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GE Feeder Management Relay 750, Instruction Manual

The GE Feeder Management Relay 750 is an advanced device designed to effectively manage power distribution systems. Enhance your understanding of this sophisticated product with the comprehensive Instruction Manual available for free download on our website. Unlock its full potential by accessing the manual at 88.208.23.73:8080.

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5-96

750/760 Feeder Management Relay

GE Multilin

5.8 S7 CONTROL

5 SETPOINTS

5

5.8S7 CONTROL

5.8.1 SETPOINT GROUPS

PATH: SETPOINTS 

ÖØ

 S7 CONTROL 

Ö

 SETPOINT GROUPS

All setpoints contained under the 

S5 PROTECTION

 setpoints page are reproduced in four groups, identified as Groups 1, 2, 3,

and 4. These multiple setpoints provide the capability of both automatic and manual changes to protection settings for dif-
ferent operating situations. Automatic (adaptive) protection setpoint adjustment is available to change settings when the
power system configuration is altered. By monitoring the state of a bus tie breaker on the bus connected to the associated
feeder breaker, different settings may be used depending the tie breaker state. Automatic group selection can be initiated
by use of a logic input. The manual adjustment capability is available for those users who use different settings for different
seasons of the year. Manual group selection can be initiated from the keypad or via communications.

In order to allow the display and editing of one group while another group is used for protection, two operating states have
been assigned to setpoint groups. The "Active Group" is used for protection, and is indicated by the appropriate faceplate
LED indicator being turned on continuously. The 'Edit' group is displayed and may be used to alter protection settings. It is
indicated by the appropriate faceplate LED indicator being flashed. If a single group is selected to be both the Active and
Edit group, the appropriate indicator is on continuously.

The setpoint group to be edited is selected through the 

EDIT SETPOINT GROUP

 setpoint. Group 1 is the default for the "Active

Group" and will be used unless another group is requested to become active. The active group can be selected with the

ACTIVE SETPOINT GROUP

 setpoint or by logic input. If there is a conflict in the selection of the active group, between a set-

point and logic input, or between two logic inputs, the higher numbered group will be made active. For example, if the logic
inputs for Group 2, 3, and 4 are all asserted the relay would use Group 4. If the logic input for Group 4 then becomes de-
asserted, the relay will use Group 3. Any change from the default Group 1 will be stored in the event recorder.

In some application conditions, the user may require that the relay will not change from the present active group. This pre-
vention of a setpoint group change can be applied when any of the overcurrent (phase, neutral, ground, sensitive ground,
or negative sequence), overvoltage, bus or line undervoltage, or underfrequency elements are picked-up.

Pickup of a protection element is possible when selected to any function except "Disabled", so elements that are
not used to perform tripping can also inhibit setpoint changes. A setpoint change can also be prevented if the
breaker is open, so that a fault detected before a reclosure will not cause a group change while the breaker is open.

Each setpoint group includes the selection of Auxiliary Output Relays 3 to 7 that can be operated by the
protection features. As these relays are hard-wired to external equipment, the selection should only be
changed from that in setpoint Group 1 with considerable care.

„

 SETPOINT GROUPS

„

 [ENTER] for more

ACTIVE SETPOINT

GROUP: Group 1

Range: Group 1, Group 2, Group 3, Group 4

EDIT SETPOINT GROUP:

Active Group

Range: Group 1, Group 2, Group 3, Group 4, Active

Group

OPEN BRKR

INHIBIT: Disabled

Range: Enabled, Disabled

OVERCURRENT PICKUP

INHIBIT: Disabled

Range: Enabled, Disabled

OVERVOLTAGE PICKUP

INHIBIT: Disabled

Range: Enabled, Disabled

UNDERVOLTAGE PICKUP

INHIBIT: Disabled

Range: Enabled, Disabled

UNDERFREQ PICKUP

INHIBIT: Disabled

Range: Enabled, Disabled

ENTER

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Courtesy of NationalSwitchgear.com

Summary of Contents for Feeder Management Relay 750

Page 1: ...REAKER OPEN 1 TRIP TRIP BREAKER CLOSED 2 CLOSE ALARM RECLOSURE ENABLED 3 AUXILIARY PICKUP RECLOSURE DISABLED 4 AUXILIARY SETPOINT GROUP 1 SETPOINT GROUP 2 SETPOINT GROUP 3 SETPOINT GROUP 4 RECLOSURE IN PROGRESS 5 AUXILIARY RESET OPEN NEXT SETPOINT MESSAGE VALUE ACTUAL CLEAR STORE CLOSE RECLOSURE LOCKOUT 6 AUXILIARY LOCAL 7 AUXILIARY 8 PROGRAM PORT PROGRAM PORT REMOTE BREAKER SELF TEST WARNING 7 8 ...

Page 2: ...Courtesy of NationalSwitchgear com ...

Page 3: ...t Relays 2 11 2 2 9 CPU 2 11 2 2 10 Physical 2 12 2 2 11 Testing 2 12 2 2 12 Approvals 2 12 3 INSTALLATION 3 1 MECHANICAL 3 1 1 Drawout Case 3 1 3 1 2 Installation 3 2 3 1 3 Unit Withdrawal and Insertion 3 3 3 1 4 Rear Terminal Layout 3 5 3 2 ELECTRICAL 3 2 1 Typical Wiring 3 7 3 2 2 Phase Sequence and Transformer Polarity 3 8 3 2 3 Current Inputs 3 8 3 2 4 Voltage Inputs 3 11 3 2 5 Control Power ...

Page 4: ...sing 5 16 5 3 3 Line VT Sensing 5 17 5 3 4 Power System 5 17 5 3 5 FlexCurves 5 18 5 4 S3 LOGIC INPUTS 5 4 1 Overview 5 19 5 4 2 Logic Inputs Setup 5 19 5 4 3 Breaker Functions 5 21 5 4 4 Control Functions 5 22 5 4 5 User Inputs 5 22 5 4 6 Block Functions 5 23 5 4 7 Block Overcurrent Functions 5 24 5 4 8 Transfer Functions 5 25 5 4 9 Reclose Functions 760 Only 5 26 5 4 10 Miscellaneous Functions 5...

Page 5: ...IEW 6 1 1 Actual Values Main Menu 6 1 6 2 A1 STATUS 6 2 1 Virtual Inputs 6 5 6 2 2 Hardware Inputs 6 5 6 2 3 Last Trip Data 6 6 6 2 4 Fault Locations 6 7 6 2 5 Clock 6 7 6 2 6 Autoreclose 760 only 6 7 6 3 A2 METERING 6 3 1 Metering Conventions 6 8 6 3 2 Current 6 9 6 3 3 Voltage 6 10 6 3 4 Frequency 6 11 6 3 5 Synchronizing Voltage 6 11 6 3 6 Power 6 11 6 3 7 Energy 6 12 6 3 8 Demand 6 13 6 3 9 An...

Page 6: ... 8 3 8 2 INPUTS OUTPUTS 8 2 1 Logic Virtual Inputs 1 to 14 8 4 8 2 2 Virtual Inputs 15 to 20 8 8 8 2 3 Output Relays 8 9 8 3 METERING 8 3 1 Current Metering 8 10 8 3 2 Voltage Metering 8 10 8 3 3 Power Metering 8 12 8 3 4 Demand Metering 8 13 8 3 5 Analog Input Metering 8 15 8 4 PROTECTION SCHEMES 8 4 1 Setpoint Groups 8 16 8 4 2 Phase Overcurrent 8 16 8 4 3 Neutral Overcurrent 8 20 8 4 4 Ground O...

Page 7: ...dervoltage Restoration 8 44 8 6 6 Underfrequency Restoration 8 46 8 6 7 Transfer Scheme 8 47 8 6 8 Autoreclose 760 only 8 52 8 7 PLACING THE RELAY IN SERVICE 8 7 1 Description 8 56 8 7 2 On Load Testing 8 56 8 7 3 Dielectric Strength Testing 8 57 A APPENDIX A 1 RELAY MODS A 1 1 Reverse Power A 1 A 2 CONFORMITY A 2 1 EU Declaration of Conformity A 3 A 3 WARRANTY A 3 1 GE Multilin Warranty A 4 Court...

Page 8: ...vi 750 760 Feeder Management Relay GE Multilin TABLE OF CONTENTS Courtesy of NationalSwitchgear com ...

Page 9: ...path representation shows how to navigate menus and sub menus to get to a specific setpoint or value in the exam ple above LAST PHASE A CURRENT DMND The forward arrows indicate entering a new sub menu to arrive at a message the down arrows indicate scrolling through a sub menu to arrive at a message See 1 2 1 Menu Navigation on page 1 2 for an example of how to navigate setpoints and actual values...

Page 10: ...ess the key and the first sub page head ing for Page 2 of actual values appears Pressing the and keys will scroll the display up and down through the sub page headers 4 Press the key until the DMND sub page heading appears Press to display the messages in this sub page 5 Note that all heading messages have the symbol preceding them and that only some sub pages have a subsequent second sub page 6 P...

Page 11: ...method of changing the setpoint Help messages will automatically scroll through all messages currently appropriate c NUMERICAL SETPOINTS Each numerical setpoint has its own minimum maximum and step value associated with it These parameters define what is acceptable for the setpoint Two methods of editing and storing a numerical setpoint value are available The 750 760 numeric keypad works the same...

Page 12: ...pon detection of the initiating condition Output relay configuration type values are changed by using the 3 to 7 keys Each key toggles the display between the corresponding number and a hyphen 1 Move to the S5 PROTECTION ÖØ PHASE CURRENT Ö PHASE TIME O C 1 ÖØ PHASE TIME O C 1 RELAYS 3 7 setpoint mes sage 2 If an application requires the Phase TOC protection element to operate the 3 Auxiliary outpu...

Page 13: ...s you with a quick and convenient way of becoming familiar with the relay To start simply power on the unit and follow the instructions in this tutorial The example assumes the following system characteristics It also assumes that relay set points are unaltered from their factory default values Power System Data System 3Φ 4 wire Frequency 60 Hz Line Voltage 13 8 kV Maximum Current 600 A Control Sy...

Page 14: ...OLTAGE 66 4 V 13 8kV ø ø 7 97kV ø N 7 97kV 120 66 4 V VT RATIO 120 1 14 4 kV VTpri 120V VTsec Make the following change in the S2 SYSTEM SETUP ÖØ POWER SYSTEM setpoints page to reflect the power system NOMINAL FREQ 60 Hz c S3 LOGIC INPUTS SETPOINTS The S3 setpoints page is for entering the characteristics of the logic inputs In our example these characteristics are spec ified under the Control Sys...

Page 15: ...SE INST OC 2 FUNCTION Trip PHASE INST OC 2 PICKUP 16 83 x CT 10100 A pickup 600 A primary PHASE INST OC 2 DELAY 0 00 s PHASES REQUIRED FOR OPERATION Any Two For the Neutral Time Overcurrent 1 element enter the following values in the S5 PROTECTION ÖØ NEUTRAL CURRENT ÖØ NEUTRAL TIME OC 1 setpoints page NEUTRAL TIME OC 1 FUNCTION Trip NEUTRAL TIME OC 1 PICKUP 0 20 x CT 120 A pickup 600 A primary NEU...

Page 16: ...ay is in the Not Ready state Move to the S1 RELAY SETUP ÖØ INSTALLATION ÖØ 750 OPERATION setpoint message To put the relay in the Ready state press the key until the READY message is displayed and press Enter Yes at the ARE YOU SURE prompt The Relay In Service LED Indicator will now turn on and the Relay Not Ready diagnostic message will disappear 1 2 5 COMMISSIONING Extensive commissioning tests ...

Page 17: ... setpoints can be displayed altered stored and printed If settings are stored in a setpoint file they can be downloaded at any time to the front panel program port of the relay via a computer cable connected to the serial port of any personal computer A summary of the available functions and a single line diagram of protection and control features is shown below For a complete understanding of eac...

Page 18: ...rent Superv Bus Transfer Programmable Logic Inputs Multiple Setpoint Groups ANSI 27 47 50 51 59 67 81 25 50 55 79 81 MONITORING CONTROL Synchrocheck Phase Neutral Current Level Power Factor Autoreclose 760 only Overfrequency Breaker Open Close Manual Close Feature Blocking Cold Load Pickup Feature Blocking Breaker Operation Failure Trip Close Circuit Failure Total Breaker Arcing Current VT Failure...

Page 19: ...ynchronized to the Va x voltage zero cross ing which results in better co ordination for multiple 750 760 relays on the same bus If a stable frequency signal is not available then the sampling rate defaults to the nominal system frequency PHASORS TRANSIENTS AND HARMONICS Current waveforms are processed once every cycle with a DC Offset Filter and a Fast Fourier Transform FFT to yield pha sors at t...

Page 20: ...2 4 750 760 Feeder Management Relay GE Multilin 2 1 OVERVIEW 2 INTRODUCTION 2 Figure 2 3 HARDWARE BLOCK DIAGRAM Courtesy of NationalSwitchgear com ...

Page 21: ...75 100 150 200 250 300 350 400 500 600 750 1000 ratios 1 A PHASE CT 50 75 100 150 200 250 300 350 400 500 600 750 1000 ratios SR 1 3 8 COLLAR For shallow switchgear the collar reduces the depth of the relay by 1 3 8 SR 3 COLLAR For shallow switchgear the collar reduces the depth of the relay by 3 Table 2 1 750 760 ORDER CODES 750 750 Feeder Management Relay 760 760 Feeder Management Relay Base Uni...

Page 22: ...D CURRENT Source CT 1 to 50000 A primary 1 or 5 A secondary Relay input 1 A or 5 A specified when ordering Burden Less than 0 2 VA at 1 or 5 A Conversion range Low end 0 005 CT Maximum 500 A primary fundamental frequency only Accuracy at 0 1 CT 0 2 of 1 CT at 0 1 CT 1 of 1 CT Overload withstand 1 second at 80 rated current continuous at 3 rated current BUS AND LINE VOLTAGE Source VT 0 12 to 600 kV...

Page 23: ...e 2 1 108 to 2 1 108 MWh Accuracy 2 of full scale see note above per hr VAR HOURS Range 2 1 108 to 2 1 108 Mvarh Accuracy 2 of full scale see note above per hr DEMAND Phase A B C current range 0 to 65535 A 3Φ real power range 3000 0 to 3000 0 MW 3Φ reactive power range 3000 0 to 3000 0 Mvar 3Φ apparent power range 3000 0 to 3000 0 MVA Measurement type Thermal Exponential 90 response time programme...

Page 24: ... 359 in steps of 1 Angle accuracy 2 Operation delay 25 to 40 ms BUS LINE UNDERVOLTAGE Minimum voltage programmable threshold from 0 00 to 1 25 VT in steps of 0 01 Pickup level 0 00 to 1 25 VT in steps of 0 01 Dropout level 102 to 103 of pickup Curve Definite Time or Inverse Time Time delay 0 0 to 6000 0 s in steps of 0 1 Phases Any one any two or all three program mable phases must operate for out...

Page 25: ...68 to 327 66 km miles 0 to 65534 ohms Memory stores the 10 most recent faults DATA LOGGER Data channels 8 channels same parameters as for analog outputs available Sample rate per cycle per second per minute every 5 10 15 20 30 or 60 minutes Trigger source pickup trip dropout control alarm event logic input manual command or contin uous Trigger position 0 to 100 Storage capacity 2 to 16 events with...

Page 26: ...eaker Failure UNDERVOLTAGE RESTORATION Initiated by Trip from Undervoltage 1 2 3 or 4 Minimum voltage level 0 00 to 1 25 VT in steps of 0 01 Time delay 0 1 to 100 0 s in steps of 0 1 Incomplete seq time 1 to 10000 min in steps of 1 Phases Any one any two or all three program mable phases must operate for output Level accuracy per voltage input Timing accuracy 100 ms UNDERFREQUENCY RESTORATION Init...

Page 27: ...mber 8 Type Trip 1 and Close 2 Relays Form A Auxiliary Relays 3 to 7 Form C Self Test Warning Relay 8 Form C Contact material silver alloy Contact durability 100 000 operations at 1800 operations hour at rated load FORM A CONTACT RATINGS Applicability Trip and Close Relays Relays 1 and 2 Make 30 A per ANSI IEEE C37 90 Carry 20 A continuous Break DC 300 W resistive 150 W inductive L R 40 ms Break A...

Page 28: ...t parameters Simulation of circuit breaker and selection of whether or not to operate outputs relays TYPE TESTING Fast transient per ANSI IEEE C37 90 1 and IEC 801 4 Level 4 5 kV at 5 50 ns Ri 50 Ω Insulation resistance per IEC 255 5 500 V DC 2000 MW Dielectric strength per IEC 255 5 and ANSI IEEE C37 90 2 kV at 60 Hz for 1 minute Surge withstand per IEC 255 22 1 and IEC 255 4 Class 3 fast transie...

Page 29: ...val of the relay from an energized panel There are no electronic components in the case Figure 3 1 CASE DIMENSIONS To prevent unauthorized removal of the drawout relay a wire lead seal can be installed through the slot provided in the mid dle of the locking latch With this seal in place the relay cannot be removed from the case Even though a passcode or set point access jumper can be used to preve...

Page 30: ...gure 3 3 SINGLE AND DOUBLE UNIT PANEL CUTOUTS Before mounting the SR unit in the supporting panel remove the unit from the case From the front of the panel slide the empty case into the cutout To ensure the case s 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 sho...

Page 31: ... side It will rotate to the left about its hinges 2 Press upward on the locking latch which is located below the handle and hold in its raised position The tip of a small screwdriver may prove helpful in this operation Figure 3 5 PRESS LATCH UP AND PULL HANDLE 3 With the latch raised pull the center of the handle outward Once disengaged continue rotating the handle up to the stop position Figure 3...

Page 32: ...he case until the guide pins on the unit have engaged the guide slots on either side of the case 5 Once fully inserted grasp the handle from its center and rotate it down from the raised position towards the bottom of the relay 6 Once the unit is fully inserted the latch will be heard to click locking the handle in the final position The unit is mechan ically held in the case by the handle s rolli...

Page 33: ...ts of interconnections in the general areas of instrument transformer inputs other inputs outputs communications and grounding The figure below shows the rear terminal layout of the 750 760 Relay contacts must be considered unsafe to touch when system is energized If the customer requires the relay contacts for low voltage accessible applications it is their responsibility to ensure proper insulat...

