phase A B and C current inputs W1 3 Derating Select...

Page 113: ...nnot generate a displayable target message INPUT 1 16 NAME Press ENTER to edit the login input name The text may be changed from Virtual Input 1 one character at a time with the VALUE keys Press ENTER to store and advance to the next character position INPUT 1 16 PROGRAMMED STATE Select Asserted to place the virtual input into the signaling state likewise select Not Asserted to place it into the n...

Page 114: ...as the following schematic symbol The exact wording of the front panel label identifies the indicator LOGIC Described using basic AND gates and OR gates NAME OF ELEMENT TARGET Latched Range Self reset Latched None Target messages indicate which elements have picked up or operated Select Latched to keep the element target message in the queue of target messages even after the condition which caused...

Page 115: ...ll be overridden if a higher number setpoint group is activated using the ACTIVE SETPOINT GROUP setpoint or another logic input Differential Element a Main Menu PATH SETPOINTS S4 ELEMENTS DIFFERENTIAL This section contains the settings to configure the percent differential element including all associated harmonic inhibit features The 745 provides three independent harmonic inhibit features HARMON...

Page 116: ...alculations have been changed from average to maximum to provide better security during external faults The basic percent differential operating principle for three winding transformers is illustrated by the following equations EQ 5 4 The basic percent differential operating principle for two winding transformers is illustrated by the following equations PERCENT DIFFERENTIAL PERCENT DIFFERENTIAL F...

Page 117: ...tivity to internal faults at normal operating current levels The criteria for setting this slope are To allow for mismatch when operating at the limit of the transformer s onload tap changer range To accommodate for CT errors PERCENT DIFFERENTIAL KNEEPOINT Enter the kneepoint for the dual slope percent differential element This is the transition point between Slopes 1 and 2 in terms of restraint c...

Page 118: ...harmonic inhibit parameters set to 2nd 5th the RMS sum of the 2nd and 5th harmonic components is compared against the level setting With harmonic averaging enabled all three phases are inhibited if the 3 phase average of the harmonics exceeds the level setting HARMONIC INHIBIT PARAMETERS Select 2nd to compare only the 2nd harmonic current against the HARMONIC INHIBIT LEVEL Select 2nd 5th to use th...

Page 119: ...NCTION Enabled Range Enabled Disabled MESSAGE ENERGIZATION INHIBIT PARAMETERS 2nd Range 2nd 2nd 5th MESSAGE HARMONIC AVERAGING Enabled Range Enabled Disabled MESSAGE ENERGIZATION INHIBIT LEVEL 20 0 f0 Range 0 1 to 65 0 f0 in steps of 0 1 MESSAGE ENERGIZATION INHIBIT DURATION 0 10 s Range 0 05 to 600 00 s in steps of 0 01 MESSAGE ENERGIZATION SENSING BY CURRENT Enabled Range Enabled Disabled MESSAG...

Page 120: ... settings are put in service when the contact closes Upon signal removal the energization inhibit duration timer is initiated and the settings are removed from service when the time delay elapses In a breaker and a half scheme where current can be present in the CTs without being present in the transformer winding it may be necessary to use the Parallel Transformer Breaker Close contact to initiat...

Page 121: ...the 745 that the transformer is de energized The selected logic input should be connected to the auxiliary contacts of the transformer breaker or disconnect switch PARALL XFMR BRKR CLS SIGNAL Select any logic input which when asserted will indicate to the 745 the onset of sympathetic inrush The selected logic input should be connected to the close command going to the parallel transformer switchin...

Page 122: ...VEL Enter the level of 5th harmonic current above which the percent differential element will be inhibited from operating FIGURE 5 12 5th Harmonic Inhibit Scheme Logic Instantaneous Differential PATH SETPOINTS S4 ELEMENTS INST DIFFERENTIAL This section contains the settings to configure the unrestrained instantaneous differential element for protection under high magnitude internal faults 5th HARM...

Page 123: ... S4 ELEMENTS PHASE OC This section contains settings to configure the phase overcurrent elements Included are phase time overcurrents and two levels of phase instantaneous overcurrent for each phase of each winding PHASE OC W1 PHASE TIME OC See page 5 54 MESSAGE W2 PHASE TIME OC See page 5 54 MESSAGE W3 PHASE TIME OC See page 5 54 MESSAGE W1 PHASE INST OC 1 See page 5 55 MESSAGE W2 PHASE INST OC 1...

Page 124: ...plier 1 with the curve shape SHAPE setting Unlike the electromechanical time dial equivalent operate times are directly proportional to the time multiplier TIME OC MULTIPLIER setting value For example all times for a multiplier of 10 are 10 times the multiplier 1 or base curve values Setting the multiplier to zero results in an instantaneous response to all current levels above pickup Graphs of st...

Page 125: ... 1 192 1 006 0 878 0 786 10 0 40 009 17 443 6 594 3 680 2 474 1 854 1 491 1 257 1 097 0 982 ANSI Very Inverse 0 5 1 567 0 663 0 268 0 171 0 130 0 108 0 094 0 085 0 078 0 073 1 0 3 134 1 325 0 537 0 341 0 260 0 216 0 189 0 170 0 156 0 146 2 0 6 268 2 650 1 074 0 682 0 520 0 432 0 378 0 340 0 312 0 291 4 0 12 537 5 301 2 148 1 365 1 040 0 864 0 755 0 680 0 625 0 583 6 0 18 805 7 951 3 221 2 047 1 55...

Page 126: ...3 297 3 116 2 971 IEC Curve B 0 05 1 350 0 675 0 338 0 225 0 169 0 135 0 113 0 096 0 084 0 075 0 10 2 700 1 350 0 675 0 450 0 338 0 270 0 225 0 193 0 169 0 150 0 20 5 400 2 700 1 350 0 900 0 675 0 540 0 450 0 386 0 338 0 300 0 40 10 800 5 400 2 700 1 800 1 350 1 080 0 900 0 771 0 675 0 600 0 60 16 200 8 100 4 050 2 700 2 025 1 620 1 350 1 157 1 013 0 900 0 80 21 600 10 800 5 400 3 600 2 700 2 160 ...

Page 127: ...9 1 060 0 926 IAC Very Inverse 0 5 1 451 0 656 0 269 0 172 0 133 0 113 0 101 0 093 0 087 0 083 1 0 2 901 1 312 0 537 0 343 0 266 0 227 0 202 0 186 0 174 0 165 2 0 5 802 2 624 1 075 0 687 0 533 0 453 0 405 0 372 0 349 0 331 4 0 11 605 5 248 2 150 1 374 1 065 0 906 0 810 0 745 0 698 0 662 6 0 17 407 7 872 3 225 2 061 1 598 1 359 1 215 1 117 1 046 0 992 8 0 23 209 10 497 4 299 2 747 2 131 1 813 1 620...

