Page 1 GE Power Management ® GENERATOR MANAGEMENT RELAY Instruction Manual 489 Firmware Revision: 32H150A8.000 489PC Software Revision: 1.50 Manual P/N: 1601-0071-E8 (GEK-106290) Copyright © 2002 GE Power Management 489 STATUS GENERATOR STATUS OUTPUT RELAYS 489 IN SERVICE BREAKER OPEN R1 TRIP SETPOINT ACCESS...
Page 3: Table Of Contents
IRIG-B ......................2-13 2.2.13 RS485 COMMUNICATIONS PORTS .............. 2-14 2.2.14 DIELECTRIC STRENGTH TESTING .............. 2-15 3. OPERATION 3.1 OVERVIEW 3.1.1 489 FACEPLATE ....................3-1 3.1.2 DISPLAY ......................3-2 3.1.3 LED INDICATORS ..................... 3-2 3.1.4 RS232 PROGRAM PORT.................. 3-3 3.1.5 KEYPAD......................3-4 3.1.6...
Page 4 RTD 11 ......................4-48 4.9.5 RTD 12 ......................4-49 4.9.6 OPEN RTD SENSOR ..................4-49 4.9.7 RTD SHORT/LOW TEMPERATURE..............4-50 4.10 S9 THERMAL MODEL 4.10.1 489 THERMAL MODEL ..................4-51 4.10.2 MODEL SETUP ....................4-52 4.10.3 UNBALANCE BIAS...................4-61 4.10.4 MACHINE COOLING..................4-62 4.10.5 HOT/COLD CURVE RATIO................4-63 4.10.6 RTD BIAS ......................4-63...
Page 5 GENERAL COUNTERS ................... 5-21 5.5.3 TIMERS......................5-21 5.6 A5 EVENT RECORDER 5.6.1 EVENT RECORDER..................5-22 5.7 A6 PRODUCT INFO 5.7.1 489 MODEL INFO ................... 5-25 5.7.2 CALIBRATION INFO..................5-25 5.8 DIAGNOSTICS 5.8.1 DIAGNOSTIC MESSAGES FOR OPERATORS ..........5-26 5.8.2 FLASH MESSAGES ..................5-27 6.
Page 6 REACTIVE POWER TEST ................7-11 7.3.4 VOLTAGE PHASE REVERSAL TEST .............7-12 7.3.5 INJECTION TEST SETUP #2................7-12 7.3.6 GE POWER MANAGEMENT HGF GROUND ACCURACY TEST ....7-13 7.3.7 NEUTRAL VOLTAGE (3RD HARMONIC) ACCURACY TEST......7-13 7.3.8 PHASE DIFFERENTIAL TRIP TEST..............7-14 7.3.9 INJECTION TEST SETUP #3................7-15 7.3.10...
Page 7 8.2.1 STARTUP & COMMUNICATIONS CONFIGURATION ........8-4 8.3 USING 489PC 8.3.1 SAVING SETPOINTS TO A FILE ..............8-5 8.3.2 UPGRADING THE 489 FIRMWARE..............8-6 8.3.3 LOADING SETPOINTS FROM A FILE .............. 8-7 8.3.4 ENTERING SETPOINTS ................... 8-7 8.3.5 UPGRADING SETPOINT FILES TO NEW REVISION ........8-9 8.3.6...
Page 8 TABLE OF CONTENTS 489 Generator Management Relay GE Power Management...
Page 9: Introduction
Fault diagnostics are provided through pretrip data, event record, waveform capture, and statistics. Prior to issuing a trip, the 489 takes a snapshot of the measured parameters and stores them in a record with the cause of the trip. This pre-trip data may be viewed using the key before the trip is reset, or by accessing the last trip data in actual values page 1.
Page 10 IRIG-B failure Power metering is a standard feature in the 489. The table below outlines the metered parameters available to the operator or plant engineer either through the front panel or communications ports. The 489 is equipped with three fully functional and independent communications ports.
Page 11: Order Information
1.1.2 ORDER INFORMATION All features of the 489 are standard, there are no options. The phase CT secondaries must be specified at the time of order. The control power and analog output range must also be specified at the time of order. There are two ground CT inputs: one for the GE Power Management HGF core balance CT and one for a ground CT with a 1 A secondary (may also be used to accommodate 5 A secondary).
Page 12: Specifications
2, Isolated together at 36 Vpk RS485 Baud Rates: 300, 1200, 2400, 4800, 9600, 19200 R S 232 B aud R ate: 9600 Parity: None, Odd, Even ® Protocol: Modbus RTU / half duplex, DNP 3.0 489 Generator Management Relay GE Power Management...
Page 13 High Voltage (E, F, G, H terminals): #8 ring lug, Time Delay: 0.1 to 250.0 s in steps of 0.1 10 AWG wire standard Pickup Accuracy: as per Phase Current Inputs Timing Accuracy: ±100 ms or ±0.5% of total time Elements: Alarm GE Power Management 489 Generator Management Relay...
Page 14 Timing Accuracy: ±100 ms or ±0.5% of total time Pickup Accuracy: as per Phase Current Inputs Elements: Trip and Alarm Timing Accuracy: ±100 ms or ±0.5% of total time Elements: Trip and Alarm 489 Generator Management Relay GE Power Management...
Page 15 Elements: Trip and Alarm Pollution Degree: LOW FORWARD POWER It is recommended that the 489 be powered up Block From Online: 0 to 15000 s in steps of 1 at least once per year to prevent deterioration 0.02 to 0.99 × rated MW...
Page 16 12” × 11” × 10” (W × H × D) Shipping Box: 30.5cm × 27.9cm × 25.4cm Shipping Weight: 17 lbs Max / 7.7 kg CERTIFICATION ISO: Manufactured under an ISO9001 regis- tered system. CSA: Conforms to IEC 947-1, IEC 1010-1 489 Generator Management Relay GE Power Management...
Page 17: Installation
Any 489 can be installed in any 489 case, except for custom manufactured units that are clearly identified as such on both case and unit, and are equipped with an index pin keying mechanism to prevent incorrect pairings.
Page 18: Product Identification
2.1.2 PRODUCT IDENTIFICATION Each 489 unit and case are equipped with a permanent label. This label is installed on the left side (when facing the front of the relay) of both unit and case. The case label details which units can be installed.
Page 19: Unit Withdrawal And Insertion
2.1.3 INSTALLATION The 489 case, alone or adjacent to another SR unit, can be installed in a standard 19-inch rack panel (see Figure 2–1: 489 DIMENSIONS on page 2–1). Provision must be made for the front door to swing open without interference to, or from, adja- cent equipment.
Page 20 Grasp the locking handle from the center and press down firmly, rotating the handle from the raised position toward the bottom of the unit. When the unit is fully inserted, the latch will be heard to click, locking the handle in the final position. 489 Generator Management Relay GE Power Management...
Page 21: Terminal Locations
2 INSTALLATION 2.1 MECHANICAL 2.1.5 TERMINAL LOCATIONS Figure 2–8: TERMINAL LAYOUT GE Power Management 489 Generator Management Relay...
Page 22 2.1 MECHANICAL 2 INSTALLATION Table 2–1: 489 TERMINAL LIST TERM. DESCRIPTION TERM. DESCRIPTION RTD #1 HOT ASSIGNABLE SW. 06 RTD #1 COMPENSATION ASSIGNABLE SW. 07 RTD RETURN SWITCH COMMON RTD #2 COMPENSATION SWITCH +24 V DC RTD #2 HOT COMPUTER RS485 + RTD #3 HOT COMPUTER RS485 –...
Page 23: Electrical
2 INSTALLATION 2.2 ELECTRICAL 2.2 ELECTRICAL 2.2.1 TYPICAL WIRING DIAGRAM GE Power Management Figure 2–9: TYPICAL WIRING DIAGRAM GE Power Management 489 Generator Management Relay...