Page 34: ...COM B7 COM2 RS485 F7 5 AUXILIARY RELAY COM B8 COM2 RS485 COM F8 6 AUXILIARY RELAY NO B9 SHIELD GROUND F9 6 AUXILIARY RELAY COM B10 IRIG B F10 7 AUXILIARY RELAY COM B11 IRIG B F11 8 SELF TEST WARNING RELAY NO B12 RESERVED F12 8 SELF TEST WARNG RELAY COM LOGIC INPUTS CT and VT INPUTS GROUND C1 LOGIC INPUT 1 G1 COIL MONITOR 1 C2 LOGIC INPUT 2 G2 COIL MONITOR 2 C3 LOGIC INPUT 3 G3 SENSITIVE GROUND CT ...

Page 35: ...GE Multilin 750 760 Feeder Management Relay 3 7 3 INSTALLATION 3 2 ELECTRICAL 3 3 2ELECTRICAL 3 2 1 TYPICAL WIRING Figure 3 9 TYPICAL WIRING DIAGRAM Courtesy of NationalSwitchgear com ...

Page 36: ... Before making ground connections consider that the relay automatically calculates the neutral residual current from the sum of the three phase current phasors The following figures show three possible ground connections using the ground current input Terminals G10 and H10 and three possible sensitive ground connections using the sensi tive ground current input Terminals G3 and H3 The ground input...

Page 37: ...GE Multilin 750 760 Feeder Management Relay 3 9 3 INSTALLATION 3 2 ELECTRICAL 3 Figure 3 10 GROUND INPUTS Figure 3 11 SENSITIVE GROUND INPUTS Courtesy of NationalSwitchgear com ...

Page 38: ...e Restricted Earth Fault protection on trans formers that do not have dedicated protection To use the 750 760 for this type of protection a stabilizing resistor and possibly a non linear resistor will be required For more details see page 5 55 Figure 3 12 RESTRICTED EARTH FAULT INPUTS d ZERO SEQUENCE CT INSTALLATION The various CT connections and the exact placement of a Zero Sequence CT so that g...

Page 39: ... that these voltage channels are internally connected as wye This is why the jumper between the phase B terminal and the Vcom terminal must be installed with a delta connection Figure 3 14 LINE VT CONNECTIONS If Delta VTs are used the zero sequence voltage V0 and neutral sensitive ground polarizing voltage V0 will be zero Also with this Delta VT connection the phase neutral voltage cannot be measu...

Page 40: ...of the close coil requires the supervision circuit to be wired in parallel with the Close contact Each connection places an impedance across the associated contact which allows a small trickle current to flow through the related trip and close coil supervision circuitry For external supply voltages in the 30 to 250 V DC range this current draw will be between 2 to 5 mA If either the trip or close ...

Page 41: ... setpoint is Enabled the trip and close coil supervision circuits can be arranged to monitor the trip and close circuits continuously unaffected by breaker state This application requires that an alternate path around the 52a or 52b contacts in series with the operating coils be provided with modifications to the standard wiring as shown on drawing 818730 With these connections trickle current can...

Page 42: ...de of the external source must be con nected to the relay s DC negative rail at Terminal D12 The maximum external source voltage for this arrangement is 300 V DC Figure 3 17 DRY AND WET CONTACT CONNECTIONS 3 2 8 ANALOG INPUT Terminals A1 and A2 are provided for the input of a current signal from a wide variety of transducer outputs refer to technical specifications for complete listing This curren...

Page 43: ...solated and allow connection to devices which sit at a different ground poten tial Each analog output terminal is clamped to within 36 V of ground To minimize the affect of noise external connections should be made with shielded cable and only one end of the shield should be grounded If a voltage output is required a burden resistor must be connected at the input of the external measuring device I...

Page 44: ...e the use of shielded twisted pair wire is recommended Correct polarity should also be observed For instance SR type relays must be connected with all B1 terminals labeled COM1 RS485 connected together and all B2 terminals labeled COM1 RS485 connected together Terminal B3 COM1 RS485 COM should be connected to the common wire inside the shield To avoid loop currents the shield should be grounded at...

Page 45: ...GE Multilin 750 760 Feeder Management Relay 3 17 3 INSTALLATION 3 2 ELECTRICAL 3 Figure 3 20 RS422 WIRING DIAGRAM Courtesy of NationalSwitchgear com ...

Page 46: ...format that allows time stamping of events to be synchronized among connected devices within 1 millisecond The IRIG time code formats are serial width modulated codes which can be either DC level shift or amplitude modulated AM form Third party equipment is available for generating the IRIG B signal this equipment may use a GPS satellite system to obtain the time reference so that devices at diffe...

Page 47: ...is also provided for connection with a computer running the 750 760PC software The 40 character liquid crystal display is backlit to allow visibility under varied lighting conditions While the keypad and dis play are not being used the screen will display system information by scrolling through a maximum of 30 user selected default messages These default messages will only appear after a user prog...

Page 48: ...er drops below its pickup level the indicator will turn off SETPOINT GROUP 1 to 4 These indicators are flashing if the corresponding group is selected for editing and or dis play they are continuously on if the corresponding group is providing settings for the protection elements c SYSTEM STATUS LED INDICATORS The Open and Closed Status Indicator colors are interchangeable at the time of placing a...

Page 49: ...rgized After the auxiliary breaker contacts indicate that the breaker has opened the Trip Relay and indicator stop operating If both 52a and 52b auxiliary contacts are not installed the Trip Relay and indicator will de energize 100 ms after the trip condition clears or after two seconds 2 CLOSE A close sequence can be initiated by a 760 reclosure or a remote serial or front panel close command Whe...

Page 50: ...e key to scroll through the messages The following shows the format of the various diagnostic messages b SELF TEST WARNINGS The relay performs self diagnostics at initialization after power up and continuously as a background task to ensure that every testable unit of the hardware and software is alive and functioning correctly There are two types of self test warnings indicating either a minor or...

Page 51: ...atures detected inside the unit IRIG B Failure Minor Caused when IRIG B time synchronization has been enabled but the signal cannot be decoded Not Calibrated Minor This warning occurs when the relay has not been factory calibrated Pickup Test Minor Occurs when the PICKUP TEST FUNCTION setpoint is Enabled Prototype Software Minor Occurs when prototype software has been loaded into the relay Relay N...

Page 52: ...XT EDIT This message is displayed in response to the and keys while on a setpoint message with a text entry value The key must be pressed to begin editing PRESS ENTER TO REMOVE MESSAGE This flash message is displayed for 5 seconds in response to pressing the key fol lowed by the key while displaying one of the selected default messages in the sub group S1 RELAY SETUP ÖØ DEFAULT MESSAGES Pressing t...

Page 53: ... Drive 20 MB free space required before installation of software Operating System Windows 3 1 and variants Windows 95 98 Windows NT 2000 The 750 760PC software is ideal for use on under used legacy equipment If running 750 760PC under Windows 3 1 3 11 the following additional considerations must be addressed The SHARE EXE application must be installed Close other applications spreadsheets word pro...

Page 54: ... your default web browser OR Go to the GE Multilin website at http www GEindustrial com multilin preferred method 2 Click the Software menu item and select 750 760 Motor Management Relay from the product list 3 Verify that the version shown on this page is identical to the installed version as shown below Select the Help About 750 760PC menu item to determine which version is running on the local ...

Page 55: ...at the newest version of 750 760PC is installed installation from the web is preferred Figure 4 3 GE MULTILIN WELCOME SCREEN 3 Click the Index by Product Name item from the main page and select 750 760 Feeder Management Relay from the product list to open the 750 760 product page 4 Click the Software item from the Product Resources list to go to the 750 760 software page 5 The latest version of th...

Page 56: ...ow talking to a 750 760 is displayed As well the status at the bottom right hand corner of the screen indicates Communicating Set the based on user preference In Communicate with Relay mode 750 760 PC will attempt to establish communications immediately upon startup While in the File mode w default settings 750 760PC waits for the user to click the ON button before attempting communications this m...

Page 57: ...oint files should have the extension 750 or 760 for example motor1 750 Click OK to proceed 3 The software reads all the relay setpoint values and stores them to the selected file b UPGRADING THE 750 760 FIRMWARE Units with bootware versions earlier than 3 00 must be set to a Baud Rate of 9600 and a Slave Address of 1 before downloading new firmware The bootware version can be checked with the A5 P...

Page 58: ... will not be in service and will require setpoint programming To communicate with the relay the Slave Address Baud Rate and Parity will have to me manually programmed When communications is established the saved setpoints must be reloaded back into the relay See the following section for details on loading saved setpoint files c LOADING SETPOINTS FROM A FILE An error message will occur when attemp...

Page 59: ...ng window 3 For setpoints requiring numerical values e g PHASE CT PRIMARY clicking anywhere within the setpoint box launches a numerical keypad showing the old value range and setpoint value increment 4 Alternately numerical setpoint values may also be chosen by scrolling with the up down arrow buttons at the end of the setpoint box The values increment and decrement accordingly 5 For setpoints re...

Page 60: ...Revision code from the pull down menu For example If the firmware revision is 27I501A4 000 software revision 5 01 and the current setpoint file revision is 4 01 change the setpoint file revision to 5 0X 5 Select the File Save menu item to save the setpoint file in the new format See Loading Setpoints from a File on page 4 12 for instructions on downloading this setpoint file to the 750 760 f PRINT...

Page 61: ...rm for the last 750 760 trip will appear The date and time of the trip is displayed at the top of the window The red vertical line indicates the trigger point of the relay 3 Press the Setup button to enter the Graph Attribute page Program the graphs to be displayed with the pull down menu beside each graph description Change the Color Style Width Group and Spline selections as desired Select the s...

Page 62: ... to open the Event Recording window This window displays the list of events with the most current event displayed first see the figure below 2 Press the View Data button to see details of selected events 3 The Event Recorder Selector at the top of the View Data window scrolls through different events Select Save to store the details of the selected events to a file 4 Select Print to send the event...

Page 63: ...is window allows the desired addresses to be written to User Map locations The User Map values that correspond to these addresses are then displayed Figure 4 9 USER MAP WINDOW DISPLAY Displays the date of last event and the total number of events since last clear EVENT LISTING List of events with the most recent displayed on top VIEW DATA Click to display the details of selected events CLEAR EVENT...

Page 64: ...4 18 750 760 Feeder Management Relay GE Multilin 4 2 750 760PC SOFTWARE INTERFACE 4 USER INTERFACES 4 Courtesy of NationalSwitchgear com ...

Page 65: ...3 DEFAULT MESSAGES ENTER for more See page 5 14 USER TEXT MESSAGES ENTER for more See page 5 14 CLEAR DATA ENTER for more See page 5 15 INSTALLATION ENTER for more See page 5 15 SETPOINTS S2 SYSTEM SETUP CURRENT SENSING ENTER for more See page 5 16 BUS VT SENSING ENTER for more See page 5 16 LINE VT SENSING ENTER for more See page 5 17 PWR SYSTEM ENTER for more See page 5 17 FLEXCURVE A ENTER for ...

Page 66: ...TPOINTS S5 PROTECTION PHASE CURRENT ENTER for more See page 5 36 NEUTRAL CURRENT ENTER for more See page 5 42 GND CURRENT ENTER for more See page 5 47 SENSTV GND CURRENT ENTER for more See page 5 51 NEGATIVE SEQUENCE ENTER for more See page 5 58 VOLTAGE ENTER for more See page 5 63 FREQ ENTER for more See page 5 68 BRKR FAILURE ENTER for more See page 5 71 REV PWR ENTER for more See page 5 72 MESS...

Page 67: ...5 101 COLD LOAD PICKUP ENTER for more See page 5 103 UNDERVOLT RESTORE ENTER for more See page 5 105 UNDERFREQ RESTORE ENTER for more See page 5 106 TRANSFER ENTER for more See page 5 107 AR ENTER for more See page 5 118 SETPOINTS S8 TESTING OUTPUT RELAYS ENTER for more See page 5 129 PICKUP TEST ENTER for more See page 5 130 A O ENTER for more See page 5 130 SIMULATION ENTER for more See page 5 1...

Page 68: ...t access terminals will result in an error message The jumper does not restrict setpoint access via serial communications The relay has a programmable passcode setpoint which may be used to disallow setpoint changes from both the front panel and the serial communications ports This passcode consists of up to eight 8 alphanumeric characters The factory default passcode is 0 When this specific value...

Page 69: ...ich the measured parameter causes an output from the measuring element DELAY setpoint The FeatureName DELAY setpoint selects a fixed time interval to delay an input signal from appearing at the output From a contact input change of state to a contact closure of the 1 Trip relay the total delay is the time selected in this set point plus approximately 2 power frequency periods From an AC parameter ...

Page 70: ...the detector is controlled by the signal entering the RUN inset The measurement comparison can only be performed if a logic 1 is provided at the RUN input Relationship between setpoint and input parameter is indicated by the following symbols less than greater than etc The ANSI device number if one exists is indicated above the block TIME DELAYS Shown as a block with the following schematic symbol...

Page 71: ...tes setpoint access automatically becomes restricted Removing the setpoint access jumper immediately restricts setpoint access If passcode protection is active but the passcode is not known contact GE Multilin with the ENCRYPTED PASSCODE value 5 2 2 COMMUNICATIONS a MAIN MENU PATH SETPOINTS Ö S1 RELAY SETUP ÖØ COMMUNICATIONS The 750 760 relay has setpoints to enable communications through its RS23...

Page 72: ...e fastest response is obtained at 19200 baud Slower baud rates should be used if noise becomes a problem The data frame is fixed at 1 start 8 data and 1 stop bit COM1 and COM2 PARITY Selects the parity for COM1 and COM2 communications ports COM1 and COM2 RS485 422 HARDWARE Selects the COM1 and COM2 hardware configurations to be either two wire RS485 or four wire RS422 communications FRONT PANEL RS...

Page 73: ...ailable DATA LINK CONFIRM RETRIES Select the 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 750 760 will set the need time internal indica tion IIN After the time is written by a DNP master the IIN will be set again after this time elapse...

Page 74: ...ETUP ÖØ EVENT RECORDER The relay captures a wide variety of events and stores the last 128 in non volatile memory See Section 6 5 1 Event Records on page 6 16 for details A single power system disturbance could conceivably fill half of the event recorder due to the various events that can be captured Also some events may happen on a regular basis as part of a control scheme e g Power Factor events...

Page 75: ...ures are trig gered than the allowable number of events selected by this setpoint the oldest data is discarded to make room for the new capture For example 4 1024 indicates that the last three events with 1024 data samples per channel 64 cycles can be stored in memory Note that one buffer must be reserved for capturing the next event Changing this setpoint clears any data that is currently in memo...

Page 76: ...data collection begins in the next buffer and the relay then waits for the next trigger Once all buffers have been filled the oldest data is overwritten when a new trigger occurs The BUFFER ORGANIZATION and TRIGGER POSITION setpoints are only applicable in trigger mode The BUFFER ORGANZIA TION selects the number triggers stored and the samples per channel stored for each trigger For example 4 x 10...

Page 77: ... period of time the relay will automatically begin to display a pro grammed set of default messages This time can be modified to ensure menu messages remain on the screen long enough during programming or reading of actual values Once default scanning starts pressing any key will restore the last message displayed on the screen DEFAULT MSG INTENSITY To extend the life of the phosphor in the vacuum...

Page 78: ...oint access jumper and entering the correct passcode 2 Select the message to remove from the S1 RELAY SETUP ÖØ DEFAULT MESSAGES default message list 3 Press the key followed by the key The screen will display PRESS ENTER TO REMOVE MESSAGE Press the key while this message is being displayed The message is now removed from the default message list and the messages that follow are moved up to fill th...

Page 79: ...ON is set to Ready This warns against the installation of a relay whose setpoints have not been entered for the required application This setpoint is defaulted to Not Ready when the relay leaves the factory These setpoints should be used on a new installation or after new equipment has been installed The RESET TRIP COUNTER DATA setpoint clears all accumulated trip counter values and updates the TR...

Page 80: ... 5 3 2 BUS VT SENSING PATH SETPOINTS ÖØ S2 SYSTEM SETUP ÖØ BUS VT SENSING With bus VTs installed the relay can be used to perform voltage measurements power calculations and directional control of overcurrent elements VT CONNECTION TYPE Enter None if Bus VTs are not used If Bus VTs are used enter the VT connection made to the system as Wye or Delta An open delta connection is entered as Delta See ...

Page 81: ...WER SYSTEM PATH SETPOINTS Ö S2 SYSTEM SETUP ÖØ PWR SYSTEM The power system data is entered in this setpoint subgroup NOMINAL FREQ Enter the nominal power system frequency This value is used as a default to set the optimal digital sampling rate if the system frequency cannot be measured as there is no voltage available at the bus voltage phase A input terminals PHASE SEQUENCE Enter the phase sequen...

Page 82: ...time must be entered FLEXCURVE A ENTER for more CURVE TRIP TIME AT 1 03 x PU 0 ms Range 0 to 65535 ms in steps of 1 CURVE TRIP TIME AT 1 05 x PU 0 ms Range 0 to 65535 ms in steps of 1 CURVE TRIP TIME AT 20 0 x PU 0 ms Range 0 to 65535 ms in steps of 1 Table 5 1 FLEXCURVE TRIP TIMES PICKUP I Ipu TRIP TIME ms PICKUP TRIP TIME PICKUP TRIP TIME PICKUP TRIP TIME 1 03 2 90 4 90 10 5 1 05 3 00 5 00 11 0 ...

Page 83: ... ÖØ VIRTUAL INPUTS actual values menu If the value stored in memory is 0 then the virtual input is Off otherwise the virtual input is On The state of virtual inputs is written as if it were a setpoint these values are non volatile and are found in memory map locations 0090 to 00A4 hex Momentary virtual inputs are simulated by first writing a 1 to the corre sponding register followed by writing a 0...

Page 84: ...ollowing values For Logic Inputs 15 through 20 this setpoint may be assigned the following values VALUE LOGIC INPUT ASSERTED WHEN Disabled Never Contact Close Contact is closed Contact Open Contact is open Virtual On Virtual input is on Virtual Off Virtual input is off Closed Von Contact is closed AND virtual input is on Closed Voff Contact is closed AND virtual input is off Open Von Contact is op...

Page 85: ...must only be contacts The 52a CONTACT and 52b CONTACT setpoints are used to monitor the 52 a and 52 b contacts The following table deter mines how these contacts affect the breaker state When asserted the logic input assigned by the BRKR CONNECTED setpoint indicates that the breaker is connected to the primary system When the breaker is determined to be disconnected the breaker state is shown to b...

Page 86: ...ched or pulsed contact convert an external contact into a Form C contact and provide a contact multiplier for an external contact by operating multiple relays The setpoints for User Input A are shown above setpoints for User Inputs B through T are identical CONTROL FUNCTIONS ENTER for more LOCAL MODE Disabled Range Input 1 to Input 20 Disabled RESET Disabled Range Input 1 to Input 20 Disabled REMO...