Page 128: ... relays such as most static units with instantaneous reset characteristics W1 3 HARMONIC DERATING CORRECTION Select Enabled to enable automatic harmonic derating correction of the Winging 1 3 Phase Time Overcurrent curve The 745 calculates the derated transformer capability when supplying non sinusoidal load currents as per ANSI IEEE C57 110 1986 and when this feature is enabled automatically shif...

Page 129: ...nt curve Pickup setting based rated load capability Pickup shifted based on harmonic derating Transformer thermal protection margin W1 PHASE INST OC 1 W1 PHASE INST OC 1 FUNCTION Enabled Range Enabled Disabled MESSAGE W1 PHASE INST OC 1 TARGET Latched Range Self Reset Latched None MESSAGE W1 PHASE INST OC 1 PICKUP 10 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 MESSAGE W1 PHASE INST OC 1 DELA...

Page 130: ...eous Overcurrent 2 element FIGURE 5 16 Phase Instantaneous Overcurrent 1 Scheme Logic Neutral Overcurrent a Main Menu PATH SETPOINTS S4 ELEMENTS NEUTRAL OC In the 745 neutral refers to residual current 3I0 calculated internally as the vector sum of the three phases The relay includes neutral time overcurrent and two levels of neutral instantaneous overcurrent for each winding NOTE NEUTRAL OC W1 NT...

Page 131: ...o coordinate with electromechanical time overcurrent relays in which the reset characteristic when the current falls below the reset threshold before tripping is proportional to ratio of energy accumulated to that required to trip Select Instantaneous reset to coordinate with relays such as most static units with instantaneous reset characteristics FIGURE 5 17 Neutral Time Overcurrent Scheme Logic...

Page 132: ...above the pickup level before the element operates The setpoint messages above and the following logic diagram are identical for the Neutral Instantaneous Overcurrent 2 element FIGURE 5 18 Neutral Instantaneous Overcurrent Scheme Logic W1 NTRL INST OC 1 W1 NEUTRAL INST OC 1 FUNCTION Enabled Range Enabled Disabled MESSAGE W1 NEUTRAL INST OC 1 TARGET Latched Range Self Reset Latched None MESSAGE W1 ...

Page 133: ... Enter the level of ground current in units of relay nominal current above which the Winding 1 3 Ground Time Overcurrent element will pickup and start timing GROUND OC W1 GND TIME OC See page 5 59 MESSAGE W2 GND TIME OC See page 5 59 MESSAGE W3 GND TIME OC See page 5 59 MESSAGE W1 GND INST OC 1 See page 5 60 MESSAGE W2 GND INST OC 1 See page 5 60 MESSAGE W3 GND INST OC 1 See page 5 60 MESSAGE W1 G...

Page 134: ... W1 3 GROUND INST OC 1 2 PICKUP Enter the level of ground current in units of relay nominal current above which the Winding 1 3 Ground Instantaneous Overcurrent 1 element will pickup and start the delay timer W1 3 GROUND INST OC 1 2 DELAY Enter the time that the ground current must remain above the pickup level before the element operates The messages above and scheme logic below are identical for...

Page 135: ...hich would not be detected by the percent differential element FIGURE 5 21 Restricted Earth Ground Fault Protection W1 RESTD GND FAULT W1 RESTD GND FAULT FUNCTION Disabled Range Enabled Disabled MESSAGE W1 RESTD GND FAULT TARGET Latched Range Self Reset Latched None MESSAGE W1 RESTD GND FAULT PICKUP 0 08 x CT Range 0 02 to 20 00 x CT in steps of 0 01 MESSAGE W1 RESTD GND FAULT SLOPE 10 Range 0 to ...

Page 136: ...d turns on the secondary Therefore the resultant differential currents could be below the slope threshold of the percent differential element and thus the fault could go undetected The graph below shows the relationship between the primary IP and fault IF currents as a function of the distance of the fault point from the neutral and FIGURE 5 24 RGF and Percent Differential Zones of Protection outl...

Page 137: ...or internal faults is of little consequence since sensitivity and security are the critical parameters For example consider a transformer with the following specifications 10 MVA 33 kV to 11 kV 10 Impedance Delta Wye30 Rg 6 3 ohms Phase CT Ratio 600 1 A Rated Load Current Irated 10 MVA 11 kV 525 A Maximum Ph to Gnd Fault Current Igf max 11 kV 6 3 1000 A For a winding fault point at 5 distance from...

Page 138: ...rrent a Main Menu PATH SETPOINTS S4 ELEMENTS NEG SEQ OC This section contains the settings to configure the negative sequence overcurrent elements Included are negative sequence time overcurrents for each winding and negative sequence instantaneous overcurrents for each winding NEG SEQ OC W1 NEG SEQ TIME OC See page 5 65 MESSAGE W2 NEG SEQ TIME OC See page 5 65 MESSAGE W3 NEG SEQ TIME OC See page ...

Page 139: ...T Select Linear reset to coordinate with electromechanical time overcurrent relays in which the reset characteristic when the current falls below the reset threshold before tripping is proportional to ratio of energy accumulated to that required to trip Select Instantaneous reset to coordinate with relays such as most static units with instantaneous reset characteristics FIGURE 5 27 Negative Seque...

Page 140: ...automatic load shedding schemes based on underfrequency This need arises if during a system disturbance an area becomes electrically isolated from the main system and suffers generation deficiency due to loss of either transmission or generation facilities If reserve generation is not available in the area conditions of low system frequency occur W1 NEG SEQ INST OC W1 NEG SEQ INST OC FUNCTION Disa...

Page 141: ...e use of either the voltage current or both signals for supervision If no supervising conditions are enabled the element could produce undesirable operation b Underfrequency PATH SETPOINTS S4 ELEMENTS FREQUENCY UNDERFREQUENCY 1 2 MINIMUM OPERATING CURRENT Enter the minimum value of Winding 1 Phase A current in units of relay nominal current required to allow the underfrequency element to operate M...

Page 142: ...abled Range Enabled Disabled MESSAGE MINIMUM OPERATING CURRENT 0 20 x CT Range 0 20 to 1 00 x CT in steps of 0 01 MESSAGE MINIMUM OPERATING VOLTAGE 0 50 x VT Range 0 10 to 0 99 x CT in steps of 0 01 MESSAGE FREQUENCY DECAY THRESHOLD 59 50 Hz Range 45 00 to 59 99 Hz in steps of 0 01 MESSAGE FREQUENCY DECAY DELAY 0 00 s Range 0 00 to 600 00 s in steps of 0 01 MESSAGE FREQUENCY DECAY RATE 1 0 4 Hz s ...

Page 143: ...ired to allow the underfrequency element to operate FREQUENCY DECAY THRESHOLD Enter the frequency in Hz below which the four frequency rate of change levels of the frequency decay element will be allowed to operate FREQUENCY DECAY RATE 1 4 Enter the rate of frequency decay beyond which the corresponding element operates FIGURE 5 30 Frequency Decay Scheme Logic MESSAGE FREQUENCY DECAY RATE 4 4 0 Hz...