Page 24: Typical Wiring
The information in this section will cover the important aspects of interconnections, in the general areas of instru- ment transformer inputs, other inputs, outputs, communications and grounding. See Figure 2–8: TERMINAL LAYOUT and Table 2–1: 489 TERMINAL LIST for terminal arrangement, and Figure 2–9: TYPICAL WIRING DIAGRAM for typical con- nections.
Page 25: Control Power
There are no internal ground connections on the CT inputs. Each phase CT circuit is shorted by automatic mecha- nisms on the 489 case if the unit is withdrawn. The phase CTs should be chosen such that the FLA is no less than 50% of the rated phase CT primary.
Page 26: Ground Current Input
The 1 A tap is used for 1 A or 5 A secondary CTs in either core balance or residual ground configurations. If the 1 A tap is used, the 489 measures up to 20 A secondary with a maximum ground CT ratio of 10000:1.
Page 27: Voltage Inputs
2.2.8 ANALOG INPUTS Terminals are provided on the 489 for the input of four 0 to 1 mA, 0 to 20 mA, or 4 to 20 mA current signals (field program- mable). This current signal can be used to monitor any external quantity such as: vibration, pressure, field current, etc. The four inputs share one common return.
Page 28: Analog Outputs
The analog output circuitry is isolated as a group with the Analog Input circuitry and the RTD circuitry. Only one ground ref- erence should be used for the three circuits. Transorbs limit this isolation to ±36 V with respect to the 489 safety ground.
Page 29: Output Relays
489 is drawn out, no trip or alarm occurs. The R6 Service output will however indicate that the 489 has been drawn out. Each output relay has an LED indicator on the 489 front panel that comes on while the associated relay is in the operated state.
Page 30: Rs485 Communications Ports
2.2.13 RS485 COMMUNICATIONS PORTS Two independent two-wire RS485 ports are provided. Up to 32 489 relays can be daisy-chained together on a communica- tion channel without exceeding the driver capability. For larger systems, additional serial channels must be added. It is also possible to use commercially available repeaters to increase the number of relays on a single channel to more than 32.
Page 31: Dielectric Strength Testing
2.2.14 DIELECTRIC STRENGTH TESTING It may be required to test for dielectric strength (“flash” or hi-pot”) with the 489 installed. The 489 is rated for 2000 V DC iso- lation between relay contacts, CT inputs, VT inputs, trip coil supervision, and the safety ground terminal G12. Some pre- cautions are required to prevent 489 damage during these tests.
Page 32 2.2 ELECTRICAL 2 INSTALLATION 2-16 489 Generator Management Relay GE Power Management...
Page 33: Operation
R6 SERVICE ALT. SETPOINTS LOSS OF FIELD RESET VT FAILURE POSSIBLE RESET MESSAGE BREAKER FAILURE NEXT PROGRAM PORT SETPOINT MESSAGE ACTUAL ESCAPE VALUE HELP ENTER Generator Management Relay 808754E3.CDR Figure 3–1: 489 FACEPLATE GE Power Management 489 Generator Management Relay...
Page 34: Display
489 IN SERVICE: Indicates that control power is applied, all monitored input/output and internal systems are OK, the 489 has been programmed, and is in protection mode, not simulation mode. When in simulation or testing mode, the LED indicator will flash.
Page 35: Rs232 Program Port
489PC software. Local interrogation of setpoints and actual values is also possible. New firmware may be downloaded to the 489 flash memory through this port. Upgrading the relay firmware does not require a hardware EEPROM change.
Page 36: Keypad
ENTER 3.1.7 ENTERING +/– SIGNS The 489 does not have a ‘+’ or ‘–’ key. Negative numbers may be entered in one of the following two ways: • Press the keys the scroll through the setpoint range, including any negative numbers.
Page 37: Setpoint Entry
The following procedure may be used to access and alter any setpoint message. This specific example will refer to entering a valid passcode in order to allow access to setpoints if the passcode was '489'. The 489 programming is broken down into pages by logical groups. Press...
Page 38 3.2 SETPOINT ENTRY 3 OPERATION 489 Generator Management Relay GE Power Management...
Page 39: Setpoint Programming
As soon as an alarm occurs, the alarms messages are updated to reflect the alarm and the 489 display defaults to that message. Since it may not be desirable to log all alarms as events, each alarm feature may be programmed to log as an event or not.
Page 40: Dual Setpoints
ACTIVATE SETPOINT GROUP setpoint or an assigned digital input in S3 Digital Inputs. The LED indicator on the faceplate of the 489 will indicate when the alternate setpoints are active in the protection scheme. Independently, the setpoints in either group can be viewed and/ or edited using the setpoint.
Page 41: S1 489 Setup
MESSAGE A passcode access security feature is provided with the 489. The passcode is defaulted to "0" (without the quotes) at the time of shipping. Passcode protection is ignored when the passcode is "0". In this case, the setpoint access jumper is the only protection when programming setpoints from the front panel keypad and setpoints may be altered using the RS232 and RS485 serial ports without access protection.
Page 42: Serial Ports
The computer RS485 port is a general purpose port for connection to a DCS, PLC, or PC. The Auxiliary RS485 port may also be used as another general purpose port or it may be used to talk to Auxiliary GE Power Manage- ment Devices in the future.
Page 43: Real Time Clock
MESSAGE The 489 displays default messages after a period of keypad inactivity. Up to 20 default messages can be selected for dis- play. If more than one message is chosen, they will automatically scroll at a rate determined by the S1 489 SETUP / setpoint.
Page 44: Message Scratchpad
Enter the correct passcode at to allow setpoint entry (unless S1 489 SETUP / PASSCODE / ENTER PASSCODE FOR ACCESS it has already been entered or is "0", defeating the passcode security feature). Select the message to be add to the default message list using the keys.
Page 45: Clear Data
4 SETPOINT PROGRAMMING 4.2 S1 489 SETUP 4.2.7 CLEAR DATA ð Range: No, Yes CLEAR DATA CLEAR LAST TRIP ENTER [ENTER] for more DATA: No ESCAPE Range: No, Yes RESET MWh and Mvarh ESCAPE MESSAGE METERS: No MESSAGE Range: No, Yes...
Page 46: S2 System Setup
The 489 will indicate that it was never programmed. Once these values are entered, the 489 will be in service. The phase CT should be selected such that the maximum fault current does not exceed 20 times the primary rating.
Page 47: Generator Parameters
"--------", indicating they are not programmed. The 489 indicates that it was never programmed. Once these values are entered, the 489 will be in service. All elements associated with power quantities are programmed in per unit values calculated from the rated MVA and power factor. The generator full load amps (FLA) is calculated as...
Page 48: S3 Digital Inputs
4.4.1 DESCRIPTION The 489 has nine digital inputs for use with external contacts. Two of the 489 digital inputs have been pre-assigned as inputs having a specific function. The Access Switch does not have any setpoint messages associated with it. The Breaker Status input, may be configured for either an 'a' or 'b' auxiliary contact.
Page 49: General Input A To G
However, if a dwell time is assigned, the output relay(s) operate as soon as the input is asserted for a period of time specified by the setpoint. If an alarm or trip is enabled and the input is asserted, an alarm or trip will occur after the specified delay. GE Power Management 489 Generator Management Relay 4-11...
Page 50: Remote Reset
ESCAPE Once the 489 is in service, it may be tested from time to time as part of a regular maintenance schedule. The unit will have accumulated statistical information relating historically to generator and breaker operation. This information includes: last...
Page 51: Sequential Trip
Group 2). In the event of a conflict between the ACTIVATE SET- setpoint or the assigned digital input, Group 2 will be activated. The LED indicator on the faceplate of the 489 POINT GROUP will indicate when the alternate setpoints are active in the protection scheme.
Page 52: Field-Breaker Discrepancy
The probe could be powered from the +24V from the digital input power supply. The NPN transistor output could be taken to one of the assignable digital inputs assigned to the tachometer function. 4-14 489 Generator Management Relay GE Power Management...