Page 87: ...accumulated BLOCK FUNCTIONS ENTER for more BLOCK 1 TRIP RELAY Disabled Range Input 1 to Input 20 Disabled BLOCK 2 CLOSE RELAY Disabled Range Input 1 to Input 20 Disabled BLOCK RESET Disabled Range Input 1 to Input 20 Disabled BLOCK UNDERVOLT 1 Disabled Range Input 1 to Input 20 Disabled BLOCK UNDERVOLT 2 Disabled Range Input 1 to Input 20 Disabled BLOCK UNDERVOLT 3 Disabled Range Input 1 to Input ...

Page 88: ...SENSTV GND OC Disabled Range Input 1 to Input 20 Disabled BLK PHASE TIME 1 Disabled Range Input 1 to Input 20 Disabled BLK PHASE TIME 2 Disabled Range Input 1 to Input 20 Disabled BLK PHASE INST 1 Disabled Range Input 1 to Input 20 Disabled BLK PHASE INST 2 Disabled Range Input 1 to Input 20 Disabled BLK NEUTRL TIME 1 Disabled Range Input 1 to Input 20 Disabled BLK NEUTRL TIME 2 Disabled Range Inp...

Page 89: ...int is used to track breaker state for prevent parallel or permission to transfer logic The TRANSFORMER LOCKOUT and SOURCE TRIP setpoints are used to initiate a transfer as Source 1 2 is about to be lost The BLOCK TRANSFER setpoint disables the transfer scheme TRANSFER FUNCTIONS ENTER for more SELECT TO TRIP Disabled Range Input 1 to Input 20 Disabled UNDERVOLT ON OTHER SOURCE Disabled Range Input...

Page 90: ...se scheme from operating 5 4 10 MISCELLANEOUS FUNCTIONS PATH SETPOINTS ÖØ S3 LOGIC INPUTS ÖØ MISC FUNCTIONS The SIMULATE FAULT input function is operational only when the relay is in simulation testing mode the breaker is closed real or simulated breaker and presently in the prefault state When the assigned input is asserted the relay is forced into the fault state where the programmed fault value...

Page 91: ...the user Each relay can be selected to become either energized or de ener gized when operated and to operate as latched self resetting or pulsed Table 5 2 BREAKER AUXILIARY CONTACTS AND RELAY OPERATION 52A CONTACT INSTALLED 52B CONTACT INSTALLED RELAY OPERATION Yes Yes Trip Relay remains operating until 52b indicates an open breaker Close Relay remains operating until 52a indicates a closed breake...

Page 92: ...ed to the reset time of the Trip Relay thus extending its pulse width This is for use in applications where the 52 contacts reporting breaker state to the 750 760 are faster than the 52 contacts that are responsible for interrupting coil current Figure 5 1 OUTPUT RELAY 1 TRIP LOGIC 1 TRIP RELAY ENTER for more TRIP RELAY SEAL IN TIME 0 04 s Range 0 00 to 9 99 s in steps of 0 01 ENTER ESCAPE ð ð Cou...

Page 93: ...ded to the reset time of the Close Relay thus extending its pulse width This is for use in applications where the 52 contacts reporting breaker state to the 750 760 are faster than the 52 contacts that are responsible for interrupting coil current Figure 5 2 OUTPUT RELAY 2 CLOSE LOGIC 2 CLOSE RELAY ENTER for more TRIP RELAY SEAL IN TIME 0 04 s Range 0 00 to 9 99 s in steps of 0 01 ENTER ESCAPE ð ð...

Page 94: ...iring diagram This PULSED OUTPUT DWELL TIME setpoint is only displayed if the RELAY 3 OUTPUT TYPE is selected as Pulsed This set point determines the time interval that the pulsed contacts remain in the operated state Figure 5 3 OUTPUT RELAYS 3 TO 7 AUXILIARY LOGIC 3 AUX RELAY ENTER for more RELAY 3 NAME Auxiliary Range 16 alphanumeric characters RELAY 3 NON OPERATED STATE De energized Range Energ...

Page 95: ...OUTPUT RELAYS 5 5 5 5 SELF TEST WARNING RELAY There are no user programmable setpoints associated with the Self Test Warning Relay Output Relay 8 The logic for this relay is shown below Figure 5 4 OUTPUT RELAY 8 SELF TEST WARNING LOGIC Courtesy of NationalSwitchgear com ...

Page 96: ...rves are shown in the table below ElementName MULTIPLIER A multiplier setpoint allows shifting of the selected base curve in the vertical time direction Unlike the electromechanical time dial equivalent trip times are directly proportional to the value of the time multiplier setpoint For example all trip times for a multiplier of 10 are 10 times the multiplier 1 or base curve values Setting the mu...

Page 97: ...2 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 1 559 1 297 1 133 1 020 0 937 0 874 8 0 25 073 10 602 4 295 2 730 2 079 1 729 1 510 1 360 1 25...

Page 98: ... 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 1 800 1 543 1 350 1 200 1 00 27 000 13 500 6 7...

Page 99: ... 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 1 490 1 395 1 323 10 0 29 012 13 121 5 374 3 434 2 663 2 266 2 025 1 ...

Page 100: ...with identical characteristics These elements can be controlled by the phase directional element providing operation for current flow in the permitted direction only Voltage restrained operation which reduces the pickup level with reduced voltage is also available PHASE CURRENT ENTER for more PHASE TIME OC 1 ENTER for more See below PHASE TIME OC 2 ENTER for more PHASE INST OC 1 ENTER for more See...

Page 101: ...king cold load pickup blocking or autoreclose features are controlling the protection If the BUS INPUT VT TYPE is selected to None this feature is automatically disabled Figure 5 5 VOLTAGE RESTRAINT CHARACTERISTIC FOR PHASE TOC If voltage restraint is enabled the adjusted pickup calculated by adjusting the pickup value by the multi plier will not fall below 0 05 CT which is the lowest value for th...

Page 102: ...nt providing operation for current flow in the permitted direction only PHASE INST OC 1 ENTER for more PHASE INST OC 1 FUNCTION Trip Range Disabled Trip Trip AR Alarm Latched Alarm Control PHASE INST OC 1 RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays PHASE INST OC 1 PICKUP 1 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 PHASE INST OC 1 DELAY 0 00 s Range 0 00 to 600 00 s in steps...

Page 103: ...tive ground and negative sequence overcurrent elements If directional control is selected it will determine whether current flow in each phase is in the forward or reverse direction as determined by the connection of the PHASE DIRECTIONAL ENTER for more PHASE DIRECTIONAL FUNCTION Disabled Range Disabled Alarm Latched Alarm Control PHASE DIRECTIONAL RELAYS 3 7 Range Any combination of 3 to 7 Auxili...

Page 104: ...ing current near this line will generate a maximum amount of torque Maximum Torque Angle MTA the angle by which the Maximum Torque Line is rotated from the Polarizing Voltage The following diagram specifically shows the phasors involved for Phase A directional polarization but the general princi ples can be applied to all directional elements Figure 5 9 PHASE A DIRECTIONAL OVERCURRENT POLARIZATION...

Page 105: ...ectional parameters and as described in this section When the Alarm function is selected the 750 760 will flash the Alarm LED while the direction is REVERSE and will turn it off when the condition disappear When the Latched Alarm function is selected the 750 760 will flash the Alarm LED while the direction is REVERSE In this case the Alarm LED will remain illuminated after the condition has cleare...

Page 106: ...C offset and harmonic compo nents removed Neutral overcurrent elements can be controlled by the neutral directional element allowing operation for faults in the permitted direction only Also the elements can be blocked individually or as a group by logic inputs NEUTRAL CURRENT ENTER for more NEUTRAL TIME OC 1 ENTER for more See below NEUTRAL TIME OC 2 ENTER for more NEUTRAL INST OC 1 ENTER for mor...

Page 107: ...ed Range Disabled Trip Trip AR Alarm Latched Alarm Control NEUTRAL TIME OC 1 RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays NEUTRAL TIME OC 1 PICKUP 1 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 NEUTRAL TIME OC 1 CURVE Ext Inverse Range see Table 5 4 TOC Curve Selections on page 5 32 for values NEUTRAL TIME OC 1 MULTIPLIER 1 00 Range 0 00 to 100 00 in steps of 0 01 NEUTRAL TIME ...

Page 108: ... overcurrent relay Figure 5 12 NEUTRAL IOC LOGIC NEUTRAL INST OC 1 ENTER for more NEUTRAL INST OC 1 FUNCTION Disabled Range Disabled Trip Trip AR Alarm Latched Alarm Control NEUTRAL INST OC 1 RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays NEUTRAL INST OC 1 PICKUP 1 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 NEUTRAL INST OC 1 DELAY 0 00 s Range 0 00 to 600 00 s in steps of 0 01 ...

Page 109: ... determine neutral current direction The polarizing current comes from a source CT measuring the current flowing from the ground return into the neutral of a ground fault current source which is usually a transformer The direction is Forward when the neutral current is within 90 of the polarizing current Otherwise the direction is Reverse If the polarizing current is less than 5 of CT nominal then...

Page 110: ...operating current leads the polarizing voltage This is the angle of maximum sensitivity This setpoint affects voltage polarizing only Additional information is provided in the figure above MIN POLARIZING VOLTAGE This setpoint affects the voltage element only As the system zero sequence voltage is used as the polarizing voltage for this element a minimum level of voltage must be selected to prevent...

Page 111: ... and H10 Ground overcurrent elements can be blocked individually or as a group by logic inputs Ground overcurrent elements can be controlled by the ground directional element allowing operation for faults in the permitted direction only GND CURRENT ENTER for more GND TIME OC 1 ENTER for more See page 5 48 GND TIME OC 2 ENTER for more GND INST OC 1 ENTER for more See page 5 49 GND INST OC 2 ENTER f...

Page 112: ...hed Alarm Control GND TIME OC 1 RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays GND TIME OC 1 PICKUP 1 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 GND TIME OC 1 CURVE Ext Inverse Range See Table 5 4 TOC Curve Selections on page 5 32 for values GND TIME OC 1 MULTIPLIER 1 00 Range 0 00 to 100 00 in steps of 0 01 GND TIME OC 1 RESET Instantaneous Range Instantaneous Linear GND TIME ...

Page 113: ...ND INST OC 1 ENTER for more GND INST OC 1 FUNCTION Disabled Range Disabled Trip Trip AR Alarm Latched Alarm Control GND INST OC 1 RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays GND INST OC 1 PICKUP 1 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 GND INST OC 1 DELAY 0 00 s Range 0 00 to 600 00 s in steps of 0 01 GND INST OC 1 DIRECTION Disabled Range Disabled Forward Reverse ENTER ...

Page 114: ...polarizing voltage magnitude is insufficient then the cur rent polarizing takes control If the polarizing current magnitude is insufficient then the voltage polarizing takes control If neither voltage nor current polarizing is possible then the direction defaults to forward GND POLARIZING If ground directional control with both voltage and current polarized elements is desired enter Dual If ground...

Page 115: ...ement Sensitive ground overcurrent elements can be controlled by the sensitive ground direc tional element allowing operation for faults in the permitted direction only Also the elements can be blocked individually or as a group by logic inputs SENSTV GND CURRENT ENTER for more SENSTV GND TIME OC ENTER for more See page 5 52 SENSTV GND INST OC ENTER for more See page 5 53 SENSTV GND DIRECTN ENTER ...

Page 116: ...hed Alarm Control SENSTV GND TIME OC RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays SENSTV GND TIME OC PICKUP 1 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 SENSTV GND TIME OC CURVE Ext Inverse Range see Table 5 4 TOC Curve Selections on page 5 32 for values SENSTV GND TIME OC MULTIPLIER 1 00 Range 0 00 to 100 00 in steps of 0 01 SENSTV GND TIME OC RESET Instantaneous Range Insta...

Page 117: ...ENSTV GND INST OC ENTER for more SENSTV GND INST OC FUNCTION Disabled Range Disabled Trip Trip AR Alarm Latched Alarm Control SENSTV GND INST OC RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays SENSTV GND INST OC PICKUP 1 000 x CT Range 0 005 to 1 000 x CT in steps of 0 001 SENSTV GND INST OC DELAY 0 00 s Range 0 00 to 600 00 s in steps of 0 01 SENSTV GND INST OC DIRECTION Disabled Rang...

Page 118: ...sufficient then the voltage polarizing takes control If neither voltage nor current polarizing is possible then the direction defaults to forward SENS GND POLARIZING If sensitive ground directional control with both voltage and current polarized elements is desired enter Dual With this setpoint both polarizing quantities must agree that the operating current is in the reverse direction for the sen...

Page 119: ...ll be required The inclusion of a stabilizing resistor encourages the circulating fault current to flow via the magnetizing impedance of the saturated current transformer thus minimizing spill current in the REF relay A non linear resistor will be required where the voltage across the inputs would be greater than 2000 V Refer to Restricted Earth Fault Inputs on page 3 10 for the con nections requi...

Page 120: ...er It is assumed that the ratio of the CT kneepoint VK VS is to 2 for stability Thus EQ 5 6 Next the voltage that would result from a fault must be determined neglecting saturation EQ 5 7 The peak value of this fault voltage would be EQ 5 8 If VP is greater than 2000 V then a non linear resistor must be used SAMPLE APPLICATION The CTs used in this example are 3000 1 10P10 15 VA and the transformer...

Page 121: ...eans also assuming 1 for CT magnetizing current EQ 5 14 and therefore EQ 5 15 To determine whether a non linear resistor is required we have EQ 5 16 A non linear resistor is recommended as the peak fault voltage is above relay voltage maximum of 2000 V Figure 5 22 RESTRICTED EARTH FAULT LOGIC IMAXf IP X 2887 A 0 07 41243 A ISFLC 2887 A 3000 0 962 A ISmax 0 962 A 0 07 13 74 A If IPICKUP 0 3 2887 A ...

Page 122: ...for more See page 5 59 NEG SEQ DIRECTION ENTER for more See page 5 60 NEG SEQ VOLTAGE ENTER for more See page 5 62 NEG SEQ TIME OC ENTER for more NEG SEQ TIME OC FUNCTION Disabled Range Disabled Trip Trip AR Alarm Latched Alarm Control NEG SEQ TIME OC RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays NEG SEQ TIME OC PICKUP 1 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 NEG SEQ TIME ...

Page 123: ...grammed in this subgroup NEG SEQ INST OC ENTER for more NEG SEQ INST OC FUNCTION Disabled Range Disabled Trip Trip AR Alarm Latched Alarm Control NEG SEQ INST OC RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays NEG SEQ INST OC PICKUP 1 000 x CT Range 0 05 to 20 00 x CT in steps of 0 001 NEG SEQ INST OC DELAY 0 00 s Range 0 00 to 600 00 s in steps of 0 01 NEG SEQ INST OC DIRECTION Disabl...

Page 124: ... more details on directional principles The operating current and polarizing voltage is shown in the following table If the polarizing voltage drops below the MIN OPERATING VOLTAGE value the direction defaults to forward NEG SEQ DIRECTION ENTER for more NEG SEQ DIRECTIONAL FUNCTION Disabled Range Disabled Alarm Latched Alarm Control NEG SEQ DIRECTIONAL RELAYS 3 7 Range Any combination of 3 to 7 Au...

Page 125: ...tion caused by system unbalanced voltages or VT ratio errors For well balanced systems and 1 accuracy VTs this setpoint can be as low as 2 of VT nominal volt age For systems with high resistance grounding or floating neutrals this setpoint can be as high as 20 The default value of 0 05 x VT is appropriate for most solidly grounded systems Figure 5 25 NEGATIVE SEQUENCE DIRECTIONAL LOGIC Table 5 15 ...

Page 126: ... alarm when the negative sequence voltage exceeds the specified threshold for a specified time delay Figure 5 26 NEGATIVE SEQUENCE VOLTAGE LOGIC NEG SEQ VOLTAGE ENTER for more NEG SEQ VOLTAGE FUNCTION Disabled Range Disabled Trip Alarm Latched Alarm Control NEG SEQ VOLTAGE RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays NEG SEQ VOLTAGE PICKUP 0 10 x VT Range 0 00 to 1 25 x VT in steps ...

Page 127: ...ce Transfer Schemes In the event of an undervoltage a transfer signal may be generated to transfer a load from its normal source to a standby or emergency power source The undervoltage elements can be programmed to have an inverse time delay characteristic The undervoltage delay set point defines a family of curves as shown below Figure 5 27 INVERSE TIME UNDERVOLTAGE CURVES SENSTV GND CURRENT ENTE...

Page 128: ...2 setpoints are identical Figure 5 28 BUS UNDERVOLTAGE LOGIC BUS UNDERVOLTAGE 1 ENTER for more BUS UNDERVOLTAGE 1 FUNCTION Disabled Range Disabled Trip Alarm Latched Alarm Control BUS UNDERVOLTAGE 1 RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays BUS UNDERVOLTAGE 1 PICKUP 0 75 x VT Range 0 00 to 1 25 x VT in steps of 0 01 BUS UNDERVOLTAGE 1 CURVE Ext Inverse Range Definite Time Inverse...

Page 129: ...ints for the Undervoltage 3 element are shown above the Undervoltage 4 setpoints are identical Figure 5 29 LINE UNDERVOLTAGE LOGIC LINE UNDERVOLT 3 ENTER for more LINE UNDERVOLT 3 FUNCTION Disabled Range Disabled Trip Alarm Latched Alarm Control LINE UNDERVOLT 3 RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays LINE UNDERVOLT 3 PICKUP 0 75 x VT Range 0 00 to 1 25 x VT in steps of 0 01 LI...

Page 130: ...ime delay The setpoints above are repeated for both Overvoltage 1 and Overvoltage 2 Figure 5 30 OVERVOLTAGE LOGIC OVERVOLTAGE 1 ENTER for more OVERVOLTAGE 1 FUNCTION Disabled Range Disabled Trip Alarm Latched Alarm Control OVERVOLTAGE 1 RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays OVERVOLTAGE 1 PICKUP 1 25 x VT Range 0 00 to 1 25 x VT in steps of 0 01 OVERVOLTAGE 1 DELAY 2 0 s Range...

Page 131: ...ture should be applied with caution It would normally be applied to give line to ground fault coverage on high impedance grounded or ungrounded systems which are isolated This constraint stems from the fact that a measurement of 3V0 cannot discriminate between a faulted circuit and an adjacent healthy circuit Use of a time delayed back up or an alarm mode allow other protections an opportunity to ...

Page 132: ...ge required to allow the underfrequency element to operate This setpoint is used to prevent incorrect operation before energization of the source to the relay location and during voltage dips MIN OPERATING CURRENT Enter the minimum value of current required on any phase to allow the underfrequency element to operate This setpoint is used to prevent underfrequency tripping during periods of light l...