Page 144: ...OVERFREQUENCY DELAY Enter the time that the frequency must remain above the pickup level before the element operates FIGURE 5 31 Overfrequency Scheme Logic OVERFREQUENCY OVERFREQUENCY FUNCTION Disabled Range Enabled Disabled MESSAGE OVERFREQUENCY TARGET Latched Range Self Reset Latched None MESSAGE CURRENT SENSING Enabled Range Enabled Disabled MESSAGE MINIMUM OPERATING CURRENT 0 20 x CT Range 0 2...

Page 145: ...re the overexcitation monitoring elements Included are a 5th harmonic level and two volts per hertz elements each with a pickup level and a time delay b 5TH Harmonic Level PATH SETPOINTS S4 ELEMENTS OVEREXCITATION 5TH HARMONIC LEVEL MINIMUM OPERATING CURRENT Enter the minimum value of current in units of relay nominal current required to allow the 5th harmonic level element to operate 5TH HARMONIC...

Page 146: ...reset after the VOLTS PER HERTZ RESET value The V Hz function can be used as an instantaneous element with no intentional delay as a definite time element or as an inverse timed element VOLTS PER HERTZ 1 VOLTS PER HERTZ 1 FUNCTION Disabled Range Enabled Disabled MESSAGE VOLTS PER HERTZ 1 TARGET Self Reset Range Self Reset Latched None MESSAGE MINIMUM OPERATING VOLTAGE 0 10 x VT Range 0 10 to 0 99 ...

Page 147: ...lement operates VOLTS PER HERTZ 1 RESET Enter the time that the volts per hertz value must remain below the pickup level before the element resets The curve for the Inverse Curve 1 shape is derived from the formula EQ 5 12 where T operate time seconds D delay setpoint seconds V fundamental RMS value of voltage V F frequency of voltage signal Hz Pickup volts per hertz pickup setpoint V Hz FIGURE 5 ...

Page 148: ...onds V fundamental RMS value of voltage V F frequency of voltage signal Hz Pickup volts per hertz pickup setpoint V Hz FIGURE 5 35 Volts Per Hertz Curve 3 0 1 1 10 100 1000 1 00 1 20 1 40 1 60 1 80 2 00 Multiples of Volts Hertz Pickup Time Delay Setting 10 3 1 0 3 0 1 Time to Trip seconds T D V F Pickup 0 5 1 when V F Pickup 0 1 1 10 100 1000 10000 1 00 1 20 1 40 1 60 1 80 2 00 Multiples of Voltz ...

Page 149: ...NICS This section contains the settings to configure the total harmonic distortion monitoring elements Included are a THD level element for each winding and each phase HARMONICS W1 THD LEVEL See page 5 76 MESSAGE W2 THD LEVEL See page 5 76 MESSAGE W3 THD LEVEL See page 5 76 MESSAGE W1 HARMONIC DERATING See page 5 77 MESSAGE W2 HARMONIC DERATING See page 5 77 MESSAGE W3 HARMONIC DERATING See page 5...

Page 150: ... delay timer W1 3 THD LEVEL DELAY Enter the time that the total harmonic distortion must remain above the pickup level before the element operates FIGURE 5 37 THD Level Scheme Logic W1 THD LEVEL W1 THD LEVEL FUNCTION Disabled Range Enabled Disabled MESSAGE W1 THD LEVEL TARGET Self Reset Range Self Reset Latched None MESSAGE MINIMUM OPERATING CURRENT 0 10 x CT Range 0 03 to 1 00 x CT in steps of 0 ...

Page 151: ...HARMONIC DERATING DELAY Enter the time that the harmonic derating must remain below the pickup level before the element operates FIGURE 5 38 Harmonic Derating Scheme Logic W1 HARMONIC DERATING W1 HARM DERATING FUNCTION Disabled Range Enabled Disabled MESSAGE W1 HARM DERATING TARGET Self Reset Range Self Reset Latched None MESSAGE MINIMUM OPERATING CURRENT 0 10 x CT Range 0 03 to 1 00 x CT in steps...

Page 152: ...feature The first element monitors the hottest spot temperature The second element monitors the aging factor and the third monitors the total accumulated loss of life Each element produces an output when the monitored quantity exceeds a set limit The Insulation Aging Loss of Life feature is a field upgradable feature For the feature and associated elements to operate correctly it must first be ena...

Page 153: ...s setting should be a few degrees above the maximum permissible hottest spot temperature under emergency loading condition and maximum ambient temperature HOTTEST SPOT LIMIT DELAY Enter a time delay above which the hottest spot temperature must remain before the element operates FIGURE 5 39 Hottest Spot Limit Scheme Logic HOTTEST SPOT LIMIT HOTTEST SPOT LIMIT FUNCTION Disabled Range Enabled Disabl...

Page 154: ...ING FACTOR LIMIT PICKUP Enter the Aging Factor required for operation of the element This setting should be above the maximum permissible aging factor under emergency loading condition and maximum ambient temperature AGING FACTOR LIMIT DELAY Enter a time delay above which the Aging Factor must remain before the element operates FIGURE 5 40 Aging Factor Limit Scheme Logic AGING FACTOR LIMIT AGING F...

Page 155: ...elay The output of this element should be used as an alarm only as users may wish to leave the transformer in service beyond the theoretical expended life Enter the expended life in hours required for operation of the element in the LOSS OF LIFE PICKUP setpoint This setting should be above the total life of the transformer in hours As an example for a 15 year transformer the total number of hours ...

Page 156: ...to the analog input terminals The analog input is configured in S2 SYSTEM SETUP ANALOG INPUT and the actual values displayed in A2 METERING ANALOG INPUT FIGURE 5 42 Analog Level Scheme Logic ANALOG LEVEL 1 ANALOG INPUT LEVEL 1 FUNCTION Disabled Range Enabled Disabled MESSAGE ANALOG INPUT LEVEL 1 TARGET Self Reset Range Self Reset Latched None MESSAGE ANALOG INPUT LEVEL 1 PICKUP 10 µA Range 1 to 65...

Page 157: ...luded are a current demand level for each winding and each phase FIGURE 5 43 Current Demand Scheme Logic CURRENT DEMAND W1 CURRENT DEMAND FUNCTION Disabled Range Enabled Disabled MESSAGE W1 CURRENT DEMAND TARGET Self Reset Range Self Reset Latched None MESSAGE W1 CURRENT DEMAND PICKUP 100 A Range 0 to 65000 in steps of 1 auto ranging MESSAGE W1 CURRENT DEMAND BLOCK Disabled Range Logc Inpt 1 to 16...

Page 158: ...ormer cooling system has failed and an over temperature condition exists The logic input should be connected to the transformer winding temperature alarm contacts FIGURE 5 44 Transformer Overload Scheme Logic XFORMER OVERLOAD TRANSFORMER OVERLOAD FUNCTION Disabled Range Enabled Disabled MESSAGE TRANSFORMER OVERLOAD TARGET Self Reset Range Self Reset Latched None MESSAGE TRANSFORMER OVERLOAD PICKUP...