Page 53: Waveform Capture
CONTACT: Auxiliary a MESSAGE This function is used to detect the status of a grounding switch for the generator for which the relay is installed. Refer to Appendix B for Application Notes. GE Power Management 489 Generator Management Relay 4-15...
Page 54: S4 Output Relays
Obviously, when control power is lost to the 489, the output relays must be de-energized and there- fore, they will be in their non-operated state. Shorting bars in the drawout case ensure that when the 489 is drawn out, no trip or alarm occurs.
Page 55: S5 Current Elements
4.6.1 INVERSE TIME OVERCURRENT CURVE CHARACTERISTICS The 489 inverse time overcurrent curves may be either ANSI, IEC, or GE Type IAC standard curve shapes. This allows for simplified coordination with downstream devices. If however, none of these curve shapes is adequate, the FlexCurve™...
Page 56 CONSTANTS IAC EXTREME INVERSE 0.0040 0.6379 0.6200 1.7872 0.2461 IAC VERY INVERSE 0.0900 0.7955 0.1000 –1.2885 7.9586 IAC INVERSE 0.2078 0.8630 0.8000 –0.4180 0.1947 IAC SHORT INVERSE 0.0428 0.0609 0.6200 –0.0010 0.0221 4-18 489 Generator Management Relay GE Power Management...
Page 57 To enter a custom FlexCurve™, read off each individual point from a time overcurrent coordination drawing and enter it into a table as shown. Then transfer each individual point to the 489 using either the 489PC software or the front panel keys and display.
Page 58: Overcurrent Alarm
CT measurements (Ia, Ib, Ic). It may be set much more sensitive than the differential element to detect high impedance phase faults. Since the breaker auxiliary contacts wired to the 489 Breaker Status input may not operate at exactly the same time as the main breaker contacts, the time delay should be coordinated with the difference of the operation times.
Page 59: Inadvertent Energization
250 ms after the generator is placed online would result in a trip. > O/C Level Operate phase < U/V Level phase Breaker Status =Off-Line 250 ms Arming Signal = U/V or Offline Figure 4–1: INADVERTENT ENERGIZATION GE Power Management 489 Generator Management Relay 4-21...
Page 60: Voltage Restrained Phase Overcurrent
The magnitude of each phase current measured at the output CTs is used to time out against an inverse time curve. The 489 inverse time curve for this element may be either ANSI, IEC, or GE Type IAC standard curve shapes.
Page 61: Negative Sequence Overcurrent
4 SETPOINT PROGRAMMING 4.6 S5 CURRENT ELEMENTS The 489 phase overcurrent restraint voltages and restraint characteristic are shown below: PHASE OVERCURRENT RESTRAINT VOLTAGES: CURRENT VOLTAGE Phase-Phase Voltage / Rated Phase-Phase Voltage Phase-Phase Voltage / Rated Phase-Phase Voltage Figure 4–2: VOLTAGE RESTRAINT CHARACTERISTIC 4.6.6 NEGATIVE SEQUENCE OVERCURRENT...
Page 62 4 SETPOINT PROGRAMMING The 489 has a definite time alarm and inverse time overcurrent curve trip to protect the generator rotor from overheating due to the presence of negative sequence currents. Pickup values are negative sequence current as a percent of generator rated full load current.
Page 63: Ground Overcurrent
The 489 ground overcurrent feature consists of both an alarm and a trip element. The magnitude of measured ground cur- rent is used to time out against the definite time alarm or inverse time curve trip. The 489 inverse time curve for this element may be either ANSI, IEC, or GE Type IAC standard curve shapes.
Page 64: Phase Differential
MESSAGE The 489 percentage differential element has a dual slope characteristic. This allows for very sensitive settings when fault current is low and less sensitive settings when fault current is high (more that 2 × CT) and CT performance may produce erroneous operate signals.
Page 65: Ground Directional
, below 2.0 V secondary. Refer to the APPLICATION NOTES for more details. The pickup level for the ground current elements is programmable as a multiple of the CT. The 50:0.025 CT is intended for very sensitive detection of ground faults and its nominal CT rating for the 489 is 50:0.025. NOTE For example, if the ground CT is 50:0.025, a pickup of 0.20 would be 0.20 x 5 = 1 A primary.
Page 66: High-Set Phase Overcurrent
4.6 S5 CURRENT ELEMENTS 4 SETPOINT PROGRAMMING AUXILIARY CONTACT GROUNDING SWITCH C(B) C(B) B(C) B(C) TO 50:0.025 TO Vneutral OF EACH 489 50:0.025 GROUND INPUTS 808812A3.CDR Figure 4–5: GROUND DIRECTIONAL DETECTION 4.6.10 HIGH-SET PHASE OVERCURRENT ð Range: Off, Latched, Unlatched HIGH-SET PHASE O/C...
Page 67: S6 Voltage Elements
1 V V – pickup where: T = trip time in seconds setpoint UNDERVOLTAGE TRIP DELAY V = actual per unit phase-phase voltage setpoint UNDERVOLTAGE TRIP PICKUP pickup Multiples of Undervoltage Pickup GE Power Management 489 Generator Management Relay 4-29...
Page 68: Overvoltage
---------------------------------------- - ⁄ pickup – pickup where: T = trip time in seconds setpoint OVERVOLTAGE TRIP DELAY V = actual per unit phase-phase voltage setpoint OVERVOLTAGE TRIP PICKUP pickup Multiples of Overvoltage Pickup 4-30 489 Generator Management Relay GE Power Management...
Page 69 The V/Hz Curve 1 trip curves are shown on the right for delay settings of 0.1, 0.3, 1, 3, and 10 seconds. 0.01 1.00 1.20 1.40 1.60 1.80 2.00 Multiples of Volts/Hertz Pickup GE Power Management 489 Generator Management Relay 4-31...
Page 70: Volts/Hertz
MESSAGE The 489 can detect the phase rotation of the three phase voltages. A trip will occur within 200 ms if the Phase Reversal fea- ture is turned on, the generator is offline, each of the phase-phase voltages is greater than 50% of the generator rated phase-phase voltage and the phase rotation is not the same as the setpoint.
Page 71: Underfrequency
Once the frequency of Vab is less than the underfrequency setpoints, for the period of time specified, a trip or alarm will occur. There are dual level and time setpoints for the trip element. GE Power Management 489 Generator Management Relay 4-33...
Page 72: Overfrequency
Once the frequency of Vab exceeds the overfrequency setpoints, for the period of time specified, a trip or alarm will occur. There are dual level and time setpoints for the trip element. 4-34 489 Generator Management Relay GE Power Management...
Page 73: Neutral Overvoltage (Fundamental)
NEUTRAL OVERVOLTAGE TRIP DELAY V = neutral voltage setpoint NEUTRAL O/V TRIP LEVEL pickup The neutral overvoltage curves are shown on the right. Refer to Appendix B for Application Notes. Multiples of Overvoltage Pickup GE Power Management 489 Generator Management Relay 4-35...
Page 74: Neutral Undervoltage (3Rd Harmonic)
GENERATOR 1 GENERATOR 2 808816A3.CDR TO Vneutral OF EACH 489 Figure 4–6: NEUTRAL OVERVOLTAGE DETECTION If the ground directional element is enabled, the Neutral Overvoltage element should be coordinated with it. In cases of paralleled generator grounds through the same point, with individual ground switches, per sketch below, it NOTE is recommended to use a ground switch status function to prevent maloperation of the element.
Page 75 0.15 which simplifies to V 17 V -------------------------------------- - 3 ⁄ The 489 tests the following permissives prior to testing the basic operating equation to ensure that V ’ should be of a mea- surable magnitude for an unfaulted generator: Neutral VT Ratio ′...
Page 76: Loss Of Excitation
CT Ratio = programmed CT ratio, if CT ratio is 1200:5 use a value of 1200 / 5 = 240 VT Ratio = programmed VT ratio, if VT ratio is 100:1 use a value of 100 4-38 489 Generator Management Relay GE Power Management...