Page 133: ...GE Multilin 750 760 Feeder Management Relay 5 69 5 SETPOINTS 5 6 S5 PROTECTION 5 Figure 5 32 UNDERFREQUENCY LOGIC Courtesy of NationalSwitchgear com ...

Page 134: ...d Trip Alarm Latched Alarm Control FREQ DECAY RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays See 5 6 1 Overview on page 5 32 for details FREQ DECAY RATE 1 0 Hz s Range 0 1 to 5 0 Hz s in steps of 0 1 FREQ DECAY PICKUP 59 00 Hz Range 20 00 to 65 00 Hz in steps of 0 01 See 5 6 1 Overview on page 5 32 for details FREQ DECAY DELAY 2 00 s Range 0 00 to 600 00 s in steps of 0 01 See 5 6 1 O...

Page 135: ...sent Delay 1 has expired and one of the phase currents is above the BRKR FAILURE CURRENT setpoint If one of the delays is not required simply program the unwanted timer to its minimum value The operation of the filter that reduces the overreaching effect of asymmetrical offset currents will cause the mea sured current to ramp down to zero after the breaker trips It is strongly recommended that a m...

Page 136: ...range of 10 to 15 seconds is typical Recall that the rated power is calculated as follows EQ 5 18 The sensitivity of this element and the requirement to have two times pickup limits its range of application The motoring power cannot be less that 3 of rated and the angle away from the 180 angle of maximum sensitivity should not be greater than 85 to 87 due to reactive loading on the generator This ...

Page 137: ...e 5 36 PHASE CURRENT LEVEL LOGIC CURRENT LEVEL ENTER for more PHASE CURRENT ENTER for more See below NEUTRAL CURRENT ENTER for more See page 5 74 PHASE CURRENT ENTER for more PHASE CURRENT FUNCTION Disabled Range Disabled Alarm Latched Alarm Control PHASE CURRENT RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays See 5 6 1 Overview on page 5 32 for details PHASE CURRENT PICKUP 1 10 x CT R...

Page 138: ...ange Disabled Alarm Latched Alarm Control NEUTRAL CURRENT RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays See 5 6 1 Overview on page 5 32 for details NEUTRAL CURRENT PICKUP 1 00 x CT Range 0 05 to 20 00 x CT in steps of 0 01 See 5 6 1 Overview on page 5 32 for details NEUTRAL CURRENT DELAY 2 s Range 0 to 60000 s in steps of 1 See 5 6 1 Overview on page 5 32 for details ENTER ESCAPE ð ð...

Page 139: ...el for a time larger than the set delay the relay will reset the output contact to the non operated state Both Power Factor 1 and 2 features are inhibited from operating unless all three voltages are above 30 of nominal and one or more currents is above 0 Power Factor 1 and 2 delay timers will only be allowed to time when the 30 threshold is exceeded on all phases and the power factor remains outs...

Page 140: ...OCATOR ENTER for more LENGTH OF FEEDER 0 1 km Range 0 1 to 99 9 km Miles in steps of 0 1 UNITS OF LENGTH km Range km Miles Zpos RESISTIVE OF FEEDER 0 01 Ω Range 0 01 to 99 99 Ω in steps of 0 01 Zpos INDUCTIVE OF FEEDER 0 01 Ω Range 0 01 to 99 99 Ω in steps of 0 01 Zzero RESISTIVE OF FEEDER 0 01 Ω Range 0 01 to 99 99 Ω in steps of 0 01 Zzero INDUCTIVE OF FEEDER 0 01 Ω Range 0 01 to 99 99 Ω in steps...

Page 141: ...urrent was available This parameter can be very useful in estimating the location of a fault on a feeder tap where the apparent distance can be calculated as beyond the feeder end The date time type of fault and phases involved are also stored for the event Non volatile memory is provided for the past ten events in a FIFO queue available under A1 STATUS ÖØ FAULT LOCATIONS If the feeder has a sourc...

Page 142: ...te value just as the response time of an analog instrument A steady state value applied for twice the response time will indicate 99 of the value Block Interval This selection calculates a linear average of the quantity RMS current real power reactive power or apparent power over the programmed demand time interval starting daily at 00 00 00 i e 12 am The 1440 minutes per day is divided into the n...

Page 143: ...current demand calculation is to be performed Figure 5 41 CURRENT DEMAND LOGIC CURRENT ENTER for more CURRENT DMND FUNCTION Disabled Range Disabled Alarm Latched Alarm Control MEASUREMENT TYPE Thermal Exponential Range Thermal Exponential Block Interval Rolling Demand See page 5 78 for details THERMAL 90 RESPONSE TIME 15 min Range 5 min 10 min 15 min 20 min 30 min 60 min Seen only if MEASUREMENT T...

Page 144: ...es auto range to show units appropriate to the power system size Figure 5 42 REAL POWER DEMAND LOGIC REAL PWR ENTER for more REAL PWR DMND FUNCTION Disabled Range Disabled Alarm Latched Alarm Control MEASUREMENT TYPE Block Interval Range Thermal Exponential Block Interval Rolling Demand See page 5 78 for details THERMAL 90 RESPONSE TIME 15 min Range 5 min 10 min 15 min 20 min 30 min 60 min Seen on...

Page 145: ...tities auto range to show units appropriate to the power system size Figure 5 43 REACTIVE POWER DEMAND LOGIC REACTIVE PWR ENTER for more REACTIVE PWR DMND FUNCTION Disabled Range Disabled Alarm Latched Alarm Control MEASUREMENT TYPE Block Interval Range Thermal Exponential Block Interval Rolling Demand See page 5 78 for details THERMAL 90 RESPONSE TIME 15 min Range 5 min 10 min 15 min 20 min 30 mi...

Page 146: ...uantities auto range to show units appropriate to the power sys tem size Figure 5 44 APPARENT POWER DEMAND LOGIC APPARENT PWR ENTER for more APPARENT PWR DMND FUNCTION Disabled Range Disabled Alarm Latched Alarm Control MEASUREMENT TYPE Block Interval Range Thermal Exponential Block Interval Rolling Demand See page 5 78 for details THERMAL 90 RESPONSE TIME 15 min Range 5 min 10 min 15 min 20 min 3...

Page 147: ...olution that will result from the selection of the minimum and maximum setpoints For example if 0 to 20 mA is to be represented via the 0 to 20 mA analog input an input of 4 5 mA will translate to a 5 mA actual value reading This is due to the rounding up of the value since the analog input actual value is an F1 format If a range of 0 to 200 mA was programmed to be represented via the 0 to 20 mA i...

Page 148: ... setpoint is programmed for a drop out ratio of 10 then the drop out current will be 4500 μA The drop out ratio is defined as follows EQ 5 21 The ANALOG THRESHLD 1 PICKUP TYPE setpoint determines if pickup will occur when the analog input is over or under the programmed threshold When set to Over the Drop Out value is calculated shown in the equation above ANALOG THRESHLD 1 ENTER for more A I THRE...

Page 149: ...ent analog input reading is captured and a new rate of change calculated for the previous minute hour The rate is calculated using the previous sixty analog input readings and the Least Squares Approximation method that generates an equation for the best line through the sample points as shown below The rate of change is equal to the slope of this line which is a stable quantity not unduly affecte...

Page 150: ...annel correspondence Type A channel ranges extend from a minimum of 0 units Type B channels range between definite boundaries Type C channels include the direction of flow The following diagram illustrates these charac teristics A O 1 ENTER for more A O 1 SOURCE Disabled Range See Table 5 16 Analog Output Parameters on page 5 87 A O 1 MIN 100 0 MW Range As per function selection See Table 5 16 Ana...

Page 151: ...Line Voltage 0 00 to 655 35 kV 0 01 0 00 100 00 A Frequency 20 00 to 65 00 Hz 0 01 47 00 63 00 B 3φ Real Power 3000 0 to 3000 0 MW1 0 1 100 0 100 0 C 3φ Reactive Power 3000 0 to 3000 0 Mvar1 0 1 100 0 100 0 C 3φ Apparent Power 0 0 to 3000 0 MVA1 0 1 0 0 100 0 A 3φ Power Factor 0 00 Lead to 0 00 Lag 0 01 0 99 Lag 0 50 Lag B Last Phase A B C Demand 0 to 65535 Amps 1 0 2000 A Last Watt Demand 3000 0 ...

Page 152: ...3000 0 MW1 0 1 100 0 100 0 C φA φB φC Reactive Power 3000 0 to 3000 0 Mvar1 0 1 100 0 100 0 C φA φB φC Apparent Power 0 0 to 3000 0 MVA1 0 1 0 0 100 0 A φA φB φC Power Factor 0 00 Lead to 0 00 Lag 0 01 0 99 Lag 0 50 Lag B Synchro Voltage 0 00 to 655 35 kV 0 01 0 00 100 00 A Synchro Voltage Angle 0 to 359 Lag 1 0 359 A Synchro Frequency 20 00 to 65 00 Hz 0 01 47 00 63 00 B Frequency Decay Rate 10 0...

Page 153: ...put will occur EQUIPMENT ENTER for more TRIP COUNTER ENTER for more See page 5 89 ARCING CURRENT ENTER for more See page 5 90 BRKR OPERATION ENTER for more See page 5 92 COIL MON 1 ENTER for more See page 5 93 COIL MON 2 ENTER for more VT FAILURE ENTER for more See page 5 94 TRIP COUNTER ENTER for more TRIP COUNTER FUNCTION Disabled Range Disabled Alarm Latched Alarm Control TRIP COUNTER RELAYS 3 ...

Page 154: ...the relay to determine when to start integrating The integration continues for 100 ms by which time most modern breakers will have cleared a fault For the TOTAL ARCING CURRENT LIMIT enter the total arcing current in kA2 cycle at which this feature is to cause an alarm For example if an alarm is desired as soon as the total arcing current in any phase exceeds 1000 kA2 cycle enter 1000 for this setp...

Page 155: ...igure 5 51 ARCING CURRENT MEASUREMENT Figure 5 52 ARCING CURRENT LOGIC 750 Trip Command Breaker Contacts Part Arc Extinguished 100 ms Programmable Start Delay Start Integration Stop Integration Total Area Breaker Arcing Current kA x cycle ARCING CDR Courtesy of NationalSwitchgear com ...

Page 156: ...onditions if BRKR OPERATION FUNCTION is set to Alarm or Control The breaker does not respond to a trip command within the programmed breaker operation delay time The breaker does not respond to a close command within the programmed time When a breaker operation failure is declared the selected output relays will operate but the Close Relay and 760 autore closure will be inhibited If the 760 alread...

Page 157: ...RKR STATE BYPASS to be Enabled Generally this selection will require a wiring modification of the breaker as detailed in Section 3 2 6 Trip Close Coil Supervision on page 3 12 Figure 5 54 COIL MONITOR LOGIC COIL MON 1 ENTER for more COIL MON 1 NAME Trip Coil Monitor Range Any combination of 18 alphanumeric characters COIL MON 1 FUNCTION Disabled Range Disabled Alarm Latched Alarm Control COIL MON ...

Page 158: ...put CTs Also if there is not a significant amount of positive sequence voltage when there is positive sequence current then it could indicate that all the VT fuses have been pulled or the VTs have been racked out Figure 5 55 VT FAILURE LOGIC VT FAILURE ENTER for more VT FAILURE FUNCTION Disabled Range Disabled Alarm Latched Alarm Control VT FAILURE RELAYS 3 7 Range Any combination of 3 to 7 Auxili...

Page 159: ...erval activation Figure 5 56 PULSED OUTPUT LOGIC PULSED OUTPUT ENTER for more PULSED OUTPUT FUNCTION Disabled Range Disabled Alarm Latched Alarm Control POS WATTHOURS PULSED RELAYS 3 7 Range Any combination of 3 to 7 Auxiliary relays POS WATTHOURS PULSED INTERVAL 10 0 MWh Range 0 0 to 6553 5 MWh in steps of 0 1 Quantities auto range to appropriate units NEG WATTHOURS PULSED RELAYS 3 7 Range Any co...

Page 160: ... or by logic input If there is a conflict in the selection of the active group between a set point and logic input or between two logic inputs the higher numbered group will be made active For example if the logic inputs for Group 2 3 and 4 are all asserted the relay would use Group 4 If the logic input for Group 4 then becomes de asserted the relay will use Group 3 Any change from the default Gro...

Page 161: ...GE Multilin 750 760 Feeder Management Relay 5 97 5 SETPOINTS 5 8 S7 CONTROL 5 Figure 5 57 SETPOINT CONTROL 1 OF 3 Figure 5 58 SETPOINT CONTROL 2 OF 3 Courtesy of NationalSwitchgear com ...

Page 162: ...5 98 750 760 Feeder Management Relay GE Multilin 5 8 S7 CONTROL 5 SETPOINTS 5 Figure 5 59 SETPOINT CONTROL 3 OF 3 Courtesy of NationalSwitchgear com ...

Page 163: ...ker closure The voltage levels that determine whether a source is dead or live are configurable in the four set points following this one The DEAD SOURCE PERMISSIVE range is as follows Off Dead source permissive is disabled DB DL Dead Bus AND Dead Line LL DB Live Line AND Dead Bus DL LB Dead Line AND Live Bus DL DB Dead Line OR Dead Bus DLxDB Dead Line XOR Dead Bus one source is Dead and one is Li...

Page 164: ...le bus or line voltage input used for synchrocheck is established as Live or energized The voltage angular and frequency differences of the primary systems are also entered through the MAX VOLTAGE DIFFER ENCE MAX ANGLE DIFFERENCE and MAX FREQ DIFFERENCE setpoints respectively A voltage magnitude angular or fre quency differential on the two input voltages below the values entered here is within th...

Page 165: ...isabled Range Disabled Enabled NEUTRAL INST OC 1 BLOCKING Disabled Range Disabled Enabled GND INST OC BLOCKING Disabled Range Disabled Enabled SENSTV GND INST OC BLOCKING Disabled Range Disabled Enabled NEG SEQ INST OC BLOCKING Disabled Range Disabled Enabled PHASE TIME OC 1 RAISED PICKUP 0 Range 0 to 100 in steps of 1 NEUTRAL TIME OC 1 RAISED PICKUP 0 Range 0 to 100 in steps of 1 GND TIME OC RAIS...

Page 166: ...5 102 750 760 Feeder Management Relay GE Multilin 5 8 S7 CONTROL 5 SETPOINTS 5 Figure 5 61 MANUAL CLOSE BLOCKING LOGIC Courtesy of NationalSwitchgear com ...

Page 167: ...ting the logic input function Cold Load Pickup Overcurrent settings are returned to nor mal after any phase current is restored to greater than 10 of nominal and then a timer of duration equal to COLD LOAD PICKUP BLOCK TIME expires COLD LOAD PICKUP ENTER for more COLD LOAD PICKUP FUNCTION Disabled Range Disabled Alarm Latched Alarm Control COLD LOAD PICKUP RELAYS 3 7 Range Any combination of 3 to ...

Page 168: ... 8 S7 CONTROL 5 SETPOINTS 5 Figure 5 62 COLD LOAD PICKUP Figure 5 63 COLD LOAD PICKUP LOGIC Time seconds Current of normal 0 100 200 300 400 500 1 0 1 2 3 4 5 6 OUTAGE PICKUP PICKUP LOAD ENERGIZED X NORMAL TRIP SETTING Courtesy of NationalSwitchgear com ...

Page 169: ...only effective if the voltage is above the restoration threshold A Block Restoration logic input is avail able to prevent both initiation and operation It is recommended that if automatic undervoltage restoration is to be used that the cold load pickup feature is also enabled to prevent the breaker from tripping shortly after it is automatically closed Figure 5 64 UNDERVOLTAGE RESTORATION LOGIC UN...

Page 170: ...celed by a reset command Cancellation of a previous initiation is only effective if the voltage and frequency are above the restoration thresholds A Block Restoration logic input is available to prevent both initiation and operation It is recommended that if automatic underfrequency restora tion is to be used that the cold load pickup feature is also enabled to prevent the breaker from tripping sh...

Page 171: ...sfer scheme minimizes the effect of outages on one of the incoming supplies by opening the incoming breaker con nected to that supply and then re energizing the dead bus by closing the bus tie breaker to transfer the dead bus to the live source To protect against damage to motors connected to the dead bus the bus tie breaker is not allowed to close after a transfer has been initiated until the dec...

Page 172: ...ult detection signal Device 86T 4 Both 1 and 2 above The only differences in implementing the transfer scheme among the configurations presented above is by connecting additional logic signals to the relay when available and by placing a jumper on one logic input if the breaker is non drawout and has no disconnect auxiliary switches Besides the setpoints and logic incorporated into the transfer sc...

Page 173: ...r scheme logic in this application and therefore the function setpoint of elements that are used must be set to Control These elements block a transfer while a fault which can cause a severe voltage dip is present on the load side of the breaker This fault should be cleared by time overcurrent protection on the incomer or an upstream breaker If Device 50P is set properly during this event it will ...

Page 174: ...ose Open Von Open Voff Closed Von Closed Voff 3 Name Remote Open Asserted Logic Contact Open Contact Close Open Von Open Voff Closed Von Closed Voff Name Remote Open Asserted Logic Contact Open Contact Close Open Von Open Voff Closed Von Closed Voff Name Remote Open Asserted Logic Contact Open Contact Close Open Von Open Voff Closed Von Closed Voff 4 Name 52a or 52b Contact Asserted Logic Contact ...

Page 175: ...GE Multilin 750 760 Feeder Management Relay 5 111 5 SETPOINTS 5 8 S7 CONTROL 5 Figure 5 66 TRANSFER SCHEME ONE LINE DIAGRAM Courtesy of NationalSwitchgear com ...

Page 176: ...5 112 750 760 Feeder Management Relay GE Multilin 5 8 S7 CONTROL 5 SETPOINTS 5 Figure 5 67 TRANSFER SCHEME INCOMER NO 1 DC SCHEMATIC Courtesy of NationalSwitchgear com ...

Page 177: ...GE Multilin 750 760 Feeder Management Relay 5 113 5 SETPOINTS 5 8 S7 CONTROL 5 Figure 5 68 TRANSFER SCHEME INCOMER NO 2 DC SCHEMATIC Courtesy of NationalSwitchgear com ...

Page 178: ...5 114 750 760 Feeder Management Relay GE Multilin 5 8 S7 CONTROL 5 SETPOINTS 5 Figure 5 69 TRANSFER SCHEME BUS TIE BREAKER DC SCHEMATIC Courtesy of NationalSwitchgear com ...