Page 159: ...oint group would be programmed through the FlexLogic This approach would be useful if very sensitive settings had been used in the normal in service Setpoint group for the Harmonic Restrained Differential element assuming that the tap changer position was used to compensate the input current magnitude FIGURE 5 45 Tap Changer Failure Scheme Logic TAP CHANGR FAILURE TAP CHANGER FAILURE FUNCTION Disa...

Page 160: ...te the output or 0 OFF i e do not operate the output The table below provides information about FlexLogic equations for all outputs As mentioned above the parameters of an equation can contain either INPUTS or GATES Table 5 10 FlexLogic Output Types Name Type Equation Parameters Evaluation Rate Output Relay 1 solid state 20 every 1 2 cycle Output Relays 2 to 5 trip rated form A contacts 20 each ev...

Page 161: ...wing the FlexLogic messages for Output Relay 2 On the right of the stack of boxes is an illustration of how the equation is interpreted In this example the inputs of the 4 input OR gate are Percent Diff OP Inst Diff OP the output of the XOR gate and the output of the AND gate The inputs of the 2 input AND gate are the output of the NOT gate and Output Relay 2 The input to the NOT gate is Logic Inp...

Page 162: ...til a reset command is issued or automatically after one week Select Self reset to automatically de energize the contacts after the condition is cleared The solid state output Output 1 remains closed until externally reset by a momentary interruption of current unless wired in parallel with an electromechanical relay Outputs 2 to 8 in which case it turns off when the relay operates OUTPUT 1 8 TYPE...

Page 163: ...quation for Output 1 8 as described in the introduction to FlexLogic FIGURE 5 48 Output Relays Scheme Logic Table 5 13 Output Relay Default FlexLogic FlexLogic Gate Output Relay Number 1 to 3 4 5 6 7 8 01 Percent Diff OP Volts Hertz 1 OP W1 THD Level OP Underfreq 1 OP Underfreq 2 OP Freq Decay 3 OP 02 Inst Diff OP Volts Hertz 2 OP W2 THD Level OP Freq Decay R1 OP Freq Decay R2 OP END 03 Any W1 OC ...

Page 164: ...rammable This section contains the settings including the FlexLogic equation to configure trace memory triggering NO OF PRE TRIGGER CYCLES Enter the number of cycles of data of the 16 cycles of waveform data to be captured that are to be pre trigger information TRACE TRIG FLEXLOGIC 01 to 10 The following 10 messages are the parameters of the FlexLogic equation for trace memory triggering as descri...

Page 165: ...ted will start Timer 1 10 TIMER 1 10 PICKUP DELAY Enter the delay time during which the start condition for Timer 1 10 must remain operated or asserted before the timer will operate TIMER 1 10 DROPOUT DELAY Enter the delay time after which the start condition for Timer 1 10 must remain not operated or not asserted before the timer will stop operating S6 Testing Description The 745 provides various...

Page 166: ...feature is enabled Analog Outputs PATH SETPOINTS S6 TESTING ANALOG OUTPUTS The 745 has the ability to override the normal function of analog transducer outputs forcing each to any level of its output range Enabling this feature turns the TEST MODE indicator on and de energize the self test relay FORCE ANALOG OUTPUT FUNCTION Select Enabled to enable the analog output testing and override the analog...

Page 167: ...ts are replaced with sample values generated based on the programmed prefault values Phase currents are balanced i e equal in magnitude and 120 apart and the phase lag between windings is that which would result under normal conditions for the transformer type selected The magnitude of phase cur rents for each winding are set to the values programmed in S6 TESTING SIMULATION PREFAULT VALUES W1 3 P...

Page 168: ...ote that the default setting blocks the operation of all output relays START FAULT MODE SIGNAL Select any logic input which when asserted initiates Fault Mode simulation This signal has an effect only if the 745 is initially in Prefault Mode START PLAYBACK MODE SIGNAL Select any logic input which when asserted initiates Playback Mode simulation This signal has an effect only if the 745 is initiall...

Page 169: ... C CURRENT ANGLE 0 Range 0 to 359 in steps of 1 MESSAGE W2 GROUND CURRENT MAGNITUDE 0 0 x CT Range 0 0 to 40 0 x CT in steps of 0 1 MESSAGE W2 GROUND CURRENT ANGLE 0 Range 0 to 359 in steps of 1 MESSAGE W3 PHASE A CURRENT MAGNITUDE 1 0 x CT Range 0 0 to 40 0 x CT in steps of 0 1 MESSAGE W3 PHASE A CURRENT ANGLE 0 Range 0 to 359 in steps of 1 MESSAGE W3 PHASE B CURRENT MAGNITUDE 1 0 x CT Range 0 0 ...

Page 170: ... C CURRENT ANGLE 0 Range 0 to 359 in steps of 1 MESSAGE W2 GROUND CURRENT MAGNITUDE 0 0 x CT Range 0 0 to 40 0 x CT in steps of 0 1 MESSAGE W2 GROUND CURRENT ANGLE 0 Range 0 to 359 in steps of 1 MESSAGE W3 PHASE A CURRENT MAGNITUDE 1 0 x CT Range 0 0 to 40 0 x CT in steps of 0 1 MESSAGE W3 PHASE A CURRENT ANGLE 0 Range 0 to 359 in steps of 1 MESSAGE W3 PHASE B CURRENT MAGNITUDE 1 0 x CT Range 0 0 ...

Page 171: ...ent magnitude in terms of the winding FLC while in Fault Mode Note that ground refers to the measured CT current in the connection between transformer neutral and ground As such this message only appears for wye or zig zag connected windings W1 3 GROUND CURRENT ANGLE Enter the Winding 1 3 ground current angle with respect to the Winding 1 Phase A current phasor This message only appears for wye or...

Page 172: ...S6 Testing 745 Transformer Management Relay Setpoints http www GEindustrial com multilin 5 98 GE Multilin ...

Page 173: ...Rear RS485 RS422 COM 1 port or RS485 COM 2 port with any system running user written software Any of these methods can be used to view the same information A computer however makes viewing much more convenient since more than one piece of information can be viewed at the same time ACTUAL VALUES A1 STATUS DATE AND TIME See page 6 3 MESSAGE LOGIC INPUTS See page 6 3 MESSAGE VIRTUAL INPUTS See page 6...

Page 174: ...OF LIFE See page 6 12 MESSAGE ANALOG INPUT See page 6 12 MESSAGE POWER See page 6 12 MESSAGE ENERGY See page 6 12 MESSAGE END OF PAGE A2 MESSAGE ACTUAL VALUES A3 EVENT RECORDER EVENT DATA CLEAR See page 6 13 MESSAGE EVENT 128 See page 6 14 MESSAGE EVENT 127 See page 6 14 MESSAGE EVENT 1 See page 6 14 MESSAGE END OF PAGE A3 MESSAGE ACTUAL VALUES A4 PRODUCT INFO TECHNICAL SUPPORT See page 6 16 MESSA...