Page 77: Distance Elements
In systems with a delta-wye transformer (DY330°), the appropriate transformations of voltage and current signals are implemented internally to allow proper detection of trans- GE Power Management 489 Generator Management Relay 4-39...
Page 78 VTFF element. In order to prevent nuisance tripping the elements require a mini- mum phase current of 0.05 x CT. Figure 4–8: DISTANCE ELEMENT SETUP 4-40 489 Generator Management Relay GE Power Management...
Page 79: S7 Power Elements
Generation of power will be displayed on the 489 as positive watts. By convention, an induction generator normally requires reactive power from the system for excitation. This is displayed on the 489 as negative vars. A synchronous generator on the other hand has its own source of excitation and can be operated with either lagging or leading power factor. This is dis- played on the 489 as positive vars and negative vars, respectively.
Page 80: Reactive Power
Rated Mvars for the system can be calculated as follows: For example, given Rated MVA = 100 MVA and Rated Power Factor = 0.85, we have – – × × Rated Mvars Rated MVA Rated PF 0.85 52.67 Mvars 4-42 489 Generator Management Relay GE Power Management...
Page 81: Reverse Power
Users are cautioned that a reverse power element may not provide reliable indication when set to a very low setting, partic- ularly under conditions of large reactive loading on the generator. Under such conditions, low forward power is a more reli- able element. GE Power Management 489 Generator Management Relay 4-43...
Page 82: Low Forward Power
From Online. The pickup level should be set lower than expected generator loading during normal operations. If the VT type is selected as "None" or VT fuse loss is detected, the low forward power protection is disabled. 4-44 489 Generator Management Relay GE Power Management...
Page 83: S8 Rtd Temperature
168.47 280.77 233.97 16.00 172.46 291.96 243.30 16.39 175.84 303.46 252.88 16.78 179.51 315.31 262.76 17.17 183.17 327.54 272.94 17.56 186.82 340.14 283.45 17.95 190.45 353.14 294.28 18.34 194.08 366.53 305.44 18.73 GE Power Management 489 Generator Management Relay 4-45...
Page 84: Rtds 1 To 6
RTD malfunction. If enabled, a second RTD must also exceed the trip temperature of the RTD being checked before a trip will be issued. If the RTD is chosen to vote with itself, the voting feature is disabled. Each RTD name may be changed if desired. 4-46 489 Generator Management Relay GE Power Management...
Page 85: Rtds 7 To 10
RTD malfunction. If enabled, a second RTD must also exceed the trip temperature of the RTD being checked before a trip will be issued. If the RTD is chosen to vote with itself, the voting feature is disabled. Each RTD name may be changed if desired. GE Power Management 489 Generator Management Relay 4-47...
Page 86: Rtd 11
RTD being checked before a trip will be issued. If the RTD is chosen to vote with itself, the voting feature is disabled. The RTD name may be changed if desired. 4-48 489 Generator Management Relay GE Power Management...
Page 87: Open Rtd Sensor
MESSAGE The 489 has an Open RTD Sensor Alarm. This alarm will look at all RTDs that have either an alarm or trip programmed and determine if an RTD connection has been broken. Any RTDs that do not have a trip or alarm associated with them will be ignored for this feature.
Page 88: Rtd Short/Low Temperature
MESSAGE The 489 has an RTD Short/Low Temperature alarm. This alarm will look at all RTDs that have either an alarm or trip pro- grammed and determine if an RTD has either a short or a very low temperature (less than –50°C). Any RTDs that do not have a trip or alarm associated with them will be ignored for this feature.
Page 89: S9 Thermal Model
4.10.1 489 THERMAL MODEL The thermal model of the 489 is primarily intended for induction generators, especially those that start on the system bus in the same manner as induction motors. However, some of the thermal model features may be used to model the heating that occurs in synchronous generators during overload conditions.
Page 90: Model Setup
MESSAGE Range: 2.00 to STALL CURRENT @ 100% VOLTAGE in ACCEL. INTERSECT @ ESCAPE steps of 0.01. Seen only if SELECT CURVE 100% VOLT: 5.00 x FLA MESSAGE STYLE is Voltage Dependent 4-52 489 Generator Management Relay GE Power Management...
Page 91 The 489 overload curve can take one of three formats, Standard, Custom Curve, or Voltage Dependent. Regardless of which curve style is selected, the 489 will retain thermal memory in the form of a register called Thermal Capacity Used. This register is updated every 50 ms using the following equation: 50 ms ×...
Page 92 4.10 S9 THERMAL MODEL 4 SETPOINT PROGRAMMING 100000 10000 1000 1.00 0.10 1.00 1000 MULTIPLE OF FULL LOAD AMPS 806804A5.CDR Figure 4–11: 489 STANDARD OVERLOAD CURVES 4-54 489 Generator Management Relay GE Power Management...
Page 93 182.27 273.41 364.55 455.68 546.82 637.96 729.09 820.23 911.37 1002.5 1093.6 1184.8 1275.9 1367.0 1.50 69.99 139.98 209.97 279.96 349.95 419.94 489.93 559.92 629.91 699.90 769.89 839.88 909.87 979.86 1049.9 1.75 42.41 84.83 127.24 169.66 212.07 254.49 296.90 339.32 381.73 424.15 466.56 508.98 551.39 593.81 636.22 2.00 29.16...
Page 94 The distinct parts of the thermal limit curves now become more critical. For these conditions, it is recommended that the 489 custom curve thermal model be used. The custom overload curve allows users to program their own curves by entering trip times for 30 pre-determined current levels.
Page 95 The protection relay must be able to distinguish between a locked rotor condition, an accelerating condition, and a running condition. The 489 voltage dependent overload curve feature is tai- lored to protect these types of machines. Voltage is monitored constantly during starting and the acceleration thermal limit curve adjusted accordingly.
Page 96 1000 489 Custom Curve Acceleration intersect @ 80% V Acceleration Intersect @ 100% V MULTIPLES OF FULL LOAD AMPS MULTIPLES OF FULL LOAD AMPS 808827A2.CDR 808828A2.CDR Figure 4–14: VOLTAGE DEPENDENT OVERLOAD CURVES 4-58 489 Generator Management Relay GE Power Management...
Page 97 4.10 S9 THERMAL MODEL The 489 takes the information provided and create protection curves for any voltage between the minimum and 100%. For values above the voltage in question, the 489 extrapolates the safe stall protection curve to 110% voltage. This current level is calculated by taking the locked rotor current at 100% voltage and multiplying by 1.10.
Page 98 4 SETPOINT PROGRAMMING The following curves illustrate the resultant overload protection for 80% and 100% voltage, respectively. For voltages inbe- tween these levels, the 489 shifts the acceleration curve linearly and constantly based upon the measured voltage during generator start.
Page 99 The 489 measures the ratio of negative to positive sequence current. The thermal model may be biased to reflect the addi- tional heating that is caused by negative sequence current when the machine is running. This biasing is done by creating an equivalent heating current rather than simply using average current ( I ).
Page 100: Machine Cooling
4.10 S9 THERMAL MODEL 4 SETPOINT PROGRAMMING 4.10.4 MACHINE COOLING The 489 thermal capacity used value is reduced exponentially when the motor current is below the set- OVERLOAD PICKUP point. This reduction simulates machine cooling. The cooling time constants should be entered for both stopped and run- ning cases (the generator is assumed to be running if current is measured or the generator is offline).
Page 101: Hot/Cold Curve Ratio
4.10 S9 THERMAL MODEL 4.10.5 HOT/COLD CURVE RATIO When thermal limit information is available for both a hot and cold machine, the 489 thermal model will adapt for the condi- tions if the is programmed. The value entered for this setpoint dictates the level of thermal capacity...
Page 102: Thermal Elements
The lockout time will be based on the reduction of thermal capacity from 100% used to 15% used. This reduc- tion will occur at a rate defined by the stopped cooling time constant. The thermal capacity used alarm may be used as a warning indication of an impending overload trip. 4-64 489 Generator Management Relay GE Power Management...