Page 179: ...GE Multilin 750 760 Feeder Management Relay 5 115 5 SETPOINTS 5 8 S7 CONTROL 5 Figure 5 70 TRANSFER SCHEME INCOMER NO 1 LOGIC Courtesy of NationalSwitchgear com ...

Page 180: ...5 116 750 760 Feeder Management Relay GE Multilin 5 8 S7 CONTROL 5 SETPOINTS 5 Figure 5 71 TRANSFER SCHEME INCOMER NO 2 LOGIC Courtesy of NationalSwitchgear com ...

Page 181: ...GE Multilin 750 760 Feeder Management Relay 5 117 5 SETPOINTS 5 8 S7 CONTROL 5 Figure 5 72 TRANSFER SCHEME BUS TIE BREAKER LOGIC Courtesy of NationalSwitchgear com ...

Page 182: ...re further recloses are permitted The reclosure scheme is considered enabled when all of the following four conditions are true 1 The AR FUNCTION setpoint is set to Enabled 2 Either a 52a or 52b contact is installed and has been programmed to a logic input function 3 Neither the Block Reclosure nor Cancel Reclosure logic input functions are asserted 4 The scheme is not in the lockout state 5 The A...

Page 183: ...he relay will then continue to trip and reclose until lockout is reached b SCHEME SETUP PATH SETPOINTS ÖØ S7 CONTROL ÖØ AR Ö SCHEME SETUP The setpoints shown above setup the general characteristics of the scheme The AR FUNCTION and MAX NUMBER OF RECLO SURE SHOTS setpoints are critical and must be set appropriately For an overcurrent element to initiate a reclosure it must be set to the Trip AR fun...

Page 184: ...deter mine if a manual close has occurred The breaker state is determined by the 52a b contact feedback to the 760 When set to Disabled only close commands sent via the 760 will be considered as a manual close for the autoreclose scheme logic INCOMPLETE SEQUENCE TIME This timer sets the maximum time interval allowed for a single reclose shot It is started whenever a reclosure is initiated and is a...

Page 185: ...GE Multilin 750 760 Feeder Management Relay 5 121 5 SETPOINTS 5 8 S7 CONTROL 5 Figure 5 73 AUTORECLOSE SCHEME SETUP LOGIC Courtesy of NationalSwitchgear com ...

Page 186: ...ched Alarm Control RATE SUPERVISION RELAYS 3 7 Range Any combination of the 3 to 7 Auxiliary relays MAX AR RATE 25 hr Range 1 to 50 hr in steps of 1 CURRENT SUPERVISION ENTER for more CURRENT SUPERVISION FUNCTION Disabled Range Enabled Disabled 3 SHOTS FOR CURRENT ABOVE 17 00 x CT Range 0 00 to 20 00 x CT in steps of 0 01 2 SHOTS FOR CURRENT ABOVE 18 00 x CT Range 0 00 to 20 00 x CT in steps of 0 ...

Page 187: ...ermitted shots whether set by the MAX NUMBER OF RECLOSE SHOTS setpoint or the Current Supervi sion feature always takes precedence unless current supervision takes the scheme to lockout Lockout has the highest pri ority Once the current supervision feature has reduced the total number of shots a subsequent shot can still reduce the limit further The fault current level above which the number of au...

Page 188: ...coordination feature will continue to increment the shot counter If this continues to the maximum number of shots programmed in the 760 the autoreclose scheme will go to lockout If the fault is transient then the autoreclose scheme and shot counter will eventually be reset by the normal reset mechanism The PHASE CURRENT INCREASE and NEUTRAL CURRENT INCREASE setpoints select the minimum phase and n...

Page 189: ...GE Multilin 750 760 Feeder Management Relay 5 125 5 SETPOINTS 5 8 S7 CONTROL 5 Figure 5 76 AUTORECLOSE ZONE COORDINATION LOGIC Courtesy of NationalSwitchgear com ...

Page 190: ...nge Enabled Disabled NEUTRAL INST OC 1 BLOCKING Disabled Range Enabled Disabled GND INST OC BLOCKING Disabled Range Enabled Disabled SENSTV GND INST OC BLOCKING Disabled Range Enabled Disabled NEG SEQ INST OC BLOCKING Disabled Range Enabled Disabled PHASE TIME OC 1 RAISED PICKUP 0 Range 0 to 100 in steps of 1 NEUTRAL TIME OC 1 RAISED PICKUP 0 Range 0 to 100 in steps of 1 GND TIME OC RAISED PICKUP ...

Page 191: ...GE Multilin 750 760 Feeder Management Relay 5 127 5 SETPOINTS 5 8 S7 CONTROL 5 Figure 5 77 AUTORECLOSURE SHOTS 1 TO 4 LOGIC Courtesy of NationalSwitchgear com ...

Page 192: ...d protection enabled a transient fault produces a current above the pickup of both Instanta neous Overcurrent 1 loset and Time Overcurrent 1 elements 2 The Time Overcurrent element begins to time and the Instantaneous Overcurrent element operates signaling the breaker to trip and initiate a reclosure 3 The breaker trips and signals the autoreclose scheme that it is now open The Instantaneous Overc...

Page 193: ...RELAYS FUNCTION is set to Enabled Selecting Energized forces the output relay to the energized state while the FORCE OUTPUT RELAYS FUNCTION setpoint is Enabled OUTPUT RELAYS ENTER for more FORCE OUTPUT RELAYS FUNCTION Disabled Range Enabled Disabled FORCE 1 TRIP RELAY De energized Range Energized De energized FORCE 2 CLOSE RELAY De energized Range Energized De energized FORCE 3 AUX RELAY De energi...

Page 194: ... 0 to 100 of the output range Enter the percentage of the DC mA output range to be signaled by the Analog Output 1 2 to 8 for the FORCE A O 1 8 setpoints For example if the relay has been ordered with 4 to 20 mA analog outputs setting this value to 100 will output 20 mA 0 will output 4 mA and 50 will output 12 mA PICKUP TEST ENTER for more PICKUP TEST FUNCTION Disabled Range Enabled Disabled Alway...

Page 195: ...state simulates the faulted operating condition of a feeder by replacing the normal prefault feeder input parameters with programmed fault values The magnitude and angle of each bus voltage and current polarizing current system frequency and analog input are set to the values programmed under the FAULT VALUES setpoints The neutral current is calculated from the vector sum of the phase currents and...

Page 196: ...itored state of the breaker b SETUP PATH SETPOINTS ÖØ S8 TESTING ÖØ SIMULATION Ö SETUP Program SIMULATION STATE to Disabled if actual system inputs are to be monitored If programmed to any other value the relay is in simulation mode and actual system parameters are not monitored The system parameters simulated by the relay will be those in the section below that corresponds to the programmed value...

Page 197: ...ITION 120 Lag Range 0 to 359 Lag in steps of 1 PHASE C N VOLTAGE LEVEL 1 00 x VT Range 0 00 to 2 00 x VT in steps of 0 01 PHASE C N VOLTAGE POSITION 240 Lag Range 0 to 359 Lag in steps of 1 PHASE A CURRENT LEVEL 1 00 x CT Range 0 00 to 20 00 x CT in steps of 0 01 PHASE A CURRENT POSITION 60 Lag Range 0 to 359 Lag in steps of 1 PHASE B CURRENT LEVEL 1 00 x CT Range 0 00 to 20 00 x CT in steps of 0 ...

Page 198: ...line voltages in order to simulate an open breaker condition and allow testing of the synchrocheck feature All phasor angles are referenced to the prefault A N bus voltage at 0 5 9 5 FACTORY SERVICE PATH SETPOINTS ÖØ S8 TESTING ÖØ FACTORY SERVICE These messages are intended for factory use only to perform testing and diagnostics Entering the factory service pass code in the first message allows ac...

Page 199: ...TER for more See page 6 5 HARDWARE INPUTS ENTER for more See page 6 5 LAST TRIP DATA ENTER for more See page 6 6 FAULT LOCATIONS ENTER for more See page 6 7 CLOCK ENTER for more See page 6 7 AR ENTER for more See page 6 7 760 only ACTUAL VALUES A2 METERING CURRENT ENTER for more See page 6 9 VOLTAGE ENTER for more See page 6 10 FREQ ENTER for more See page 6 11 SYNCHRO VOLTAGE ENTER for more See p...

Page 200: ... E127 Mar 15 1997 ENTER for more E1 Mar 14 1997 ENTER for more LAST RESET DATE ENTER for more See page 6 18 ACTUAL VALUES A5 PRODUCT INFO TECHNICAL SUPPORT ENTER for more See page 6 19 REV CODES ENTER for more See page 6 19 CAL DATES ENTER for more See page 6 19 MESSAGE ESCAPE ENTER ESCAPE ð ð MESSAGE ESCAPE MESSAGE ESCAPE MESSAGE ESCAPE MESSAGE ESCAPE ENTER ESCAPE ð ð MESSAGE ESCAPE MESSAGE ESCAP...

Page 201: ...GE Multilin 750 760 Feeder Management Relay 6 3 6 ACTUAL VALUES 6 1 OVERVIEW 6 Figure 6 1 ACTUAL VALUES BLOCK DIAGRAM 1 OF 2 Courtesy of NationalSwitchgear com ...

Page 202: ...6 4 750 760 Feeder Management Relay GE Multilin 6 1 OVERVIEW 6 ACTUAL VALUES 6 Figure 6 2 ACTUAL VALUES BLOCK DIAGRAM 2 OF 2 Courtesy of NationalSwitchgear com ...

Page 203: ... virtual inputs are those that have their INPUT n ASSERTED LOGIC setpoint programmed to monitor the state of the virtual input There are subsequent displays for the remaining virtual inputs 6 2 2 HARDWARE INPUTS PATH ACTUAL VALUES Ö A1 STATUS ÖØ HARDWARE INPUTS These messages display the state of all hardware inputs The top line in the last two values above reflect the names pro grammed in the S6 ...

Page 204: ...AST TRIP Mar 16 1997 Range Date in format shown TIME OF LAST TRIP 12 34 56 789 Range Time in format shown TRIP Φ Cause Range See Section 6 5 A4 Event Recorder on page 6 16 for range details A 0 B 0 C 0 Amps Range 0 to 65535 A GND CURRENT 0 A Range 0 to 65535 A SENSTV GND CURRENT 0 A Range 0 to 655 35 A NEUTRAL CURRENT 0 A Range 0 to 65535 A AN 0 00 BN 0 00 CN 0 00 kVolts Range On Off Seen only if ...

Page 205: ...function The number of reclosures in the past hour is shown in the AR SHOT RATE value This value will be cleared by a RESET AR RATE DATA command via the front panel or communications The AR SHOT COUNT value shows the total number of reclosures since the AR SHOT COUNT LAST RESET date FAULT LOCATION 0 ENTER for more DATE OF FAULT 0 Mar 16 1997 Range Date in format shown TIME OF FAULT 0 12 34 56 789 ...

Page 206: ...otection and monitoring functions Displayed metered quantities are updated approximately three 3 times a second for readability All phasors and symmetrical components are referenced to the A N voltage phasor for wye connected VTs to the A B voltage phasor for delta connected VTs or to the phase A current phasor when no volt age signals are present Figure 6 3 POWER QUANTITY RELATIONSHIPS I2 I2 I1 I...

Page 207: ... A Range 0 to 655535 A PHASE A CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag PHASE B CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag PHASE C CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag NEUTRAL CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag GND CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag SENSTV GND CURRENT 0 00 A 0 Lag Range 0 to 655 35 A 0 to 359 Lag POS SEQ CURRENT 0 A 0 Lag ...

Page 208: ...E 0 00 kV Range 0 to 600 00 kV Seen only if VT CONNECTION TYPE is Wye LINE A B VOLTAGE 0 00 kV 0 Lag Range 0 to 600 00 kV 0 to 359 Lag LINE B C VOLTAGE 0 00 kV 0 Lag Range 0 to 600 00 kV 0 to 359 Lag LINE C A VOLTAGE 0 00 kV 0 Lag Range 0 to 600 00 kV 0 to 359 Lag LINE A N VOLTAGE 0 00 kV 0 Lag Range 0 to 600 00 kV 0 to 359 Lag Seen only if VT CONNECTION TYPE is Wye LINE B N VOLTAGE 0 00 kV 0 Lag ...

Page 209: ...R FREQ ENTER for more SYSTEM FREQ 0 00 Hz Range 0 to 90 00 Hz FREQ DECAY RATE 0 00 Hz s Range 10 00 to 10 00 Hz s SYNCHRO VOLTAGE ENTER for more SYNCHRO VOLTAGE 0 00 kV 0 Lag Range 0 to 600 00 kV 0 to 359 Lag SYNCHRO FREQ 0 00 Hz Range 0 to 90 00 Hz SYNCHRO DELTA 0 0 00 kV 0 00 Hz Range 0 to 359 0 to 600 00 kV 0 to 90 00 Hz PWR ENTER for more 3Φ REAL PWR 0 0 kW Range 30000 to 30000 kW See the Powe...

Page 210: ... more complex these values provide approximate costs Energy quantities auto range to show units appropriate to the nominal power Power quantities in the positive direction are added to the positive values power quantities in the opposite direction are added to the negative values The 750 760 is not a revenue class meter and cannot be used for billing purposes Table 6 1 POWER QUANTITIES NOMINAL POW...

Page 211: ... The actual values displays for Phase B Current Phase C Current Real Power Reactive Power and Apparent Power Demand are similar to those above c LAST RESET DATE PATH ACTUAL VALUES ÖØ A2 METERING ÖØ DMND ÖØ LAST RESET DATE This message displays the last date the maximum demand data was cleared If the date has never been programmed this relay will display Unavailable DMND ENTER for more PHASE A CURR...

Page 212: ...actual values display the name programmed in setpoint message S6 MONITORING ÖØ A I ÖØ A I SETUP Ö A I NAME will be displayed instead of the factory default A I The name of the units programmed in the setpoint message S6 MONITORING ÖØ A I ÖØ A I SETUP ÖØ A I UNITS will be displayed instead of the factory default µA The subsequent actual value messages display the analog input rate of change in per ...

Page 213: ...arcing currents in kA2 cycles since the ARCING CURRENT LAST RESET date are dis played The relay calculates an estimate of the per phase wear on the breaker contacts Arcing current data can be reset to zero with the S1 RELAY SETUP ÖØ INSTALLATION ÖØ RESET ARCING CURRENT DATA setpoint command TRIP COUNTERS ENTER for more BRKR TRIPS 0 Range 0 to 65535 GND OC TRIPS 0 Range 0 to 65535 SENSTV GND OC TRI...

Page 214: ... Table 6 3 Cause of Events on page 6 18 PHASE A CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag PHASE B CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag PHASE C CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag GND CURRENT 0 A 0 Lag Range 0 to 65535 A 0 to 359 Lag SENSTV GND CURRENT 0 00 A 0 Lag Range 0 to 655 35 A 0 to 359 Lag LINE A B VOLTAGE 0 00 kV 0 Lag Range 0 to 65535 kV 0 to 359 Lag LIN...

Page 215: ...T TYPE DISPLAY DESCRIPTION General Events None Events that occur when a specific operation takes place Pickup Events PICKUP Φ These are events that occur when a protection element picks up and starts timing Trip Events TRIP Φ These are events that occur when an element whose function has been programmed to Trip or Trip AR operates Alarm Events ALARM Φ These are events that occur when an element wh...

Page 216: ...Gnd Inst OC Trip Coil Monitor Trip Counter UFreq Restore Init Underfrequency 1 Underfrequency 2 User Input A to T 3 UVolt Restore Init VT Failure LOGIC INPUT EVENT CAUSES 52a Contact 52b Contact Block 1 Trip Block 2 Close Block All OC Block Freq Decay Block Gnd Inst OC Block Gnd Time OC Block Ground OC Block Neg Seq Inst Block Neg Seq Time Block Neg Seq Volt Block Neutral Disp Block Neutral Inst O...

Page 217: ...ilin com The GE Multilin web page address is indicated here REV CODES ENTER for more GE Multilin 750 REVISION 4 00 The product name and software revision are indicated HARDWARE REV H Displays the hardware revision of the relay S W REV 400 Displays the software revision of the relay VERSION NUMBER 000 Displays the version number of the relay indicating any special modification number ORDER CODE 760...

Page 218: ...6 20 750 760 Feeder Management Relay GE Multilin 6 6 A5 PRODUCT INFO 6 ACTUAL VALUES 6 Courtesy of NationalSwitchgear com ...

Page 219: ...32 RS422 RS485 fiber optics etc The 750 760 includes a front panel RS232 port and two rear terminal RS485 ports one of which can also be configured as RS422 Data flow is half duplex in all con figurations See Section 3 2 10 RS485 and RS422 Communications on page 3 16 for details on wiring Each data byte is transmitted in an asynchronous format consisting of 1 start bit 8 data bits 1 stop bit and p...

Page 220: ...based on the packet but none will respond to the master Broadcast mode is only recognized when associated with Function Codes 05h 06h and 10h For any other function code a packet with broadcast mode slave address 0 will be ignored See Section 7 3 3 Clock Synchronization of Multiple Relays on page 7 8 for an example of broadcast mode Function Code This is one of the supported functions codes of the...

Page 221: ...acteristic polynomial 1010000000000001 binary with MSbit dropped and bit order reversed shr x right shift operator the LSbit of x is shifted into a carry flag a 0 is shifted into the MSbit of x all other bits are shifted right one location Algorithm 1 FFFF hex A 2 0 i 3 0 j 4 Di Alow Alow 5 j 1 j 6 shr A 7 Is there a carry No go to step 8 Yes G A A and continue 8 Is j 8 No go to 5 Yes continue 9 i...

Page 222: ... responds with the bit values 1 0 1 1 0 0 1 0 0 and 1 from binary status addresses 13h through 1Ch inclusive Note that two bytes are required to contain the response data The first byte contains the first eight data bits stored in the least significant to the most significant bit posi tion The second byte contains the last two data bits stored in the least two significant bit positions Note that t...

Page 223: ... hi and lo Code Value bytes always have the values FFh and 00h respectively and are a remnant of the original Modbus definition of this function code MASTER QUERY MESSAGE EXAMPLE HEX SLAVE ADDRESS 11 query message for slave 11 FUNCTION CODE 03 read register values DATA STARTING ADDRESS high order byte low order byte 02 00 data starting at address 0200 NUMBER OF REGISTERS high order byte low order ...

Page 224: ...the same function as the CLEAR EVENT RECORDER DATA command 000A RESET TRIP COUNTER DATA Performs the same function as the RESET TRIP COUNTER DATA command 000B RESET ARCING CURRENT DATA Performs the same function as the RESET ARCING CURRENT DATA command 000C DISPLAY OVERRIDE PACKET Displays the 40 character 20 register Override_Packet addresses 10B1 to 10C4 hex for the time specified in Override_Ti...