Page 175: ...relay during manufacture For example no display associated with Winding 3 will ever appear if the relay is not configured for three winding operation A1 Status Date and Time PATH ACTUAL VALUES A1 STATUS DATE AND TIME The current date and time are displayed here Logic Inputs PATH ACTUAL VALUES A1 STATUS LOGIC INPUTS The states of Logic Inputs 1 through 16 and the setpoint access jumper are displaye...

Page 176: ...here Self Test Errors PATH ACTUAL VALUES A1 STATUS SELF TEST ERRORS The FLEXLOGIC EQN ERROR value displays the source of the error occurring in a FlexLogic equation The BAD SETTINGS ERROR value displays the cause of a bad setting made while assigning setpoint values OUTPUT RELAYS OUTPUT RELAY 1 STATE De energized MESSAGE OUTPUT RELAY 8 STATE De energized MESSAGE SELF TEST RELAY STATE Energized VIR...

Page 177: ...e are displayed and updated approximately twice a second for readability b Winding Currents PATH ACTUAL VALUES A2 METERING CURRENT W1 3 CURRENT CURRENT W1 CURRENT See below MESSAGE W2 CURRENT See below MESSAGE W3 CURRENT See below MESSAGE POSITIVE SEQUENCE See page 6 6 MESSAGE NEGATIVE SEQUENCE See page 6 6 MESSAGE ZERO SEQUENCE See page 6 6 MESSAGE DIFFERENTIAL See page 6 7 MESSAGE RESTRAINT See ...

Page 178: ...positive sequence current magnitudes and phase values for Windings 1 2 and 3 are shown here d Negative Sequence Current PATH ACTUAL VALUES A2 METERING CURRENT NEGATIVE SEQUENCE The negative sequence current magnitudes and phase values for Windings 1 2 and 3 are shown here e Zero Sequence Current PATH ACTUAL VALUES A2 METERING CURRENT ZERO SEQUENCE The zero sequence current magnitudes and phase val...

Page 179: ...tial Current PATH ACTUAL VALUES A2 METERING CURRENT GROUND DIFFERENTIAL The ground differential current magnitudes for Windings 1 through 3 are shown DIFFERENTIAL PHASE A DIFFERENTIAL CURRENT 0 00 x CT MESSAGE PHASE A DIFFERENTIAL ANGLE 0 Lag MESSAGE PHASE B DIFFERENTIAL CURRENT 0 00 x CT MESSAGE PHASE B DIFFERENTIAL ANGLE 0 Lag MESSAGE PHASE C DIFFERENTIAL CURRENT 0 00 x CT MESSAGE PHASE C DIFFER...

Page 180: ...HARMONIC The 745 is capable of measuring harmonic components up to a frequency of 21 times nominal system frequency An actual value is calculated for each phase of each monitored winding The example above shows what is displayed in a typical case for harmonic components in this case the second harmonic Similar displays exist for all harmonics up to the 21st The second harmonic magnitude for each p...

Page 181: ...ency band in terms of harmonic number over which THD is being calculated d Harmonic Derating Factor PATH ACTUAL VALUES A2 METERING HARMONIC CONTENT HARMONIC DERATING The Harmonic Derating Factor for each of the windings shows the effect of non sinusoidal load currents on power transformer s rated full load current The calculations are based on ANSI IEEE standard C57 110 1986 The actual values mess...

Page 182: ...ETERING VOLTAGE For phase to neutral input voltages the SYSTEM LINE TO LINE VOLTAGE displays its line to line equivalent Demand a Main Menu PATH ACTUAL VALUES A2 METERING HARMONIC CONTENT Current demand is measured on each phase of each monitored winding These parameters can be monitored to reduce supplier demand penalties or for statistical metering purposes The calculated demand is based on the ...

Page 183: ...urrent demand the phase in which it occurred and the date and time it occurred are also shown If the date has never been programmed the default values shown above appear These messages are repeated for Windings 2 and 3 Ambient Temperature PATH ACTUAL VALUES A2 METERING AMBIENT TEMPERATURE Ambient temperature is monitored via an RTD connected to the 745 DEMAND DATA CLEAR MAX DEMAND DATA No MESSAGE ...

Page 184: ...UT ANALOG INPUT UNITS are displayed instead of µA which is the factory default Power PATH ACTUAL VALUES A2 METERING POWER W1 3 POWER The 745 calculates and displays real reactive and apparent power as well as the power factor for all of the available windings providing that the voltage sensing is enabled Power flowing into the power transformer is designated as source power and power flowing out o...

Page 185: ... VALUES A3 EVENT RECORDER EVENT DATA CLEAR Enter Yes for the CLEAR EVENT DATA RECORDER to clear all event recorder data The CLEAR EVENT RECORDER SIGNAL actual value assigns a Logic Input to be used for remote clearing of the event recorder The last date and time the demand data were cleared are also displayed If the date has never been programmed the default values shown above appear ENERGY DATA C...

Page 186: ...ag MESSAGE W1 ƒo H2a 0 0 H2b 0 0 H2c 0 0 MESSAGE W1 ƒo H5a 0 0 H5b 0 0 H5c 0 0 MESSAGE W2 PHASE A CURRENT 0 A at 0 Lag MESSAGE W2 PHASE B CURRENT 0 A at 0 Lag MESSAGE W2 PHASE C CURRENT 0 A at 0 Lag MESSAGE W2 GROUND CURRENT 0 A at 0 Lag MESSAGE W2 ƒo H2a 0 0 H2b 0 0 H2c 0 0 MESSAGE W2 ƒo H5a 0 0 H5b 0 0 H5c 0 0 MESSAGE W3 PHASE A CURRENT 0 A at 0 Lag MESSAGE W3 PHASE B CURRENT 0 A at 0 Lag MESSAG...

Page 187: ...ble 6 1 Types and Causes of Events PICKUP OPERATE DROPOUT Events Percent Differential Inst Differential W1 Phase Time OC W2 Phase Time OC W3 Phase Time OC W1 Phase Inst OC 1 W2 Phase Inst OC 1 W3 Phase Inst OC 1 W1 Phase Inst OC 2 W2 Phase Inst OC 2 W3 Phase Inst OC 2 W1 Neutral Time OC W2 Neutral Time OC W3 Neutral Time OC W1 Neutral Inst OC 1 W2 Neutral Inst OC 1 W3 Neutral Inst OC 1 W1 Neutral ...

Page 188: ... Input 13 Virtual Input 14 Virtual Input 15 Virtual Input 16 Output Relay 1 Output Relay 2 Output Relay 3 Output Relay 4 Output Relay 5 Output Relay 6 Output Relay 7 Output Relay 8 Self Test Relay Virtual Output 1 Virtual Output 2 Virtual Output 3 Virtual Output 4 Virtual Output 5 Setpoint Group 1 Setpoint Group 2 Setpoint Group 3 Setpoint Group 4 Test Mode Simulation Disabled Simulation Prefault ...