Page 103: S10 Monitoring
If that continuity is bro- ken, a trip coil monitor alarm will occur in approximately 300 ms. GE Power Management 489 Generator Management Relay 4-65...
Page 104 I > 0.075 x CT Block V > 0.05 x Full Scale Appropriate Elements Breaker Status = Online & Operate Alarm 99ms Relay × V < 0.05 Full Scale Figure 4–20: VT FUSE FAILURE 4-66 489 Generator Management Relay GE Power Management...
Page 105: Current, Mw, Mvar, Mva Demand
RELAYS (2-5): ---5 MESSAGE Range: 0.10 to 20.00 × Rated in steps of 0.01 MVA DEMAND ESCAPE LIMIT: 1.25 x Rated MESSAGE Range: On, Off MVA DEMAND ESCAPE ALARM EVENTS: Off MESSAGE GE Power Management 489 Generator Management Relay 4-67...
Page 106 4 SETPOINT PROGRAMMING The 489 can measure the demand of the generator for several parameters (current, MW, Mvar, MVA). The demand values of generators may be of interest for energy management programs where processes may be altered or scheduled to reduce overall demand on a feeder.
Page 107: Pulse Output
MESSAGE The 489 can perform pulsed output of positive kWh and both positive and negative kvarh. Each output parameter can be assigned to any one of the alarm or auxiliary relays. Pulsed output is disabled for a parameter if the relay setpoint is selected as OFF for that pulsed output.
Page 108: S11 Analog I/O
MESSAGE The 489 has four analog output channels (4 to 20 mA or 0 to 1 mA as ordered). Each channel may be individually config- ured to represent a number of different measured parameters as shown in the table below. The minimum value pro- grammed represents the 4 mA output.
Page 109: Analog Inputs 1 To 4
Range: –50000 to 50000 in steps of 1 ANALOG INPUT1 ESCAPE MAXIMUM: 100 MESSAGE Range: 0 to 5000 sec. in steps of 1 BLOCK ANALOG INPUT1 ESCAPE FROM ONLINE: 0 s MESSAGE GE Power Management 489 Generator Management Relay 4-71...
Page 110 "25", and the Block From Online as "0 s". Set the alarm for a reasonable level slightly higher than the nor- mal vibration level. Program a delay of "3 s" and the pickup as "Over". 4-72 489 Generator Management Relay GE Power Management...
Page 111: Testing
SIMULATION MODE If the 489 is to be used for training, it might be desirable to allow all parameter averages, statistical information, and event recording to update when operating in simulation mode. If however, the 489 has been installed and will remain installed on a specific generator, it might be desirable assign a digital input to Test Input and to short that input to prevent all of this data from being corrupted or updated.
Page 112: Pre-Fault Setup
Range: 0 to 100% in steps of 1 PRE-FAULT ANALOG ESCAPE INPUT 4: 0% MESSAGE The values entered under Pre-Fault Values will be substituted for the measured values in the 489 when the SIMULATION is "Simulate Pre-Fault". MODE 4-74 489 Generator Management Relay...
Page 113: Fault Setup
The appropriate relay indicator will illuminate at that time. Selecting "Disabled" places the out- put relays back in service. If the 489 measures current or control power is cycled, the force operation of relays setpoint will automatically become disabled and the output relays will revert back to their normal states.
Page 114: Test Analog Output
If the 489 measures current or control power is cycled, the force analog output function is automati- cally disabled and all analog outputs will revert back to their normal state. Any time the analog outputs are forced, the In Service indicator will flash, indicating that the 489 is not in protection mode. 4.13.6 COMM PORT MONITOR ð...
Page 115: Actual Values
Actual value messages are organized into logical groups, or pages, for easy reference, as shown below. All actual value messages are illustrated and described in blocks throughout this chapter. All values shown in these message illustrations assume that no inputs (besides control power) are connected to the 489. A1 ACTUAL VALUES...
Page 116: A1 Status
The values for USED ESTIMATED TRIP will appear whenever the 489 thermal model picks up on the overload curve. TIME ON OVERLOAD 5.2.2 LAST TRIP DATA ð...
Page 117: Alarm Status
MESSAGE Immediately prior to issuing a trip, the 489 takes a snapshot of generator parameters and stores them as pre-trip values; this allows for troubleshooting after the trip occurs. The cause of last trip message is updated with the current trip and the screen defaults to that message.
Page 118 Range: 0 to 100% FLA. Reflects the present negative- NEG. SEQ. CURRENT ESCAPE sequence current level. ALARM: 15% FLA MESSAGE Range: 0.00 to 200000.00 A. Seen only if the GE HGF GROUND OVERCURRENT ESCAPE CT is used. Reflects the present ground ALARM: 5.00 A MESSAGE current level.
Page 119: Trip Pickups
ANALOG I/P 4 ESCAPE Name. The Analog Input level is shown here. ALARM: 201 Units MESSAGE If the 489 chassis is only partially engaged with the ALARM, 489 NOT ESCAPE case, this service alarm appears after 1 sec. Secure the INSERTED PROPERLY...
Page 120 Range: Not Enabled, Inactive, Timing Out, Active Trip, NEUTRAL U/V (3rd) ESCAPE Latched Trip. PICKUP: Not Enabled MESSAGE Range: Not Enabled, Inactive, Timing Out, Active Trip, LOSS OF EXCITATION 1 ESCAPE Latched Trip. PICKUP: Not Enabled MESSAGE 489 Generator Management Relay GE Power Management...
Page 121 Name. Seen only if input is enabled. Range: see ANALOG I/P 1 above ANALOG I/P 2 ESCAPE PICKUP: Not Enabled MESSAGE Range: see ANALOG I/P 1 above ANALOG I/P 3 ESCAPE PICKUP: Not Enabled MESSAGE GE Power Management 489 Generator Management Relay...
Page 122: Alarm Pickups
MESSAGE Range: Not Enabled, Inactive, Timing Out, Active Alarm, VOLTS/HERTZ ESCAPE Latched Alarm. PICKUP: Not Enabled MESSAGE Range: Not Enabled, Inactive, Timing Out, Active Alarm, UNDERFREQUENCY ESCAPE Latched Alarm. PICKUP: Not Enabled MESSAGE 489 Generator Management Relay GE Power Management...
Page 123 Range: Not Enabled, Inactive, Timing Out, Active Alarm, THERMAL MODEL ESCAPE Latched Alarm. PICKUP: Not Enabled MESSAGE Range: Not Enabled, Inactive, Timing Out, Active Alarm, TRIP COUNTER ESCAPE Latched Alarm. PICKUP: Not Enabled MESSAGE GE Power Management 489 Generator Management Relay...
Page 124 (no longer picked up, but had timed out and caused a alarm that is latched). These values may also be par- ticularly useful as data transmitted to a master device for monitoring. 5-10 489 Generator Management Relay GE Power Management...
Page 125: Real Time Clock
Range: 01/01/1995 to 12/31/2094, 00:00:00 to 23:59:59 REAL TIME CLOCK DATE: 01/01/1995 ENTER [ENTER] for more TIME: 12:00:00 ESCAPE The time and date from the 489 real time clock may be viewed here. GE Power Management 489 Generator Management Relay 5-11...
Page 126: A2 Metering Data
AMPS A, B, C DIFF. AMPS difference between the output side and the neutral end CT measurements on a per phase basis. The 489 negative- / FLA × 100%. The gener- sequence current is defined as the ratio of negative-sequence current to generator rated FLA, I ×...
Page 127: Voltage Metering
"No" in S2 SYSTEM, the follow- VT CONNECTION TYPE NEUTRAL VOLTAGE TRANSFORMER ing flash message will appear when an attempt is made to enter this group of messages. THIS FEATURE NOT PROGRAMMED GE Power Management 489 Generator Management Relay 5-13...