Page 225: ...slave device 11 MASTER QUERY MESSAGE EXAMPLE HEX SLAVE ADDRESS 11 query message for slave 11 FUNCTION CODE 10 store multiple setpoint values DATA STARTING ADDRESS high order byte low order byte 11 00 data starting at address 1100 NUMBER OF SETPOINTS high order byte low order byte 00 02 2 setpoint values 4 bytes total BYTE COUNT 04 4 bytes of data DATA 1 high order byte low order byte 00 C8 data fo...

Page 226: ...ocation 04 FAILURE IN ASSOCIATED DEVICE An external device connected to the addressed slave device has failed and the data requested cannot be sent This response will be returned if a GE Multilin device connected to the RS485 external device port of the 745 has failed to respond to the 750 760 05 ACKNOWLEDGE The addressed slave device has accepted and is processing a long duration command Poll for...

Page 227: ... The following example illustrates how information can be retrieved from the Event Recorder A SCADA system polls the Number of Events register once every minute It now reads a value of 27 from the register when previously the value was 24 which means that three new events have occurred The SCADA system writes a value of 25 to the Event Number Selector register It then reads the data for event numb...

Page 228: ...ex and Trigger Index which determine how to unravel the data samples see the description of the circular data structure below The Trace Memory Channel Selector determines which data channel samples can be read from the Trace Memory Sam ples registers at addresses 2120h to 215Fh refer to format F26 for a complete listing of the available data channels For example to read Vc voltage samples a value ...

Page 229: ...rates this is less important but when sampling is per formed at a high rate it is very likely that the start index will move between subsequent reads of the memory map The Data Log Trigger Index will always index the last sample added to the buffer Thus it too will also be quickly and continuously changing if the sampling rate is high The Data Log Trigger Cause will be set to zero and the time and...

Page 230: ...would be the address required by the Modbus communications driver similarly if address 320h 800d was to be read then 40801d would be the address required by the Modbus com munications driver Table 7 4 USER MAP REGISTER ADDRESSES DATA REGISTER DESCRIPTION VALUES TO STORE IN USER MAP ADDRESSES LOCATIONS IN USER MAP VALUES TO READ DATA General Status Store 0200h at 0180h 0100h Active Condition Store ...

Page 231: ...al Input 20 F66 Not Asserted SET TIME DATE READ WRITE 00F01 Set Time 2 words F22 00F21 Set Date 2 words F23 USER MAP VALUES READ ONLY 0100 User Map Value 1 0101 User Map Value 2 0177 User Map Value 120 USER MAP ADDRESSES READ WRITE 0180 User Map Address 1 0000 to FFFF hex F1 0 0181 User Map Address 2 0000 to FFFF hex F1 0 01F7 User Map Address 120 0000 to FFFF hex F1 0 A1 SYSTEM STATUS READ ONLY 0...

Page 232: ... B N B C Voltage 0 00 to 600 00 kV F3 02EB Last Trip C N C A Voltage 0 00 to 600 00 kV F3 02EC Last Trip System Frequency 0 00 to 90 00 Hz F3 02ED Last Trip Analog Input 0 to 65535 Units F1 02EE Last Trip Neutral Current 0 to 65535 A F1 02EF3 Last Trip Sensitive Ground Current 0 00 to 655 35 A F3 02F05 Last Trip Neutral Voltage 0 00 to 655 35 kV F3 A2 CURRENT AND VOLTAGE READ ONLY 02FE5 Neutral Vo...

Page 233: ...5 A F1 0331 Last Phase B Current Demand 0 to 65535 A F1 0332 Last Phase C Current Demand 0 to 65535 A F1 03332 Last Real Power Demand 30000 to 30000 kW F86 03342 Last Reactive Power Demand 30000 to 30000 kvar F86 03352 Last Apparent Power Demand 0 to 30000 kVA F86 A2 MAXIMUM DEMAND READ ONLY 0340 Maximum Phase A Current Demand 0 to 65535 A F1 0341 Maximum Phase A Current Date 2 words F23 0343 Maxi...

Page 234: ...ensitive Ground Overcurrent Trips 0 to 65535 F1 A3 TOTAL ARCING CURRENT READ ONLY 03A0 Total Arcing Current Phase A 0 to 65535 kA2 cyc F1 03A1 Total Arcing Current Phase B 0 to 65535 kA2cyc F1 03A2 Total Arcing Current Phase C 0 to 65535 kA2 cyc F1 03A3 Total Arcing Current Last Reset 2 words F23 A1 FAULT LOCATION 1 READ ONLY 03B0 Date of Fault 2 words F23 03B2 Time of Fault 2 words F22 03B4 Type ...

Page 235: ... words F23 03F2 Time of Fault 2 words F22 03F4 Type of Fault F76 03F5 Distance to Fault 327 68 to 327 67 km F52 03F6 Line Z1 to Fault magnitude 0 00 to 655 35 Ω F53 A1 FAULT LOCATION 10 READ ONLY 03F8 Date of Fault 2 words F23 03FA Time of Fault 2 words F22 03FC Type of Fault F76 03FD Distance to Fault 327 68 to 327 67 km F52 03FE Line Z1 to Fault magnitude 0 00 to 655 35 Ω F53 A2 CURRENT PHASE AN...

Page 236: ...062 Neutral Time Overcurrent 1 F49 06072 Neutral Time Overcurrent 2 F49 06082 Neutral Instantaneous Overcurrent 1 F49 06092 Neutral Instantaneous Overcurrent 2 F49 060A2 Phase Directional is Reverse F49 060B2 Neutral Directional is Reverse F49 060C Manual Close Blocking F49 060D Cold Load Pickup Blocking F49 060E Bus Undervoltage 1 F49 060F Bus Undervoltage 2 F49 0610 Line Undervoltage 3 F49 0611 ...

Page 237: ...ulse Output Positive Watthours F49 06415 Pulse Output Negative Watthours F49 06425 Pulse Output Positive Varhours F49 06435 Pulse Output Negative Varhours F49 06446 Ground Directional is Reverse F49 06457 Reserved for MOD 010 F49 06468 User Input I F49 06478 User Input J F49 06488 User Input K F49 06498 User Input L F49 064A8 User Input M F49 064B8 User Input N F49 064C8 User Input O F49 064D8 Use...

Page 238: ...AD WRITE 1040 User Text Message 1 20 words F33 Text 1 1054 User Text Message 2 20 words F33 Text 2 1068 User Text Message 3 20 words F33 Text 3 107C User Text Message 4 20 words F33 Text 4 1090 User Text Message 5 20 words F33 Text 5 S1 OVERRIDE MESSAGE READ WRITE 10B0 Override Message Display Time 0 to 9000 s F1 0 s 10B1 Override Message 20 words F33 This is a test S1 COMMUNICATIONS READ WRITE 10...

Page 239: ... 0 kWh F2 5 0 kWh 11083 Reserved for Polarizing CT Primary 1109 Line VT Connection F18 Vbn 110A Line Nominal VT Secondary Voltage 50 0 to 240 0 V F2 120 0 V 110B Line VT Ratio 1 0 to 5000 0 xxx 1 F1 120 0 1 110C1 Phase Sequence F83 ABC 110D3 Sensitive Ground CT Primary 1 to 50000 A F1 1000 A S3 LOGIC INPUT ASSERTED LOGIC READ WRITE 11402 Logic Input 1 Asserted Logic F63 Contact Close 11412 Logic I...

Page 240: ...EAD WRITE 11C0 User Input E Name 9 registers F33 User Input E 11C9 User Input E Source F65 Disabled 11CA User Input E Function F37 Disabled 11CB User Input E Relays F57 None 11CC User Input E Delay 0 00 to 600 00 s F3 0 00 s S3 USER INPUT F READ WRITE 11D0 User Input F Name 9 registers F33 User Input F 11D9 User Input F Source F65 Disabled 11DA User Input F Function F37 Disabled 11DB User Input F ...

Page 241: ...126B2 Block Neutral Instantaneous Overcurrent 1 F65 Disabled 126C2 Block Neutral Instantaneous Overcurrent 2 F65 Disabled 126D Block Negative Sequence Time Overcurrent F65 Disabled 126E Block Negative Sequence Instantaneous Overcurrent F65 Disabled 126F Block Phase Time Overcurrent 2 F65 Disabled 12703 Block All Sensitive Ground Overcurrent F65 Disabled 12713 Block Sensitive Ground Instantaneous O...

Page 242: ...Relay 6 AUXILIARY Pulse Dwell Time 0 1 to 6000 0 s F2 0 1 s S4 RELAY 7 AUXILIARY READ WRITE 1360 Relay 7 AUXILIARY Name 8 words F33 AUXILIARY 1368 Relay 7 AUXILIARY Non operated State F34 De energized 1369 Relay 7 AUXILIARY Output Type F35 Self resetting 136A Relay 7 AUXILIARY Pulse Dwell Time 0 1 to 6000 0 s F2 0 1 s S38 USER INPUT I READ WRITE 13708 User Input I Name 9 registers F33 User Input I...

Page 243: ... 9 registers F33 User Input Q 13F98 User Input Q Source F65 Disabled 13FA8 User Input Q Function F37 Disabled 13FB8 User Input Q Relays F57 None 13FC8 User Input Q Delay 0 00 to 600 00 s F3 0 00 s S38 USER INPUT R READ WRITE 14008 User Input R Name 9 registers F33 User Input R 14098 User Input R Source F65 Disabled 140A8 User Input R Function F37 Disabled 140B8 User Input R Relays F57 None 140C8 U...

Page 244: ... ms 144D FlexCurve A Trip Time at 3 80 x PU 0 to 65535 ms F1 0 ms 144E FlexCurve A Trip Time at 3 90 x PU 0 to 65535 ms F1 0 ms 144F FlexCurve A Trip Time at 4 00 x PU 0 to 65535 ms F1 0 ms 1450 FlexCurve A Trip Time at 4 10 x PU 0 to 65535 ms F1 0 ms 1451 FlexCurve A Trip Time at 4 20 x PU 0 to 65535 ms F1 0 ms 1452 FlexCurve A Trip Time at 4 30 x PU 0 to 65535 ms F1 0 ms 1453 FlexCurve A Trip Ti...

Page 245: ...ords see FlexCurve A 0 to 65535 ms F1 0 ms S5 PHASE TIME OVERCURRENT 1 READ WRITE 1500 Phase Time Overcurrent 1 Function F37 Trip 1501 Phase Time Overcurrent 1 Relays F57 None 15022 Phase Time Overcurrent 1 Curve F36 Ext Inverse 1503 Phase Time Overcurrent 1 Voltage Restraint F30 Disabled 15041 Phase Time Overcurrent 1 Pickup 0 05 to 20 00 x CT F3 1 00 x CT 15051 Phase Time Overcurrent 1 Multiplie...

Page 246: ...d Directional Maximum Torque Angle 0 to 359 Lead F1 315 16106 Ground Directional Minimum Polarizing Voltage 0 00 to 1 25 x VT F3 0 05 x VT 16116 Ground Directional Polarizing F50 Voltage 16126 Ground Directional Relays F57 None S5 NEUTRAL TIME OVERCURRENT 1 READ WRITE 1630 Neutral Time Overcurrent 1 Function F37 Disabled 1631 Neutral Time Overcurrent 1 Relays F57 None 1632 Neutral Time Overcurrent...

Page 247: ...S5 NEGATIVE SEQUENCE VOLTAGE READ WRITE 1720 Negative Sequence Voltage Function F39 Disabled 1721 Negative Sequence Voltage Relays F57 None 17222 Negative Sequence Voltage Pickup 0 00 to 1 25 x VT F3 0 10 1723 Negative Sequence Voltage Delay 0 0 to 6000 0 s F2 2 0 s S5 NEGATIVE SEQUENCE DIRECTIONAL READ WRITE 17301 Negative Sequence Directional Function F38 Disabled 17311 Neg Seq Directional Maxim...

Page 248: ... 0 to 6000 0 s F2 2 0 s 178C Bus Undervoltage 2 Phases Required for Operation F41 All Three 178D2 Bus Undervoltage 2 Minimum Operating Voltage 0 00 to 1 25 x VT F3 0 30 x V 178E Bus Undervoltage 2 Curve F45 Definite Time S5 OVERVOLTAGE 1 READ WRITE 1790 Overvoltage 1 Function F39 Disabled 1791 Overvoltage 1 Relays F57 None 17922 Overvoltage 1 Pickup 0 00 to 1 25 x VT F3 1 25 x VT 1793 Overvoltage ...

Page 249: ...ay Minimum Operating Current 0 00 to 20 00 x CT F3 0 00 x CT S55 REVERSE POWER requires Mod 008 READ WRITE 17C8 Reverse Power Function F39 Disabled 17C9 Reverse Power Relays F57 None 17CA Reverse Power Pickup 0 015 to 0 600 x RATED F70 0 050 x RATED 17CB Reverse Power Delay 0 0 to 6000 0 s F2 10 0 s S55 NEUTRAL DISPLACEMENT READ WRITE 17CE Neutral Displacement Function F39 Disabled 17CF Neutral Di...

Page 250: ...F57 None 184D2 Real Power Demand Pickup 1 to 3000 0 MW F86 100 MW S6 REACTIVE POWER DEMAND READ WRITE 1850 Reactive Power Demand Function F38 Disabled 1851 Reactive Power Demand Measurement Type F58 Block Interval 1852 Reactive Power Demand Thermal 90 Response F16 15 min 1853 Reactive Power Demand Time Interval F16 20 min 1854 Reactive Power Demand Relays F57 None 18552 Reactive Power Demand Picku...

Page 251: ... 60000 s F1 0 s S6 ANALOG INPUT RATE 2 READ WRITE 18B8 Analog In Rate 2 Function F38 Disabled 18B9 Analog In Rate 2 Relays F57 None 18BA Analog In Rate 2 Pickup 1000 0 to 1000 0 Units hr F5 10 0 µA hr 18BB Analog In Rate 2 Delay 0 to 60000 s F1 0 s S6 ANALOG OUTPUT 1 READ WRITE 18C0 Analog Output 1 Parameter F77 Disabled 18C1 Analog Output 1 Minimum F78 0 18C2 Analog Output 1 Maximum F78 0 S6 ANAL...

Page 252: ...0 to 20 00 x CT F3 0 50 x CT 1931 Prefault Power Factor Angle 0 to 359 Lag F1 0 Lag S8 SIMULATION FAULT VALUES READ WRITE 1940 Fault Phase A N Voltage Level 0 00 to 2 00 x VT F3 1 00 x VT 1941 Fault Phase A N Voltage Position 0 to 359 Lag F1 0 Lag 1942 Fault Phase B N Voltage Level 0 00 to 2 00 x T F3 1 00 x VT 1943 Fault Phase B N Voltage Position 0 to 359 Lag F1 120 Lag 1944 Fault Phase C N Volt...

Page 253: ...oil Monitor 2 Relays F57 None 199A Breaker State Bypass F30 Disabled 199B8 Coil Monitor 2 Delay 5 to 100 s F1 5 s 199C8 Coil Monitor 2 Type F90 Close S68 COIL MONITOR NAMES READ WRITE 19A08 Coil Monitor 1 Name 9 registers F33 Trip Coil Monitor 19A98 Coil Monitor 2 Name 9 registers F33 Close Coil Monitor S68 ANALOG INPUT THRESHOLD NAMES READ WRITE 19B28 Analog Input Threshold 1 Name 9 registers F33...

Page 254: ...1B231 Select Setpoint Group F80 Active Group 1B242 Overcurrent Blocking Flags F59 None blocked 1B252 Phase Time Overcurrent 1 Raised Pickup 0 to 100 F1 0 1B262 Neutral Time Overcurrent 1 Raised Pickup 0 to 100 F1 0 1B272 Ground Time Overcurrent Raised Pickup 0 to 100 F1 0 1B282 Negative Sequence Time Overcurrent Raised Pickup 0 to 100 F1 0 1B293 Sensitive Ground Time Overcurrent Raised Pickup 0 to...

Page 255: ...Supervision Function F38 Disabled 1BAB8 Max Autoreclose Rate 1 to 50 hr F1 25 1BAC8 Rate Supervision Relays F57 None S7 CURRENT SUPERVISION 760 ONLY READ WRITE 1BB0 Current Supervision Function F30 Disabled 1BB12 3 Shots For Current Above 0 00 to 20 00 x CT F3 17 00 x CT 1BB22 2 Shots For Current Above 0 00 to 20 00 x CT F3 18 00 x CT 1BB32 1 Shot For Current Above 0 00 to 20 00 x CT F3 19 00 x CT...

Page 256: ...ed Pickup 0 to 100 F1 0 S3 LOGIC INPUTS NAMES READ WRITE 1C001 Logic Input 1 Name 9 words 18 characters F33 Logic Input 1 1C091 Logic Input 2 Name 9 words 18 characters F33 Logic Input 2 1CAB1 Logic Input 20 Name 9 words 18 characters F33 Logic Input 20 A4 EVENT RECORD SELECTOR READ WRITE 2000 Event Number Selector 0 to 65535 F1 0 A4 EVENT RECORDOR INFORMATION READ ONLY 2001 Number of Events Since...

Page 257: ...0 TRACE MEMORY INFORMATION READ ONLY 2110 Number of Trace Memory Triggers Since Clear 0 to 65535 F1 2111 Number of Trace Memory Samples Stored 0 to 4096 F1 2112 Trace Memory Start Index 0 to 4095 F1 2113 Trace Memory Trigger Index 0 to 4095 F1 2114 Trace Memory Trigger Cause F24 2115 Trace Memory Trigger Date F23 2117 Trace Memory Trigger Time F22 2119 Trace Memory Sampling Frequency 16 00 to 65 0...

Page 258: ...6 bits Example 1234 56 stored as 123456 F13 HARDWARE REVISION 1 A 2 B 26 Z F14 SOFTWARE REVISION 0F00h Major Revision Number 0 to 9 in steps of 1 00F0h Minor Revision Number 0 to 9 in steps of 1 000Fh Ultra Minor Revision No 0 to 9 in steps of 1 Example Revision 2 83 stored as 0283 hex F15 INSTALLED OPTIONS 0001h Phase Current Inputs 0 1 A 1 5 A 0002h Ground Current Input 0 1 A 1 5 A 0004h3 Sens G...