Page 189: ...eys If no key is pressed the next target message in the queue will be displayed after a delay of four seconds This process repeats continuously cycling through the queue of target messages As long as there is at least one message in the queue the Message LED will remain lit Pressing any key other than MESSAGE or MESSAGE will return the display to the setpoint or actual value message that was previ...

Page 190: ... the target messages but the conditions that caused the LATCHED messages to be displayed originally are no longer present The bottom line of the display i e CAUSE will be the name of the element that has been activated These are as follows LATCHED a Percent Differentl STATUS PHASE CAUSE Table 6 2 Target Message Causes Percent Differentl Inst Differential W1 Phase Time OC W2 Phase Time OC W3 Phase ...

Page 191: ...after power up and continuously thereafter in a background task The tests ensure that every testable unit of the hardware is functioning correctly ANY SELF TEST ERROR INDICATES A SERIOUS PROBLEM REQUIRING SERVICE Major Self Test Errors Upon detection of a major self test error the 745 disables all protection functionality turns on the front panel Self Test Error LED turns off the front panel In Se...

Page 192: ...nd Analog Output Minor This error is caused by failure of the 32 V DC power supply used to power analog outputs Analog output currents are affected by this failure Not Calibrated Minor This error message appears when the 745 determines that it has not been calibrated Although the relay is fully functional the accuracy of measured input values e g currents and line voltage as well as generated outp...

Page 193: ...the prompt PLEASE RE ENTER NEW PASSCODE is different from the one entered at the prompt PLEASE ENTER A NEW PASSCODE the 745 will not store the entered passcode and display this flash message INPUT FUNCTION IS ALREADY ASSIGNED This flash message is displayed under certain conditions when attempting to assign logic input functions under S3 LOGIC INPUTS Only the Disabled and To FlexLogic functions ca...

Page 194: ...ge is displayed removes the default message PRESSED KEY IS INVALID HERE This flash message is displayed in response to any pressed key that has no meaning in the current context RESETTING LATCHED CONDITIONS This flash message is displayed in response to pressing RESET when the relay is in local mode All active targets for which the activating condition is no longer present will be cleared SETPOINT...

Page 195: ... as follows GENERAL outlines safety precautions conventions used in the test procedures TEST EQUIPMENT the test equipment required GENERAL PRELIMINARY WORK LOGIC INPUTS AND OUTPUT RELAYS tests all digital and analog inputs the A D data acquisition system and relay and transistor outputs DISPLAY METERING COMMUNICATIONS ANALOG OUTPUTS tests all values derived from the AC current and voltage inputs P...

Page 196: ...T THE CONTROL POWER APPLIED TO THE RELAY AND THE AC CURRENT AND VOLTAGE INPUTS MATCH THE RATINGS SPECIFIED ON THE RELAY NAMEPLATE DO NOT APPLY CURRENT TO THE CT INPUTS IN EXCESS OF THE SPECIFIED RATINGS ENSURE THAT THE LOGIC INPUT WET CONTACTS ARE CONNECTED TO VOLTAGES BELOW THE MAXIMUM VOLTAGE SPECIFICATION OF 300 V DC Conventions The following conventions are used for the remainder of this chapt...

Page 197: ...ble power resistors to control current amplitude Ten turn 2 KΩ low power potentiometer Power rectifier to build a circuit to generate 2nd harmonics Accurate timing device Double pole single throw contactor suitable for at least 40 amperes AC Combined fundamental and 5th harmonic adjustable current supply for elements involving the 5th harmonic Variable frequency source of current or voltage to tes...

Page 198: ...atches relay nameplate Turn the auxiliary supply ON 10 Verify that all grounding connections are correctly made To facilitate testing it is recommended that all functions be initially set to Disabled Every feature which will be used in the application should be set per desired settings enabled for the specific commissioning test for the feature then returned to Disabled at completion of its test E...

Page 199: ...t Relay Commissioning http www GEindustrial com multilin 7 5 GE Multilin FIGURE 7 2 Testing for Dielectric Strength Logic Inputs and Output Relays Logic Inputs The dry and wet contact connections are shown below FIGURE 7 3 Logic Inputs GE Power Management g ...

Page 200: ...he relay is in test mode and no longer in service In test mode all output relays can be controlled manually 2 Under S6 TESTING OUTPUT RELAYS set the FORCE OUTPUT 1 to FORCE OUTPUT 8 setpoints to De energized 3 Using a multimeter check that all outputs are de energized For outputs 2 to 5 the outputs are dry N O contacts and for Outputs 6 to 8 the outputs are throw over contacts form C Output 1 is a...

Page 201: ...d be zero or equal to distortion of input current 6 Verify frequency shown in A2 METERING FREQUENCY SYSTEM FREQUENCY It should be 60 or 50 Hz as per frequency of input current on Phase A 7 To verify the positive and negative sequence component values apply the current signal to Phase A of each winding in series Read the values of positive and negative sequence current displayed by the relay where ...

Page 202: ...nes examine the CT ratios the transformer voltage ratios the transformer phase shift etc and apply correction factors to match the current signals under steady state conditions Consider the case of a Y D30 power transformer with the following data using a 1 A CT secondary rating for the relay Winding 1 100 MVA 220 kV 250 1 CT ratio rated current is 262 4 A hence CT ratio of 250 1 Winding 2 100 MVA...

Page 203: ...ed from the Delta side winding currents the Winding 2 current values will change under unbalanced conditions Consider the case described above with the 1 CT injected into Phase A of Winding 2 For the 1 CT current the zero sequence value is 1 3 of 1 0 CT or 0 333 CT A The value for IW2a is therefore 1 0 0 333 CT 0 6667 CT A This value must be divided by the CT error correction factor of 0 797 as de...

Page 204: ... values View the measured values in A2 METERING AMBIENT TEMP AMBIENT TEMPERATURE Refer to RTD tables included in this manual for calibration of resistance versus temperature c Ambient Temperature by Monthly Averages 1 If the ambient temperature is entered as 12 monthly averages program the value for the month during which the relay is being commissioned 2 Examine the A2 METERING AMBIENT TEMP AMBIE...

Page 205: ...ism The tap position is displayed in A2 METERING TAP CHANGER TAP CHANGER POSITION 3 Adjust the resistance to simulate the minimum tap position and verify that a 1 is displayed Now gradually increase the resistance up to the value which represents the maximum tap value verifying that the tap position indicator tracks the resistance Protection Schemes Precautions Keep track of modifications changes ...

Page 206: ...Transformer Types on page 5 11 6 For the phase shift shown for the particular set of vectors determine the processing applied to the current vectors for that winding from Table 5 2 Phase Shifts on page 5 23 7 Calculate the dashed current values using the equations in Table 5 2 Phase Shifts on page 5 23 If applicable use the zero sequence removal computation This is applicable for all Delta winding...