Page 128 (+vars). NOTE If the is programmed as "None", the flash message will appear when VT CONNECTION TYPE THIS FEATURE NOT PROGRAMMED an attempt is made to enter this group of messages. 5-14 489 Generator Management Relay GE Power Management...
Page 129: Temperature
The current level of the 12 RTDs will be displayed here. If the RTD is not connected, the value will be "No RTD". If no RTDs are programmed in the setpoints menu, the flash message will S7 RTD TEMPERATURE THIS FEATURE NOT PROGRAMMED appear when an attempt is made to enter this group of messages. GE Power Management 489 Generator Management Relay 5-15...
Page 130: Speed
If no digital input is configured for tachometer in the setpoints page, the THIS FEATURE NOT PRO- S3 DIGITAL INPUTS flash message will appear when an attempt is made to enter this group of messages. GRAMMED 5-16 489 Generator Management Relay GE Power Management...
Page 131: A3 Learned Data
None VOLTAGE: MESSAGE The 489 calculates the average magnitude of several parameters over a period of time. This time is specified by S1 489 setpoint (default 15 minutes). The calculation is a sliding win- SETUP \ PREFERENCES \ PARAMETER AVERAGES CALC PERIOD dow and is ignored when the generator is offline (that is, the value that was calculated just prior to going offline will be held until the generator is brought back online and a new calculation is made).
Page 132: Analog In Min/Max
ESCAPE MAX: 0 Units MESSAGE The 489 learns the minimum and maximum values of the analog inputs since they were last cleared. This information can be cleared using the setpoint. When the data is cleared, the present S1 489 SETUP \ CLEAR DATA \ CLEAR ANALOG I/P MIN/MAX value of each analog input will be loaded as a starting point for both minimum and maximum.
Page 133: A4 Maintenance
Range: 0 to 50000 NEUTRAL O/V (Fund) ESCAPE TRIPS: 0 MESSAGE Range: 0 to 50000 NEUTRAL U/V (3rd) ESCAPE TRIPS: 0 MESSAGE Range: 0 to 50000 LOSS OF EXCITATION 1 ESCAPE TRIPS: 0 MESSAGE GE Power Management 489 Generator Management Relay 5-19...
Page 134 Trip counters will not update if a digital input S1 489 SETUP / CLEAR DATA / CLEAR TRIP COUNTERS programmed as Test Input is shorted. In the event of multiple trips, the only the first trip will increment the trip counters.
Page 135: Timers
RESETS: 0 MESSAGE One of the 489 general counters will count the number of breaker operations over time. This may be useful information for breaker maintenance. The number of breaker operations is incremented whenever the breaker status changes from closed to open and all phase currents are zero.
Page 136: A5 Event Recorder
Range: –50 to +250°C. Seen only if 1 or more RTDs are AMBIENT ESCAPE programmed as Ambient. RTD#12 0°C E65535 MESSAGE Range: –50000 to 50000 ANALOG INPUT 1 ESCAPE Seen only if the Analog Input is in use. E65535: 0.0 Units MESSAGE 5-22 489 Generator Management Relay GE Power Management...
Page 137 MESSAGE The 489 Event Recorder stores generator and system information each time an event occurs. The description of the event is stored and a time and date stamp is also added to the record. This allows reconstruction of the sequence of events for troubleshooting.
Page 138 *Analog I/P 2 Alarm Hiset Phase O/C Trip *Analog I/P 3 Alarm Distance Zone 1 Trip *Analog I/P 4 Alarm Distance Zone 2 Trip Gnd. Directional Alarm reflects the name that is programmed 5-24 489 Generator Management Relay GE Power Management...
Page 139: A6 Product Info
MESSAGE All of the 489 model information may be viewed here when the unit is powered up. In the event of a product software upgrade or service question, the information shown here should be jotted down prior to any inquiry.
Page 140: Diagnostics
489 to display the next default message immediately. NEXT EXAMPLE: If a thermal model trip occurred, an RTD alarm may also occur as a result of the overload. The 489 would automatically default to the message at the top of the...
Page 141: Flash Messages
Flash messages are warning, error, or general information messages that are temporarily displayed in response to certain key presses. These messages are intended to assist with navigation of the 489 messages by explaining what has hap- pened or by prompting the user to perform certain actions.
Page 142 PRESS [ENTER] TO REMOVE MESSAGE: ENTER in the setpoint page. This message prompts the user to press to remove a S1 489 SETUP \ DEFAULT MESSAGES ENTER default message. To remove the default message, must be pressed while this message is being displayed. ENTER •...
Page 143 Group 1 as shown on the display. • This message appear each time a setpoint has been altered and stored to set- GROUP 2 SETPOINT HAS BEEN STORED: point Group 2 as shown on the display. GE Power Management 489 Generator Management Relay 5-29...
Page 144 5.8 DIAGNOSTICS 5 ACTUAL VALUES 5-30 489 Generator Management Relay GE Power Management...
Page 145: Communications
6.1.3 DATA FRAME FORMAT AND DATA RATE One data frame of an asynchronous transmission to or from a 489 is default to 1 start bit, 8 data bits, and 1 stop bit. This produces a 10-bit data frame. This is important for transmission through modems at high bit rates (11 bit data frames are not supported by Hayes modems at bit rates of greater than 300 bps).
Page 146 If a 489 Modbus slave device receives a transmission in which an error is indicated by the CRC-16 calculation, the slave device will not respond to the transmission. A CRC-16 error indicates than one or more bytes of the transmission were received incorrectly and thus the entire transmission should be ignored in order to avoid the 489 performing any incorrect operation.
Page 147: Algorithm
(i.e. all slaves start listening for a new transmission from the master). Thus at 9600 baud a delay of greater than 3.5 × 1 / 9600 × 10 = 3.65 ms will cause the communication link to be reset. GE Power Management 489 Generator Management Relay...
Page 148: Supported Modbus Functions
Read Setpoints and Actual Values For the 489 Modbus implementation, these commands are used to read any setpoint ("holding registers") or actual value ("input registers"). Holding and input registers are 16-bit (two byte) values transmitted high order byte first. Thus all 469 set- points and actual values are sent as two bytes.
Page 149: Function Code 05: Execute Operation
Preset Single Register 489 Implementation: Store Single Setpoint This command allows the master to store a single setpoint into the 489 memory. The slave response to this function code is to echo the entire master transmission. MESSAGE FORMAT AND EXAMPLE Request slave 11 to store the value 01F4 in Setpoint address 1180.
Page 150: Function Code 07: Read Device Status
This function reads the selected device status. A short message length allows for rapid reading of status. The returned sta- tus byte has individual bits set to 1 or 0 depending on the slave device status. The 489 general status byte is shown below: BIT NO.
Page 151: Function Code 16: Store Multiple Setpoints
Modbus allows up to a maximum of 60 holding regis- ters to be stored. The 489 response to this function code is to echo the slave address, function code, starting address, the number of Setpoints stored, and the CRC.
Page 152: Function Code 16: Performing Commands
6.2.9 ERROR RESPONSES When a 489 detects an error other than a CRC error, a response will be sent to the master. The MSbit of the FUNCTION CODE byte will be set to 1 (i.e. the function code sent from the slave will be equal to the function code sent from the master plus 128).
Page 153: Memory Map
6.3.1 MEMORY MAP INFORMATION The data stored in the 489 is grouped as Setpoints and Actual Values. Setpoints can be read and written by a master com- puter. Actual Values are read only. All Setpoints and Actual Values are stored as two byte values. That is, each register address is the address of a two-byte value.
Page 154: Waveform Capture
6.3.4 WAVEFORM CAPTURE The 489 stores up to 64 cycles of A/D samples in a waveform capture buffer each time a trip occurs. The waveform capture buffer is time and date stamped and may therefore be correlated to a trip in the event record. To access the waveform cap- ture memory, select the channel of interest by writing the number to the Waveform Capture Channel Selector (30F5h).