Page 259: ...T 3 OF 17 TYPE VALUE DESCRIPTION 1 2 3 4 5 6 7 8 9 For explanation of footnotes see notes of end of Table F24 ctd 16 Reset Arcing Current 17 Display Override Message 18 Trigger Data Logger 20 Transfer Initiated 21 Transfer Not Ready 22 Close From Transfer 23 Trip From Transfer 30 Reclosure 1 760 only 31 Reclosure 2 760 only 32 Reclosure 3 760 only 33 Reclosure 4 760 only 34 Reclosure Lockout 760 o...

Page 260: ...r Input K 73 7 User Input L 74 7 User Input M 75 7 User Input N 76 7 User Input O Table 7 7 MEMORY MAP DATA FORMATS SHEET 5 OF 17 TYPE VALUE DESCRIPTION 1 2 3 4 5 6 7 8 9 For explanation of footnotes see notes of end of Table F24 ctd 77 7 User Input P 78 7 User Input Q 79 7 User Input R 80 7 User Input S 81 7 User Input T 82 7 Autoreclose Rate 760 ONLY 83 7 Restricted Earth Fault LOGIC INPUT EVENT...

Page 261: ...VALUE DESCRIPTION 1 2 3 4 5 6 7 8 9 For explanation of footnotes see notes of end of Table F24 ctd 8 Internal Temperature 9 Clock Not Set 10 Prototype Software 11 Not Calibrated 12 Force Relays 13 Force Analog Out 14 Simulation Mode 15 Pickup Test 16 Factory Service Mode 17 IRIG B Failure 18 7 Not Used 19 7 Not Used 20 7 RTC Crystal F25 2 s COMPLEMENT SIGNED VALUE To convert phase currents to Amps...

Page 262: ...Relay 8 Aux 0 not operated 1 operated F41 CURRENT VOLTAGE PHASES 1 Any One 2 Any Two 3 All Three F422 ANALOG INPUT RANGE 0 0 1 mA 1 0 5 mA 2 4 20 mA 3 0 20 mA 41 0 10 mA F432 IRIG B SIGNAL TYPE 0 None 1 DC Shift 2 Amplitude Modulated F44 OUT OF SERVICE STATES 0001h Major Internal Failure 0 disabled 1 enabled 0002h Minor Internal Failure 0 disabled 1 enabled 0004h Testing Mode 0 Disabled 1 Enabled ...

Page 263: ...ED 7 0 Off 1 On 0080h LED 8 Bottom 0 Off 1 On F55 FRONT PANEL KEY 0 0 1 1 2 2 3 3 4 4 5 5 6 6 7 7 8 8 9 9 10 13 Value Up 14 Value Down 15 Message Up Table 7 7 MEMORY MAP DATA FORMATS SHEET 11 OF 17 TYPE VALUE DESCRIPTION 1 2 3 4 5 6 7 8 9 For explanation of footnotes see notes of end of Table F55 ctd 16 Message Down 17 Next 18 Enter 19 Escape 20 Setpoints 21 Actual 22 Reset 23 Open 24 Close 25 Hel...

Page 264: ...MORY MAP DATA FORMATS SHEET 13 OF 17 TYPE VALUE DESCRIPTION 1 2 3 4 5 6 7 8 9 For explanation of footnotes see notes of end of Table F74 ctd 4 10 minutes 5 15 minutes 6 20 minutes 7 30 minutes 8 60 minutes F75 UNITS OF LENGTH 0 km 1 Miles F76 TYPE OF FAULT 0001h øA 0 Not involved 1 Involved 0002h øB 0 Not involved 1 Involved 0004h øC 0 Not involved 1 Involved 0008h Ground 0 Not involved 1 Involved...

Page 265: ...itive Ground Current Angle 79 4 Neutral Voltage 80 4 Neutral Voltage Angle Table 7 7 MEMORY MAP DATA FORMATS SHEET 15 OF 17 TYPE VALUE DESCRIPTION 1 2 3 4 5 6 7 8 9 For explanation of footnotes see notes of end of Table F78 2 ANALOG OUTPUT MINIMUM MAXIMUM The Range Step Value and Units for the Analog Output Minimum and Maximum depends upon the parameter type programmed for the output The following...

Page 266: ...es before scaling by the multiplier is k All power quantities are signed single word registers F4 All energy quantities are unsigned double word registers F7 The multiplier is determined from the nominal power which is defined as the product of three setpoints PN Phase CT Primary x Bus VT Secondary Voltage x Bus VT Ratio Example If the 3φ Real Power register 0310 has a value of 123 and the Multipl...

Page 267: ...og Input Change Object 32 Variations 1 2 3 and 4 Warm Restart Function code 14 Maximum Data Link Frame Size octets Transmitted 292 Received 292 Maximum Application Fragment Size octets Transmitted 2048 Received 2048 Maximum Data Link Re tries None Fixed Configurable Note 1 Maximum Application Layer Re tries None Configurable Requires Data Link Layer Confirmation Never Always Sometimes Configurable...

Page 268: ...g Binary Output Control Relay Output point list Queue Never Always Sometimes Configurable Clear Queue Never Always Sometimes Configurable Reports Binary Input Change Events when no specific variations requested Never Only time tagged Only non time tagged Configurable to send both one or the other Reports time tagged Binary Input Change Events when no specific variation requested Never Binary Input...

Page 269: ...tions 1 06 1 1 Binary Input 1 00 01 06 129 00 01 1 2 Binary Input With Status 1 00 01 06 129 00 01 2 0 Binary Input Change All Variations 1 06 07 08 2 1 Binary Input Change Without Time 1 06 07 08 129 17 28 2 2 Binary Input Change With Time 1 06 07 08 129 17 28 10 0 Binary Output All Variations 1 06 10 2 Binary Output Status 1 00 01 06 129 00 01 12 1 Control Relay Output Block 3 4 5 6 17 28 129 17...

Page 270: ... 3 Protection Picked Up Class 1 25 Contact Input 7 Closed Class 1 4 Setpoint Group 1 Active Class 1 26 Contact Input 8 Closed Class 1 5 Setpoint Group 2 Active Class 1 27 Contact Input 9 Closed Class 1 6 Setpoint Group 3 Active Class 1 28 Contact Input 10 Closed Class 1 7 Setpoint Group 4 Active Class 1 29 Contact Input 11 Closed Class 1 8 Breaker Is Open Class 1 30 Contact Input 12 Closed Class 1...

Page 271: ... value in this field will cause the virtual input to be turned off The Breaker Control point 23 will only accept a Trip or Close value A value of Trip will activate the Breaker Open function Similarly a value of Close will activate the Breaker Close function All operations not defined above are invalid and will be rejected 3 The On Time and Off Time fields are ignored A Pulse On Code takes effect ...

Page 272: ...TION EVENT CLASS ASSIGNED NOTES DISABLED ENABLED n a 0 User Map Value 1 n a 1 User Map Value 2 n a 118 User Map Value 119 n a 119 User Map Value 120 0 120 F49 Phase Time Overcurrent 1 Class 1 1 121 F49 Phase Instantaneous Overcurrent 1 Class 1 2 122 F49 Phase Instantaneous Overcurrent 2 Class 1 3 123 F49 Ground Time Overcurrent Class 1 4 124 F49 Ground Instantaneous Overcurrent Class 1 5 125 F49 N...

Page 273: ...storation Class 1 54 174 F49 Underfrequency Restoration Class 1 55 175 F49 Phase Time Overcurrent 2 Class 1 56 176 F49 Frequency Decay Class 1 57 177 F49 Negative Sequence Directional Is Reverse Class 1 58 178 F49 Sensitive Ground Instantaneous Overcurrent Class 1 59 179 F49 Sensitive Ground Time Overcurrent Class 1 60 180 F49 Sensitive Ground Directional Is Reverse Class 1 61 181 F1 Phase A RMS C...

Page 274: ...log Input Class 1 98 218 F1 Last Trip Neutral Current Class 1 99 219 F23 Date Of Fault 1 Upper 16 Bits See Note 1 Class 3 Note 1 100 220 F23 Date Of Fault 1 Lower 16 Bits See Note 1 Class 3 Note 1 101 221 F22 Time Of Fault 1 Upper 16 Bits See Note 1 Class 3 Note 1 102 222 F22 Time Of Fault 1 Lower 16 Bits See Note 1 Class 3 Note 1 103 223 F76 Type Of Fault 1 Class 3 104 224 F52 Distance To Fault 1...

Page 275: ...1 143 263 F22 Time Of Fault 7 Upper 16 Bits See Note 1 Note 1 144 264 F22 Time Of Fault 7 Lower 16 Bits See Note 1 Note 1 145 265 F76 Type Of Fault 7 146 266 F52 Distance To Fault 7 147 267 F53 Line Z1 To Fault 7 Magnitude 148 268 F23 Date Of Fault 8 Upper 16 Bits See Note 1 Note 1 149 269 F23 Date Of Fault 8 Lower 16 Bits See Note 1 Note 1 150 270 F22 Time Of Fault 8 Upper 16 Bits See Note 1 Note...

Page 276: ...wing beginning with Point Index 120 The value read from points 0 through 119 will depend upon the value pro grammed into the corresponding User Map Address setpoint note that programming of these setpoints can only be accomplished via Modbus Refer to Section 7 3 7 Accessing Data via the User Map on page 7 11 for more informa tion Please note that changes in User Map Values never generate event obj...

Page 277: ...cteristic of every relay feature The various features are implemented in software which is thoroughly tested at the factory Our recommendation is to field test all of the input display and output hardware and features which are to be operational in the specific application The setpoints considered for the measurement of parameters and the operation of features are shown on the logic dia grams All ...

Page 278: ...ed in the Trace Memory All metering calculations and logic associated with protection monitor ing and control are performed normally using phasors calculated from the samples placed in the memory instead of pha sors generated from the input parameter data acquisition system The advantage of simulation is that all metering calculations can be verified without the inaccuracies associated with curren...

Page 279: ...T CONTROL POWER FILTER GND SAFETY GND BUS Ic Ig Ib Ia E2 F2 E3 F3 E4 F4 E5 C10 C11 1 TRIP 2 CLOSE 3 ALARM START TRIGGER STOP TRIGGER INTERVAL TIMING DEVICE Ω MULTIMETER 818776A5 CDR 750 760 Va START Va Va Ia Ia Va Vb Vb Vc Ib Ib Vb Vc Vc Vb Ic Ic POWER MULTIMETER VARIABLE DCmA SOURCE 3 VARIABLE SOURCE φ Vc Vn Vn Vcom G7 G5 G6 G8 G9 G10 A1 G12 G11 H7 H5 H6 H8 H9 H10 A2 H11 H12 ANALOG INPUT CONTROL ...

Page 280: ...t Recorder that the selected function has been invoked 3 4 Set the monitored contact for the logic input programmed in setpoint USER INPUT A SOURCE to the open state Again note that the corresponding virtual input will have no affect 3 5 Check that the diagnostic message is removed from the display with the Auxiliary LED and relay deactivated 3 6 Repeat Steps 3 1 through 3 7 for all functions prog...

Page 281: ... 3 auxiliary LED and relay deactivated 7 3 Set the monitored contact to the closed state with the virtual input remaining in the off state Check that no diag nostic message is on the display with the Auxiliary LED and relay deactivated 7 4 Leave the monitored contact in the closed state and put the virtual input in the on state Check that the diagnos tic message either User Input A or the name pro...

Page 282: ...cted function has been invoked 10 5 Set the monitored contact to the closed state and the virtual input to the on state Check that the diagnostic message is removed from the display with the Auxiliary LED and relay deactivated 10 6 Repeat steps 10 3 through 10 7 for all functions programmed to be asserted by a Open Voff input 11 For INPUT ASSERTED LOGIC setpoints set to Closed Von 11 1 Check that ...

Page 283: ... the Event Recorder that the selected function has been invoked 14 3 Leave the monitored contact in the open state and put the virtual input in the off state Check that the diagnostic message the Auxiliary LED and relay remain activated 14 4 Set the monitored contact to the closed state and leave the virtual input in the off state Check that the diagnos tic message the Auxiliary LED and relay rema...

Page 284: ... tic message is removed from the display with the Auxiliary LED and relay deactivated 17 6 Repeat steps 17 3 through 17 7 for all functions programmed to be asserted by a Open X Von input 18 For INPUT ASSERTED LOGIC setpoints set to Open X Voff 18 1 Check that there is no logic input diagnostic message on the display 18 2 Set the monitored contact for the logic input programmed in setpoint message...

Page 285: ... Check that the Trip output is energized i e N O contacts closed and the Trip LED is illuminated 5 Make the following setting change S8 TESTING Ö OUTPUT RELAYS ÖØ FORCE 1 TRIP RELAY De energized 6 Repeat Steps 3 through 5 for Output Relays 2 through 8 inclusive 7 Observing polarity connect a minimum 5 V DC source in series with a limiting resistor that will permit a minimum cur rent of 100 mA in s...

Page 286: ...ÖØ CURRENT as follows GND CURRENT Phasor SENSTV GND CURRENT Phasor 1 Inject current of various values into the relay ground input Terminals G10 H10 and note the current 2 Inject current of various values into the relay sensitive ground input Terminals G3 H3 and note the current b PERCENT OF LOAD TO TRIP For these tests refer to the figures on page 8 3 for test connections The expected accuracy is ...

Page 287: ...s refer to the figures on page 8 3 for test connections The expected accuracy is as follows Frequency 0 02 Hz of injected value within the range 16 00 to 90 00 Hz Undervoltage Inhibit 10 V secondary The procedure for testing the metered bus voltage frequency is as follows 1 The relevant actual values display is located as follows A2 METERING ÖØ FREQ ÖØ SYSTEM FREQ 2 Inject a voltage of nominal val...

Page 288: ...s 50 to 130 V Varhours 2 of full scale currents 5 to 199 of nominal voltages 50 to 130 V The procedure for metered reactive power and energy is as follows 1 The relevant actual values displays are shown below A2 METERING ÖØ PWR ÖØ 3Φ REACTIVE PWR A2 METERING ÖØ PWR ÖØ ΦA REACTIVE PWR not available when connected Delta A2 METERING ÖØ PWR ÖØ ΦB REACTIVE PWR not available when connected Delta A2 METE...

Page 289: ...etpoint for the element The relevant actual values displays are shown below A2 METERING ÖØ DMND Ö PHASE A CURRENT Ö LAST PHASE A CURRENT DMND A2 METERING ÖØ DMND Ö PHASE A CURRENT ÖØ MAX PHASE A CURRENT DMND A2 METERING ÖØ DMND Ö PHASE A CURRENT ÖØ MAX PHASE A CURRENT DATE A2 METERING ÖØ DMND ÖØ PHASE A CURRENT ÖØ MAX PHASE A CURRENT TIME A2 METERING ÖØ DMND ÖØ PHASE B CURRENT Ö LAST PHASE B CURRE...

Page 290: ...ter is watts c REACTIVE POWER DEMAND For these tests refer to the figures on page 8 3 for test connections The expected accuracy is as follows Expected Accuracy 2 0 of full scale The relevant actual values displays are shown below A2 METERING ÖØ DMND ÖØ REACTIVE PWR Ö LAST REACTIVE PWR DMND A2 METERING ÖØ DMND ÖØ REACTIVE PWR ÖØ MAX REACTIVE PWR DMND A2 METERING ÖØ DMND ÖØ REACTIVE PWR ÖØ MAX REAC...

Page 291: ...ject steady values of DC current in mA of various values into relay terminals A1 and A2 Verify that the analog input is correctly measured and displayed in the A I value 2 Inject a fixed rate of ramping DC current in mA of various values into relay terminals A1 and A2 for at least 2 minutes At the end of this time verify that the analog input is correctly measured and displayed in the A I MIN valu...

Page 292: ... 1 through 3 for Phases B and C The following procedure checks indications and operations caused by a Trip function with front panel key resetting 1 Inject current to cause a pickup and wait until the element times to Trip 2 Check that the Trip and Message LEDs are flashing the Last Trip message is displayed and the Output Relay 1 and any others programmed to operate as well as their associated LE...

Page 293: ...cking From Logic Inputs Note that this procedure is different for Phase TOC2 see the next section for details 1 Inject current to cause a pickup 2 Assert a logic input to provide a Block Phase Time 1 The Pickup LED should immediately go out 3 Repeat Steps 1 and 2 for logic inputs Block Phase O C Block All O C and Block 1 Trip Relay as required The following procedure checks timing 1 Connect the St...

Page 294: ...14 Repeat Steps 6 through 12 for current injected in Phase C and controlling voltage Vca To check trip timing with voltage restraint set the input voltage to a given level establishing a new pickup current and then following the procedure outlined earlier under Timing b PHASE TOC 2 The procedure to test this element is identical to that for Phase TOC 1 except for the blocking from logic inputs in ...

Page 295: ... The procedures to test this element are identical to those outlined for Phase IOC 1 above with the exception of the block ing from logic inputs check which is performed as follows 1 Inject current into the required number of phases to cause a pickup 2 Assert a logic input to provide a Block Phase Inst 2 and verify the Pickup LED immediately turns off 3 Repeat Steps 1 and 2 for logic inputs Block ...

Page 296: ...rol check that any output relays programmed for this condition are operated If the function is set to Alarm check that the Alarm and Message LEDs are flashing the correct Phase Directional Reverse alarm message is displayed and any output relays programmed for this condition are operated 2 Slowly increase the angle of the Phase A current in the lagging direction The directional element should dete...

Page 297: ...dual polarizing is required check the operation of the voltage and current polarized elements individually as outlined below then check the overall dual polarized response as outlined at the end of this section A plot of the operating characteristic of the voltage polarized neutral directional feature for various settings of MTA is shown below Other characteristics for specific MTA settings can be...

Page 298: ... of 3Io At an angle lagging the ground current by 90 2 any output relays programmed for this condition should operate if the function is set to Control If the function is set to Alarm check that the Alarm and Message LEDs are flashing the Neutral Directional Reverse alarm message is displayed and any output relays pro grammed for this condition are operated 4 Continue to increase the lagging angle...

Page 299: ...input to provide a Block Ground Time The Pickup LED should immediately go out 3 Repeat Steps 1 and 2 for logic inputs Block Ground O C Block All O C and Block 1 Trip Relay as required b GROUND IOC The procedure to test this element is identical to that outlined in Phase TOC 1 on page 8 16 except that current is injected into the ground input terminals and the element is not subject to the phases r...

Page 300: ... go out 3 Repeat Steps 1 and 2 for logic input Block All O C and Block 1 Trip Relay as required b NEGATIVE SEQUENCE IOC The procedure to test this element is identical to that outlined in Phase IOC 1 on page 8 18 except that current is injected into any one phase of the phase input terminals and the negative sequence current magnitude is 1 3rd of the injected cur rent The element is not subject to...