Page 207: ...these relays operate whenever the relay is in a trip condition Ensure that the current though the auxiliary coils is interrupted by an external contactor between each test 2 To avoid operating the breaker during the commissioning process when the solid state output operates the breaker directly use the circuit shown below to verify this output Whenever the relay is in a trip state current flows th...

Page 208: ...the relay as shown in the fig ure below FIGURE 7 6 Current Signal Connections 2 If I1 1 5 CT and I2 0 the element is operated as all the current appears as a differential current 3 The slope is calculated from the values of Idifferential and Irestraint as follows EQ 7 11 4 Slowly increase I2 As I2 is increased the element will reset when the differential current drops below the minimum pickup 5 As...

Page 209: ...nt at which the slope changed in value Keep in mind the effects of auto configuration on the magnitude of the current signal fed to the differential elements when conducting the slope kneepoint test i 2nd Harmonic Restraint To measure the percentage of second harmonic required to block the operation of the harmonic restraint differential elements use the connection diagram shown below Current is s...

Page 210: ... element operates 4 Calculate the percentage 5th harmonic to restrain from the following equation EQ 7 14 5 Compare this value to the relay setting k Energization Detection Scheme Refer to Differential Element on page 5 41 for a description of this feature This feature is activated by up to three inputs breaker auxiliary switch current below a threshold or absence of voltage The procedure below te...

Page 211: ...evel of the Phase A element is measured by applying an AC cur rent to terminals H1 and G1 Monitor the appropriate trip and auxiliary con tact s as the current is increased from 0 A Due to the auto configuration feature it may be easier to read the actual differential current on the relay rather computing it Compare the value of the differential current at which oper ation is detected against the S...

Page 212: ...the relay elements are set for a Linear reset characteristic when measuring the operating times ensure that there is sufficient time between test current injections for the element to reset fully otherwise erroneous timing measurements will be obtained The settings for these elements are found in the S4 ELEMENTS PHASE OVERCURRENT setpoints page b Winding 1 Elements To ensure that only the Phase Ti...

Page 213: ...ible triggering To perform such a test please contact GE Multilin for detailed test instructions A simple verification the selected reset mode can be obtained using FIGURE 7 9 General Test Setup on page 7 18 The procedure consists of performing repetitive operating time measurements in quick succession If the reset is selected for instantaneous the operating time will always be equal to the nomina...

Page 214: ...uld be 97 of the operate level When the element resets the Trip and Phase LEDs should remain on if the W1 PHASE INST OC 1 TARGET was selected as Latched Otherwise only the Trip LED should stay on 4 Reset indicators and clear messages d Operating Time Using the setup shown in FIGURE 7 9 General Test Setup on page 7 18 and the Interval Timer enabled set the current level to 1 5 times the operating l...

Page 215: ...tude until the trip relay and all the selected auxiliary relays operate 2 If the relay under test has a very inverse time characteristic it is easier and more accurate to increase the current far above the pickup level until the trip relay operates then reduce the current to just above the expected operate level Slowly reduce the current below the operate level and observe for a reset action on th...

Page 216: ...rrent signal to X H4 and Y G4 and repeat tests in this section To test Winding 3 elements disable all protection elements except for W3 NEUTRAL TIME OVERCURRENT Connect the current signal to X H7 and Y G7 and repeat the tests in this section The blocking from logic input if enabled can be tested as described in earlier tests for other elements Neutral Instantaneous Overcurrent 1 a Description This...

Page 217: ...ently the same test procedure can be used to verify their correct operation Disable all protection features except Neutral Instantaneous Overcurrent 2 and follow the steps in the previous section making the appropriate changes for the LEDs and output relays operated by the Neutral Instantaneous Overcurrent 2 elements Ground Time Overcurrent a Description This procedure verifies that the Ground Tim...

Page 218: ... which the timing is to be measured Enter the expected operating times from the timing curve applied in the settings Using FIGURE 7 9 General Test Setup on page 7 18 with the Interval Timer enabled set the current level to the desired value and apply suddenly by closing the double pole switch Record the operate time and compare to the expected value Repeat for the all the desired values of current...

Page 219: ... c Pickup Level 1 With the interval timer disabled apply the current signal and increase its mag nitude until the trip relay and all the selected auxiliary relays operate Com pare the measured operating level against the S4 ELEMENTS GROUND OC W1 GND INST OC 1 W1 GND INST OC 1 PICKUP setpoint 2 When the element operates check that the Trip and Message LEDs are flashing and one of the following mess...

Page 220: ...terminals FIGURE 7 10 Fault Current Distribution due to an External Phase to Ground Fault on Winding 2 The procedure for this test is shown below 1 Select the D Y30 transformer type into the relay and set the same CT ratio for both phase and ground winding inputs The selected transformer type assures the G1 2 ground input is associated to Winding 2 Wye 2 Enable the RGF protection only and monitor ...

Page 221: ...rent element Monitor the appropriate output relays as per the relay FlexLogic settings FIGURE 7 11 Restricted Ground Test Setup c Pickup Level 1 With the interval timer disabled apply the current signal feeding the phase cur rent element and increase its magnitude slowly until the trip relay and all the selected auxiliary relays operate The operate level should correspond to the S4 ELEMENTS RESTRI...

Page 222: ... Restricted Ground Fault element Connect the ground current signal to Terminals F12 and E12 Repeat all the tests described for the Winding 1 element in this section The blocking from logic input if enabled can be tested as described in earlier tests for other elements Negative Sequence Time Overcurrent a Description This procedure verifies that the Negative Sequence Time Overcurrent performance ma...

Page 223: ... Trip LED remains on Reset indicators and clear messages d Operating Time Using a table like the one shown below select 3 or 4 values of current multiples at which the timing is to be measured Enter the expected operating times from the timing curve applied in the settings Using the setup in FIGURE 7 9 General Test Setup on page 7 18 with the Interval Timer enabled set the current level to the des...

Page 224: ... 18 Connect the current supply to terminals X H1 and Y G1 to test the Winding 1 element Monitor the appropriate output relays as per the relay FlexLogic settings c Pickup Level 1 With the interval timer disabled apply the current signal and increase its mag nitude until the trip relay and all selected auxiliary relays operate Compare the measured operating level against the S4 ELEMENTS NEG SEQ OC ...

Page 225: ...abled it may be necessary to inject a current signal into Winding 1 Phase A if the current supervision is enabled or else the detectors will not operate FIGURE 7 12 Frequency Element Testing b Underfrequency 1 As a preliminary step disable all protection functions except Underfrequency 1 Verify that settings match the in service requirements Settings are entered or modified in the S4 ELEMENTS FREQ...

Page 226: ...tage to rated VT secondary value the current to rated CT secondary and the pre trigger frequency to the nominal frequency 60 or 50 Hz If current sensing is not enabled it is not necessary to connect the current signal 13 Set the post trigger to 0 5 Hz below the setting for Underfrequency 1 Reset all targets and relays if necessary Reset the timer 14 Initiate the frequency step and timer start The ...