Page 155 6 COMMUNICATIONS 6.3 MEMORY MAP 6.3.7 489 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 1 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT PRODUCT ID 0000 GE POWER MANAGEMENT PRODUCT DEVICE CODE 0001 PRODUCT HARDWARE REVISION 1 to 26...
Page 156 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 2 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 023D REACTIVE POWER Mvar PreTrip –2000000 to 2000000 Mvar 023F APPARENT POWER MVA PreTrip 0 to 2000000 0241 LAST TRIP DATA STATOR RTD 1 to 12 –...
Page 157 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 3 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 029E RTD #3 PICKUP 0 to 4 – F123 029F RTD #4 PICKUP 0 to 4 – F123 02A0...
Page 158 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 4 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 0320 RTD #12 PICKUP 0 to 4 – F123 0321 OPEN SENSOR PICKUP 0 to 4 – F123 0322...
Page 159 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 5 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 0421 PHASE B CURRENT ANGLE 0 to 359 ° 0422 PHASE A CURRENT ANGLE 0 to 359 ° 0423...
Page 160 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 6 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 04AC RTD #11 TEMPERATURE –52 to 251 °C –52 04AD RTD #12 TEMPERATURE –52 to 251 °C –52 04C0 HOTTEST STATOR RTD TEMPERATURE –52 to 250...
Page 161 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 7 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 0643 RTD #4 MAX. TEMP. –52 to 251 °F –52 0644 RTD #5 MAX. TEMP. –52 to 251 °F –52...
Page 162 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 8 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 07A1 NUMBER OF THERMAL RESETS 0 to 50000 – MAINTENANCE / TRIP COUNTERS 07A2 LOSS OF EXCITATION 1 TRIPS 0 to 50000 –...
Page 163 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 9 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 1138 CLEAR BREAKER INFORMATION 0 to 1 – F103 SYSTEM SETUP / CURRENT SENSING 1180 PHASE CT PRIMARY 10 to 50001...
Page 164 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 10 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 1242 ASSIGN TRIP RELAYS (1-4) 0 to 3 – 1243 GENERAL INPUT B TRIP DELAY 1 to 50000 DIGITAL INPUTS / GENERAL INPUT C...
Page 165 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 11 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 12B2 INPUT NAME 0 to 12 – 12B8 BLOCK INPUT FROM ONLINE 0 to 5000 12B9 GENERAL INPUT F CONTROL 0 to 1 –...
Page 166 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 12 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 13A2 TACHOMETER ALARM 0 to 2 – F115 13A3 ASSIGN ALARM RELAYS (2-5) 1 to 4 – 13A4 TACHOMETER ALARM SPEED...
Page 167 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 13 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT FLEXCURVE TRIP TIME AT 1.80 × PU 160E 0 to 65535 65535 FLEXCURVE TRIP TIME AT 1.90 × PU...
Page 168 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 14 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT FLEXCURVE TRIP TIME AT 11.5 × PU 1643 0 to 65535 65535 FLEXCURVE TRIP TIME AT 12.0 × PU...
Page 169 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 15 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT FLEXCURVE TRIP TIME AT 1.90 × PU 1733 0 to 65535 65535 FLEXCURVE TRIP TIME AT 2.00 × PU...
Page 170 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 16 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT FLEXCURVE TRIP TIME AT 12.0 × PU 1768 0 to 65535 65535 FLEXCURVE TRIP TIME AT 12.5 × PU...
Page 171 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 17 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 2009 UNDERVOLTAGE CURVE RESET RATE 0 to 9999 200A UNDERVOLTAGE CURVE ELEMENT 0 to 1 – F208 VOLTAGE ELEMENTS / OVERVOLTAGE...
Page 172 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 18 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 20A9 OVERFREQUENCY TRIP LEVEL1 2501 to 7000 6050 20AA OVERFREQUENCY TRIP DELAY1 1 to 50000 20AB OVERFREQUENCY TRIP LEVEL2...
Page 173 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 19 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 213A ZONE 2 ANGLE 50 to 85 ° 213B ZONE 2 TRIP DELAY 0 to 1500 POWER ELEMENTS / REACTIVE POWER...
Page 174 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 20 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 2427 ASSIGN TRIP RELAYS (1-4) 0 to 3 – 2428 RTD #1 TRIP TEMPERATURE 1 to 250 °C 2429...
Page 175 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 21 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 2565 RTD #6 TRIP 0 to 2 – F115 2566 RTD #6 TRIP VOTING 1 to 12 – F122...
Page 176 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 22 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 26A3 RTD #11 ALARM TEMPERATURE 1 to 250 °C 26A4 RTD #11 ALARM EVENTS 0 to 1 – F105...
Page 177 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 23 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT TIME TO TRIP AT 3.50 × FLA 2828 5 to 999999 TIME TO TRIP AT 3.75 × FLA 282A 5 to 999999 TIME TO TRIP AT 4.00 ×...
Page 178 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 24 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT × FLA 2A63 CURRENT DEMAND LIMIT 10 to 2000 2A65 CURRENT DEMAND ALARM EVENTS 0 to 1 F105 MONITORING / MW DEMAND...
Page 179 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 25 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT × FLA 2B0E AVERAGED GEN. LOAD MIN 0 to 2000 × FLA 2B0F AVERAGED GEN. LOAD MAX 0 to 2000...
Page 180 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 26 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 2B46 ANALOG INPUT 1 MAX –50000 to 50000 Units 50000 2B48 ANALOG INPUT 2 MIN –50000 to 50000 Units...
Page 181 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 27 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 2C56 ANALOG INPUT2 TRIP LEVEL –50000 to 50000 Units 2C58 ANALOG INPUT2 TRIP PICKUP 0 to 1 – F130...
Page 182 6.3 MEMORY MAP 6 COMMUNICATIONS Table 6–1: 489 MEMORY MAP (Sheet 28 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 2D29 PRE-FAULT AMBIENT RTD TEMP –50 to 250 °C 2D2A PRE-FAULT SYSTEM FREQUENCY 50 to 900 2D2B PRE-FAULT ANALOG INPUT 1...
Page 183 6 COMMUNICATIONS 6.3 MEMORY MAP Table 6–1: 489 MEMORY MAP (Sheet 29 of 29) ADDR NAME RANGE STEP UNITS FORMAT DEFAULT 3016 NEG. SEQ. CURRENT 0 to 2000 %FLA 3017 GROUND CURRENT 0 to 20000000 3019 A-B VOLTAGE 0 to 50000...
Page 184: Memory Map Data Formats
0 = None, 1 = 1 A Secondary, 2 = 50:0.025 Ground CT, 3 = 5 A Secondary F105 Unsigned Off / On selection 16 bit integer 0 = Off, 1 = On 6-40 489 Generator Management Relay GE Power Management...
Page 185 IAC Extremely Inverse ANSI Normally Inverse IAC Very Inverse ANSI Moderately Inverse IAC Inverse IEC Curve A (BS142) IAC Short Inverse IEC Curve B (BS142) Flexcurve™ IEC Curve C (BS142) Definite Time GE Power Management 489 Generator Management Relay 6-41...
Page 186 Distance Zone 2 Trip Analog I/P 4 Trip Broken Rotor Bar Dig I/P Wavefrm Trig Single Phasing Trip Analog I/P 1 Alarm Serial Waveform Trig Reverse Power Trip Analog I/P 2 Alarm 6-42 489 Generator Management Relay GE Power Management...
Page 187 Undervoltage trip element type 16 bit integer 0 = Curve, 1 = Definite Time F209 Unsigned Breaker operation type 16 bit integer 0 = Breaker Auxiliary a, 1 = Breaker Auxiliary b GE Power Management 489 Generator Management Relay 6-43...
Page 188 Unsigned Step Up Transformer Type 16 bit integer 0 = None, 1 = Delta/Wye F220 Unsigned IRIG-B Type 16 bit integer 0 = None, 1 = DC Shift, 2 = Amplitude Modulated 6-44 489 Generator Management Relay GE Power Management...