Page 301: ... 8 4 6 VOLTAGE a BUS UNDERVOLTAGE WYE VTS ONLY To test Bus Undervoltage for Wye VTs use the test connections specified in Figure 8 1 Relay Test Wiring Wye Connec tion on page 8 3 The following procedure checks Pickup with One Phase For Operation 1 Inject Van Vbn Vcn nominal voltage into the bus voltage input of the relay The Pickup LED should be off 2 Slowly lower Van until the Pickup LED comes on...

Page 302: ...ests Pickup with One Phase For Operation 1 Inject Vab Vcb nominal voltage into the bus voltage input of the relay The Pickup LED should be off 2 Slowly lower Vab until the Pickup LED comes on This is the pickup voltage 3 Continue to lower Vab until the Pickup LED goes out This is the MIN OPERATING VOLTAGE minus 2 of VT 4 Raise Vab until the Pickup LED comes on and continue to increase until the in...

Page 303: ...e to cause a pickup 2 Assert a logic input to provide a Block Undervolt 3 4 The Pickup LED should immediately go out 3 Repeat Steps 1 and 2 for logic input Block 1 Trip Relay as required The following procedure tests the Line Undervoltage element Timing 1 Connect the Stop Trigger 2 Set the voltage source to nominal voltage 3 Reset the timer Turn on the voltage and measure the operating time 4 Repe...

Page 304: ...3 except adjust Vbc The following procedure tests Pickup with Two or Three Phases For Operation 1 Inject Vab Vcb pickup into the bus voltage input The Pickup LED should be on 2 Lower Vab until the Pickup LED goes out This is the reset voltage which should be the pickup value minus 2 of VT 3 Slowly raise Vab until the Pickup LED comes on This is the pickup voltage 4 Repeat Steps 1 through 3 except ...

Page 305: ...ck that this dropout voltage is the pickup voltage minus 2 x VT nominal Turn the injection voltage off The following procedure checks Minimum Operating Current Supervision 1 Set the injection source well below the pickup frequency Inject Va 0 V into the bus voltage input and Ia Ib Ic 0 A into the phase current inputs of the relay The Pickup LED should be off 2 Slowly increase the voltage in Phase ...

Page 306: ... Va bus voltage input at a level well above the Minimum Operating Voltage level Also inject Ia Ib Ic at a level well above the Minimum Operating Current level Starting with the Va frequency at a level well below the FREQ DECAY PICKUP drop the frequency of Va at a speed greater than the FREQ DECAY RATE setting The pickup indi cator should come on while the Va frequency is dropping The following pro...

Page 307: ...ock 1 Trip Relay as required The following procedure checks the Frequency Decay Timing 1 Connect the Stop Trigger 2 Preset the ramp rate to a minimum of 110 of the pickup and reset the timer 3 Inject the preset voltage into the Va bus voltage input and note the measured delay time Reset the timer 4 Repeat Step 3 four more times and obtain an average of the time intervals 5 Disconnect the Stop Trig...

Page 308: ...he measured power as a percentage of the rated power calculated using rated values in the above equation The value should be within specifications for this element 6 Adjust the phase angle to 100 120 240 and 260 checking the current pickup value for each angle Calculate the relay pickup power for each angle using the formula given in Step 4 The following procedure tests the Blocking From Logic Inp...

Page 309: ...l current injected into the phase current inputs 8 5 2 FAULT LOCATOR To test the Fault Locator use the test connections specified in Figure 8 1 Relay Test Wiring Wye Connection or Figure 8 2 Relay Test Wiring Delta Connection on page 8 3 Because of the broad range of variables that can be encountered in actual systems a representative config uration with a set of impedances and instrument transfor...

Page 310: ... B to C 10 0 km from the relay Van 60 3 0 Vbn 60 3 240 Vcn 60 3 120 Ia 10 8 283 Ib 10 8 163 Ic 10 8 43 13 Inject the prefault voltages and currents then apply the fault The relay should trip and determine the type of fault A B C the distance to the fault 10 0 km and the reactance to the fault 5 45 Ω 8 5 3 DEMAND MONITORING a CURRENT DEMAND To test Current Demand use the test connections specified ...

Page 311: ...c tion 1 Connect the output of a DC ramping current generator to the analog input 2 Remove the power supply from the relay to ensure the analog input memory is set to zero then re apply power 3 Set the ramp rate below the rate of change pickup and inject into the analog input Wait for 90 seconds fast rate or 90 minutes slow rate to ensure the relay has properly measured the input ramping rate The ...

Page 312: ...re should reset 7 Return Ia to nominal The power factor feature should operate again Return Ib and Ic to nominal 8 Decrease the angle of lagging balanced current until the feature drops out and resets the output relays The following procedure checks Power Factor Timing 1 Connect the Stop Trigger 2 Preset the 3 phase voltage and current inputs to a power factor more lagging than the pickup level Tu...

Page 313: ...s for the Close Coil Monitor are as outlined for Phase TOC 1 on page 8 16 except that this element has no Trip function 1 Ensure the wiring to the circuit breaker trip and close circuits is complete 2 Energize the breaker trip and close circuits and open the breaker 3 Carefully disconnect a wire to open the close circuit After 5 seconds the element should generate an output 4 Restore the open circ...

Page 314: ...etpoint at the end of this test 8 5 12 ANALOG OUTPUT CHANNELS 1 Connect a milli ammeter to channel output terminals as required 2 Follow the test procedures previously outlined for the channel parameter observing the output on the milli ammeter 8 5 13 IRIG B 1 Disconnect the IRIG B input to the relay from the signal source 2 Under S1 RELAY SETUP ÖØ CLOCK manually set the relay date and time to inc...

Page 315: ...roup 1 10 Check that the operation of the protection feature programmed is controlled by the setting in Group 1 11 Assert logic input Setpoint Group 2 and check that the LED indicator shows Setpoint Group 2 12 Assert logic input Setpoint Group 3 and check that the LED indicator shows Setpoint Group 3 13 Assert logic input Setpoint Group 4 and check that the LED indicator shows Setpoint Group 4 14 ...

Page 316: ...ake the test connections specified in Figure 8 1 Relay Test Wiring Wye Connection or Figure 8 2 Relay Test Wir ing Delta Connection on page 8 3 and also connect a variable voltage source to the line voltage input 2 Initially set the function setpoint to Control the Dead Source Permissive setpoint to Off and the Maximum Voltage Dif ference setpoint to 100 kV 3 As there are no input voltages any sel...

Page 317: ...the display slowly decrease the line voltage frequency until the Out of Sync alarm is no longer displayed Check that the frequency difference is the selected value Turn voltages off If the Dead Source Permissive feature is to be used set the MAX VOLTAGE DIFFERENCE MAX ANGLE DIFFERENCE and MAX FREQ DIFFERENCE setpoints to the minimum values and the DEAD SOURCE PERMISSIVE DEAD BUS MAX VOLTAGE DEAD L...

Page 318: ...th voltages off For a DEAD SOURCE PERMISSIVE setpoint of DL X DB perform the following steps 1 Set the bus voltage to a magnitude above the DEAD BUS MAX VOLTAGE limit and below the LIVE BUS MIN VOLTAGE limit at nominal frequency and inject into the relay Set the line voltage to a magnitude above the minimum live line limit 180 out of phase with the bus voltage at the same frequency and inject into...

Page 319: ...rmal When this happens reduce the injection current until the Pickup LED goes out The MANUAL CLOSE BLOCK TIME can be checked in the Event Recorder For Neutral TOC 1 Raised Pickup Ground TOC Raised Pickup Sensitive Ground TOC Raised Pickup and Neg Seq TOC Raised Pickup follow the procedure outlined for Phase TOC 1 Raised Pickup above injecting current as appropriate To check the Select Setpoint Gro...

Page 320: ...cted setpoint group becomes active Verify that settings return to the previous setpoint group after the Cold LOAD PICKUP BLOCK TIME interval expires 8 6 5 UNDERVOLTAGE RESTORATION Make the test connections specified in Figure 8 1 Relay Test Wiring Wye Connection or Figure 8 2 Relay Test Wiring Delta Connection on page 8 3 The following procedure checks Logic and Timers for Undervoltage Restoration...

Page 321: ... and Vcn to nominal 5 Slowly raise Van until the Close Relay operates This is the operating level of the UNDERVOLT RESTORE MIN VOLTS set point for Van with Vcn 6 Inject Van Vbn Vcn nominal voltage into the bus voltage input of the relay 7 Reduce the injected voltages to cause an undervoltage trip then set Vcn to 0 and Vbn to nominal 8 Slowly raise Van until the Close Relay operates This is the ope...

Page 322: ...Slowly raise Vab until the Close Relay operates This is the operating level of UNDERVOLT RESTORE MIN VOLTS for Vab 6 Repeat Steps 3 through 5 except adjust Vcb The following procedure checks Pickup with Two or Three Phases For Operation 1 Assert or De assert a logic input to simulate an open breaker 2 Set UNDERVOLT RESTORE DELAY to 0 3 Inject Vab Vcb nominal voltage into the bus voltage input of t...

Page 323: ...16 If Underfrequency 2 initiation is to be checked change Underfrequency Restoration to Disabled Underfrequency 1 to Disabled Underfrequency 2 to Trip and repeat Steps 2 through 8 The following procedure checks the minimum voltage for underfrequency restoration 1 Assert or De assert a logic input to simulate an open breaker 2 Set UNDERFREQ RESTORE DELAY to 0 3 Inject a voltage below the UNDERFREQ ...

Page 324: ...comer 1 relay Output Relays 5 and 7 should operate at both Incomer relays the message Transfer Not Ready should be removed from the display 17 Momentarily assert Logic Input 3 Remote Open at the Incomer 1 relay the Incomer 1 breaker should trip and Output Relays 5 and 7 should reset at both Incomer relays the message Transfer Not Ready should be displayed 18 Momentarily assert Logic Input 2 Remote...

Page 325: ...uld trip the Incomer 1 breaker and operate Output Relay 6 to send a Close From Incomer 1 signal to the Bus Tie relay Output Relay 6 at the Incomer 1 relay should reset when the Incomer 1 breaker trips removing the signal to the Bus Tie relay The Bus Tie breaker should not close as the voltage on its Bus and Line inputs is too high 3 Slowly reduce the test Source 1 voltage The Bus Tie breaker shoul...

Page 326: ...ltage The Bus Tie breaker should close when the voltage is below the Dead Line Max Volts setpoint of its Synchrocheck feature Increase the voltage to nominal 4 At the Incomer 2 relay de assert Logic Input No 13 Source Trip 5 Momentarily assert Logic Input 3 Remote Open at the Bus Tie relay The Bus Tie breaker should open 6 Momentarily assert Logic Input 2 Remote Close at the Incomer 2 relay The In...

Page 327: ...e the line voltage input of both incomer relays from a single source at nominal voltage and wait until the Trans fer Not Ready message is removed from the display of both relays 2 Turn the test source off The Undervoltage 3 element of both incomer relays should operate immediately and operate Output Relay 4 at both incomers the Transfer Not Ready message will be displayed 3 If the BLOCK TRIP ON DO...

Page 328: ...e Neutral IOC 1 feature and Disable the Phase IOC 1 feature Inject a current into the phase current input of the Incomer 2 relay Slowly increase this current until the Neutral IOC 1 element operates At the Incomer 2 relay the Transfer Not Ready message should be displayed 5 Slowly decrease the injected current until the Neutral IOC 1 element resets At the Incomer 2 relay after the delay time of se...

Page 329: ...losure logic input and the scheme should become in progress 10 Assert a Cancel Reclosure logic input and the scheme should become disabled canceling the reclose in progress De assert the Cancel Reclosure logic input and the scheme should become enabled 11 Assert the Initiate Reclosure logic input then immediately after assert the Remote Open logic input initiating a reclose and tripping the breake...

Page 330: ...the feature sends a trip which will also initiate reclosure After the failure delay time a breaker failure condition will be determined which should immediately set the reclose scheme to the Lockout state turning the Reclo sure Lockout LED on 4 Turn the injected current off and Reset the relay Disable the overcurrent element and close both the breaker and SW9 Use the following procedure to test Au...

Page 331: ...s Trip AR set the test set to a current level above the pickup of this element Turn off the current reset the relay and close the breaker 2 In Reclosure Shot 1 settings select the PHASE TIME OC 1 RAISED PICKUP such that it brings the pickup level just below the actual current that is being injected Turn on the current The relay should trip and reclose 4 times 3 In Reclosure Shot 1 settings select ...

Page 332: ... following AB BC CA Magnitude AVERAGE LINE VOLTAGE Magnitude AN BN CN Magnitude AVERAGE PHASE VOLT AGE Magnitude in kV LINE A B VOLTAGE Phasor LINE B C VOLTAGE Phasor LINE C A VOLTAGE Pha sor PHASE A N VOLTAGE Phasor PHASE B N VOLTAGE Phasor PHASE C N VOLTAGE Phasor POS SEQ VOLTAGE Phasor NEG SEQ VOLTAGE Phasor and ZERO SEQ VOLTAGE Phasor 2 To have an immediate indication upon closing of the load ...

Page 333: ... production version of the relay is tested in its metal case The dielectric strength of all the input output terminals are tested with respect to its grounded chassis and Terminal G12 safety ground The test voltage of the tester from the initial value of 0 V AC is raised to 1 6 kV AC in such a manner slowly that no appreciable transients occur The voltage is maintained for 1 minute and is then red...

Page 334: ...8 58 750 760 Feeder Management Relay GE Multilin 8 7 PLACING THE RELAY IN SERVICE 8 COMMISSIONING TESTS 8 Courtesy of NationalSwitchgear com ...

Page 335: ...ssage will be displayed 6 Press the key once The following message appears 7 Press the key to edit this passcode Use the and keys to change each digit to match the 16 digit passcode supplied by GE Multilin Press to move to the next digit After entering the last digit the cursor will return to the first digit of the code 8 Press the key once The following message will be displayed 9 Press the key o...

Page 336: ...n 5 6 10 Reverse Power if Enabled on page 5 72 Should assistance be required at any time during this procedure please contact GE Multilin technical support at 1 800 547 8629 within the U S and Canada or 1 905 294 6222 outside U S or Canada You can also send an e mail to our tech nical support department at gemultilin indsys ge com Courtesy of NationalSwitchgear com ...

Page 337: ...GE Multilin 750 760 Feeder Management Relay A 3 APPENDIX A A 2 CONFORMITY A A 2 CONFORMITY A 2 1 EU DECLARATION OF CONFORMITY Courtesy of NationalSwitchgear com ...

Page 338: ...d 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 relay which has been subject to mis use negligence accident incorrect installation or use not in accor dance with instructions nor any unit that has been altered outside a GE Multilin authorized factory outlet GE ...

Page 339: ... technical support 6 19 trip counters 6 15 virtual inputs 6 5 voltage 6 10 ANALOG INPUT actual values 6 14 description 3 14 measurement 8 15 measuring 8 15 rate of change 5 85 5 86 setpoints 5 83 setup 5 83 threshold 5 85 ANALOG INPUT RATE OF CHANGE monitoring 8 35 setpoints 5 85 ANALOG INPUT SETUP 5 83 ANALOG OUTPUTS channels 8 38 characteristics 5 87 connection 3 15 description 3 15 parameters 5...

Page 340: ...e blocking 8 42 setpoint group control 8 39 specifications 2 10 synchrocheck 8 40 transfer 8 47 underfrequency restoration 8 46 undervoltage restoration 8 44 COUNTERS trip 6 15 CRC 16 ALGORITHM 7 3 CTs see CURRENT TRANSFORMER CURRENT ACTUAL VALUES 6 9 CURRENT DEMAND logic diagram 5 79 measurement 8 13 monitoring 8 34 setpoints 5 79 CURRENT SENSING SETPOINTS 5 16 CURRENT TRANSFORMER AC inputs 3 8 c...

Page 341: ...diagram 5 49 protection scheme 8 23 setpoints 5 49 setting example 1 7 GROUND OVERCURRENT 5 47 GROUND TIME OVERCURRENT logic diagram 5 48 protection scheme 8 23 setpoints 5 48 setting example 1 7 H HARDWARE BLOCK DIAGRAM 2 4 HARDWARE INPUTS 6 5 HARMONICS 2 3 HELP KEY 1 3 I IAC CURVES constants 5 35 description 5 35 trip times 5 35 IEC CURVES constants 5 34 description 5 34 trip times 5 34 INCOMER ...

Page 342: ...5 62 NEUTRAL CURRENT logic diagram 5 74 monitoring 8 33 setpoints 5 74 NEUTRAL DIRECTIONAL OVERCURRENT 8 21 description 5 45 logic diagram 5 47 operating characteristics 5 45 operating regions 8 21 setpoints 5 45 test connections 8 22 voltage polarizing 5 46 NEUTRAL DISPLACEMENT logic diagram 5 67 protection scheme 8 28 setpoints 5 67 NEUTRAL INSTANTANEOUS OVERCURRENT logic diagram 5 44 protection...

Page 343: ...us overcurrent 8 24 negative sequence time overcurrent 8 24 negative sequence voltage 8 24 neutral displacement 8 28 neutral instantaneous overcurrent 8 21 neutral time overcurrent 8 20 overvoltage 8 27 phase directional overcurrent 8 19 phase instantaneous overcurrent 8 18 8 19 phase time overcurrent 8 16 8 18 sensitive ground directional overcurrent 8 24 sensitive ground instantaneous overcurren...

Page 344: ...ground time overcurrent 5 48 installation 5 15 installing the setpoint access jumper 1 3 line undervoltage 5 65 loading from a file 4 12 manual close blocking 5 101 message summary 5 1 miscellaneous functions 5 26 modbus 7 5 negative sequence directional 5 60 negative sequence instantaneous overcurrent 5 59 negative sequence time overcurrent 5 58 negative sequence voltage 5 62 neutral current 5 74...

Page 345: ...reaker DC schematic 5 114 bus tie breaker logic 5 117 description 8 47 incomer 1 DC schematic 5 112 incomer 1 logic diagram 5 115 incomer 2 DC schematic 5 113 incomer 2 logic diagram 5 116 one line diagram 5 111 setpoints 5 107 TRANSFORMER POLARITY 3 8 TRANSIENTS 2 3 TRIP COIL MONITORING 8 37 TRIP COIL SUPERVISION connection diagram 3 13 description 3 12 TRIP COUNTER actual values 6 15 logic diagr...

Page 346: ...EX see VOLTAGE TRANSFORMER W WARRANTY A 4 WATTHOURS MEASUREMENT 8 12 WAVEFORM CAPTURE description 2 3 4 15 graph attributes 4 15 window 4 16 WEBSITE 1 1 WET CONTACT CONNECTIONS 3 14 Z ZERO SEQUENCE CT INSTALLATION 3 10 Courtesy of NationalSwitchgear com ...

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