Page 227: ...c input if enabled can be tested as described in earlier tests for other elements c Underfrequency 2 1 Disable all protection functions except the Underfrequency 2 function 2 Verify that settings match in service requirements Enter modify settings and logic in the S4 ELEMENTS FREQUENCY UNDERFREQUENCY 2 setpoints menu 3 Repeat the appropriate steps of Underfrequency 1 on page 7 31 for this element ...

Page 228: ...ent 11 Set the post trigger to 0 5 Hz above the setting of the Overfrequency element If necessary reset all targets and relays Reset the timer 12 Initiate the frequency step and timer start The Interval Timer records the operating time of element Compare this time to the S4 ELEMENTS FREQUENCY OVERFREQUENCY DELAY setting 13 Provided that the operate times are not scattered over a wide range it may ...

Page 229: ...It is the experience of GE Multilin that some commercial dedicated relay test equipment with built in frequency ramping functions is not accurate enough to verify the 745 performance Disable all protection functions except the Frequency Decay function Verify that settings match in service requirements The settings are entered and modified in the S4 ELEMENTS FREQUENCY FREQUENCY DECAY setpoints menu...

Page 230: ...hold if the relay is to operate Note that operation occurs if the rate criterion is satisfied and the frequency is below the threshold 3 Initiate ramping action and verify that the element operates once the frequency drops below the threshold 4 Check that the Trip and Pickup LEDs are on and one of the following trip messages is displayed LATCHED Freq Decay Rate 1 or OPERATED Freq Decay Rate 1 If t...

Page 231: ... the setting of the element 4 Check that the Trip Pickup and if selected Alarm LEDs are on and one of the following is displayed LATCHED 5th Harmonic Level or OPERATED 5th Harmonic Level 5 Reduce the 5th harmonic component until the element resets The reset level should be 97 of the operate level Reset indicators and clear messages 6 Repeat the above steps with a fundamental current level below th...

Page 232: ...e monitor circuit Connect a resistance to simulate the tap changer resistance and increase this resistance until the element operates Calculate that the resistance at which the element operated is 150 of the resistance that would be present at the maximum tap position Verify all relay targets and messages for correct operation per programmed values Auxiliary Protection and Monitoring Functions THD...

Page 233: ...sformer parameters such as Load Losses at Rated Load and Winding Resistance be entered This feature makes use of the Harmonic Derating Factor HDF computed by the relay using the harmonic content of the current signals and the transformer data refer to IEEE C57 110 1986 for the computation method Once the derating factor falls below a set value the 745 can trip and or alarm b Operating Level 1 To v...

Page 234: ...ER OVERLOAD DELAY setting The blocking from logic input if enabled can be tested as described in earlier tests for other elements Placing the Relay Into Service Precautions The procedure outlined in this section is explicitly concerned with the 745 relay and does not include the operation commissioning or placing into service of any equipment external to the 745 Users should have already performed...

Page 235: ...to the 745 Manual MANUAL P N REVISION RELEASE DATE ECO 1601 0161 A1 3 0x July 2 2004 Table A 1 Major Updates for 745 Manual Revision A1 PAGE B5 PAGE A1 CHANGE DESCRIPTION Title Title Update Manual part number to 1601 0161 A1 7 1 Remove Removed Communications chapter It will be made available separately as GE publication GEK 106636 745 Communications Guide ...

Page 236: ... EN 50082 2 1997 Electromagnetic Compatibility Requirements Part 2 Industrial Environment IEC100 4 3 EN 61000 4 3 Immunity to Radiated RF EN 61000 4 6 Immunity to Conducted RF Manufacturer s Name General Electric Multilin Inc Manufacturer s Address 215 Anderson Ave Markham Ontario Canada L6E 1B3 Manufacturer s Representative in the EU Christina Bataller Mauleon GE Multilin Avenida Pinoa 10 48710 Z...

Page 237: ...ctive and it is returned with all transportation charges prepaid to an authorized service centre or the factory Repairs or replacement under warranty will be made without charge Warranty shall not apply to any device which has been subject to misuse negligence accident incorrect installation or use not in accordance with instructions nor any unit that has been altered outside a GE Multilin authori...

Page 238: ...GE Multilin Warranty 745 Transformer Management Relay Appendix http www GEindustrial com multilin 8 4 GE Multilin ...

Page 239: ...tions 7 2 preliminary work 7 4 test equipment 7 2 COMMUNICATIONS dnp 5 26 RS232 3 14 4 7 4 11 4 13 RS422 3 13 3 14 RS485 3 13 4 8 4 11 4 13 setpoints 5 25 5 26 wiring 4 7 4 8 CONDITIONS 4 3 CONTACT INFORMATION 1 1 CONTROL POWER 3 11 CT INPUTS 3 9 CURRENT DEMAND setpoints 5 83 CURVES definite time 5 50 FlexCurves 5 50 IAC 5 53 IEC 5 52 IEEE 5 51 types 5 50 D DEFAULT MESSAGES 5 27 DEFINITE TIME CURV...

Page 240: ...4 9 IEEE CURVES 5 51 IN SERVICE INDICATOR 4 2 INDICATORS see LEDs and entries for individual indicators INPUTS AC voltage 3 10 commissioning 7 6 specifications 2 4 INSERTION 3 3 INSPECTION CHECKLIST 1 1 INSTALLATION setpoints 1 7 5 29 INSTANTANEOUS DIFFERENTIAL setpoints 5 48 testing 7 17 INSULATION AGING 7 37 setpoints 5 78 INVERSE CURVE 1 5 73 IRIG B 3 15 K KNEEPOINT 7 15 L LEDs alarm 4 3 descri...

Page 241: ... 5th harmonic 5 71 7 37 energization detection 7 16 features 2 2 frequency decay 5 68 frequency decay rate 7 35 ground instantaneous o c 5 60 ground instantaneous overcurrent 7 25 7 26 ground time o c 5 59 ground time overcurrent 7 23 harmonic restrained percent differential 7 11 instantaneous differential 5 48 7 17 insulation aging 7 37 negative sequence instantaneous o c 5 66 negative sequence i...

Page 242: ... 3 T TAP CHANGER FAILURE 5 85 TAP MONITOR FAILURE 7 38 TAP POSITION 7 11 TAP POSITION INPUT 3 11 5 6 TARGET MESSAGES 6 17 TEMPERATURE ambient 5 35 7 9 7 10 RTD 7 10 TEST MODE INDICATOR 4 2 TEST SETUP 7 18 TEXT SETPOINTS 1 6 THD LEVEL setpoints 5 76 testing 7 38 TIME DELAYS 5 40 TIMERS 5 91 TOC CURVES IAC 5 53 IEC 5 52 TRACE MEMORY 5 90 TRANSFORMER 5 30 TRANSFORMER DE ENERGIZED INDICATOR 4 3 TRANSF...

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