Page 189: Dnp Communications
6.4 DNP COMMUNICATIONS 6.4 DNP COMMUNICATIONS 6.4.1 DEVICE PROFILE DOCUMENT DNP 3.0 DEVICE PROFILE DOCUMENT Vendor Name: General Electric Power Management Inc. Device Name: 489 Generator Management Relay Highest DNP Level Supported: Device Function: Ë For Requests: Level 2 Master...
Page 190 No Counters Reported No Counters Reported Ë Ë Configurable Configurable Ë 16 Bits Default Object Ë 32 Bits Default Variation Ë Ë Point-by-point list attached Other Value Point-by-point list attached Sends Multi-Fragment Responses: 6-46 489 Generator Management Relay GE Power Management...
Page 191: Implementation Table
Internal Indications 00 (Note 4) No object (cold restart command) No object (warm restart command) No object (delay measurement command) (Note 5) For Notes, see the IMPLEMENTATION TABLE NOTES on the following page. GE Power Management 489 Generator Management Relay 6-47...
Page 192: Default Variations
Binary Input - Single Bit Binary Input Change With Time Binary Output Status 16-Bit Binary Counter without Flag 16-Bit Frozen Counter without Flag 32-Bit Analog Input Without Flag 32-Bit Analog Input Change Without Time 6-48 489 Generator Management Relay GE Power Management...
Page 193: Dnp Point Lists
Class 1 Latched or Latched Assignable Input 7 Trip Active / Class 1 Loss of Excitation Circle 2 Trip Active Class 1 Latched or Latched Sequential Trip Active or Latched Class 1 GE Power Management 489 Generator Management Relay 6-49...
Page 194 RTD #4 Alarm Active or Latched Class 1 assigned to Class 1 will cause the generation of an RTD #5 Alarm Active or Latched Class 1 NOTE event object. RTD #6 Alarm Active or Latched Class 1 6-50 489 Generator Management Relay GE Power Management...
Page 195: Binary / Control Relay Output Block (Objects 10/12)
When using object 10 to read the status of any Binary Output, a value of zero will always be returned. This is due to the fact that all points are “Pulse On” and are deemed to be normally off. GE Power Management 489 Generator Management Relay 6-51...
Page 196: Binary / Frozen Counter (Objects 20/21)
There is only one copy of each counter, so clearing a counter via NOTE Modbus or the front panel display causes the corresponding DNP counter point to be cleared and vice-versa. 6-52 489 Generator Management Relay GE Power Management...
Page 197: Analog Input / Input Change (Objects 30/32)
Therefore, the value read should be interpreted in this manner. Many of the values reported by the 489 have a size of 32-bits and have had their upper and lower 16-bit components assigned to separate points. Where indicated, refer to the appropriate note following the table for more detail.
Page 198 Third Harmonic Terminal Voltage (tenths of a volt) Class 2 Note 10 Vab/Iab (loss of excitation impedance) Class 2 Vab/Iab Angle (loss of excitation impedance angle) Class 2 Power Factor Class 2 Real Power (MW) Class 2 Note 8 6-54 489 Generator Management Relay GE Power Management...
Page 199 Average Phase-Phase Voltage Class 2 User Map Value 1 Note 5 User Map Value 2 Note 5 ↓ ↓ ↓ ↓ …↓... User Map Value 124 Note 5 User Map Value 125 Note 5 GE Power Management 489 Generator Management Relay 6-55...
Page 200 The user should select the unit which is closest to providing the resolution and range desired. If 32-bit analog input capability is present, the higher-resolution (tenths of a volt) points should generally be used, since they provide the greatest resolution. 6-56 489 Generator Management Relay GE Power Management...
Page 201: Testing
489 hardware while also testing firmware/hardware interaction in the process. Since the 489 is packaged in a dra- wout case, a demo case (metal carry case in which the 489 may be mounted) may be useful for creating a portable test set with a wiring harness for all of the inputs and outputs.
Page 202: Secondary Injection Test Setup
ASSIGNABLE INPUT 5 ASSIGNABLE INPUT 6 ASSIGNABLE INPUT 7 COMMON SWITCH +24Vdc COMPUTER ANALOG I/O AUXILIARY COMM. ACCESS RS485 RS485 ANALOG OUTPUTS ANALOG INPUTS BREAKER STATUS RS485 RS485 Figure 7–1: SECONDARY INJECTION TEST SETUP 489 Generator Management Relay GE Power Management...
Page 203: Hardware Functional Testing
APPLIED LINE- EXPECTED VOLTAGE MEASURED VOLTAGE NEUTRAL VOLTAGE READING 30 V 300 V 50 V 500 V 100 V 1000 V 150 V 1500 V 200 V 2000 V 270 V 2700 V GE Power Management 489 Generator Management Relay...
Page 204: Ground (1A), Neutral And Differential Current Accuracy
View the measured values in: A2 METERING DATA\VOLTAGE METERING APPLIED NEUTRAL EXPECTED NEUTRAL MEASURED NEUTRAL VOLTAGE AT 60 HZ VOLTAGE VOLTAGE 10 V 100 V 30 V 300 V 50 V 500 V 489 Generator Management Relay GE Power Management...
Page 205: Negative Sequence Current Accuracy
7.2 HARDWARE FUNCTIONAL TESTING 7.2.5 NEGATIVE SEQUENCE CURRENT ACCURACY The 489 measures negative sequence current as a percent of Full Load Amperes (FLA). A sample calculation of negative sequence current is shown below. Given the following generator parameters: Rated MVA ( P ) = 1.04...
Page 206: Rtd Accuracy
10 Ω COPPER °C °F 7.49 Ω –40°C –40°F 9.04 Ω 0°C 32°F 10.97 Ω 50°C 122°F 12.90 Ω 100°C 212°F 14.83 Ω 150°C 302°F 16.78 Ω 200°C 392°F 18.73 Ω 250°C 482°F 489 Generator Management Relay GE Power Management...
Page 207: Digital Inputs And Trip Coil Supervision
MEASURED ANALOG INPUT OUTPUT AMMETER (MA) ANALOG INPUT READING (UNITS) FORCE READING READING VALUE 4 mA 0 units 8 mA 250 units 12 mA 500 units 16 mA 750 units 100% 20 mA 1000 units GE Power Management 489 Generator Management Relay...
Page 208: Output Relays
NO NC R1 Trip R2 Auxiliary R3 Auxiliary R4 Auxiliary R5 Alarm R6 Service All Relays No Relays R6 Service relay is failsafe or energized normally, operating R6 causes it to de-energize. NOTE 489 Generator Management Relay GE Power Management...
Page 209: Additional Functional Testing
6.00 × FLA 6000 A 9.99 sec. 9.79 to 10.19 sec. 10.00 × FLA 10000 A 5.55 sec. 5.44 to 5.66 sec. Generator Rated MVA ---------------------------------------------------------------------------------------------------------- - × 3 Generator Phase-to-Phase Voltage NOTE GE Power Management 489 Generator Management Relay...
Page 210: Power Measurement Test
Va = 120 V∠288° lag Va = 120 V∠288° lag 3519 kvar Vb = 120 V∠48° lag Vb = 120 V∠48° lag Vc = 120 V∠168° lag Vc = 120 V∠168° lag 7-10 489 Generator Management Relay GE Power Management...
Page 211: Reactive Power Test
Ibn=5 A∠100°lag Icn=5 A∠220°lag Vab=120V∠0° Vbc=120V∠120°lag Vca=120V∠240°lag –52 –57 to –47 Ian=5 A∠330°lag Ibn=5 A∠90°lag Icn=5 A∠210°lag Vab=120V∠0° Vbc=120V∠120°lag Vca=120V∠240°lag 47 to 57 Ian=5 A∠30°lag Ibn=5 A∠150°lag Icn=5 A∠270°lag Activated Not Activated GE Power Management 489 Generator Management Relay 7-11...
Page 212: Voltage Phase Reversal Test
PHASE REVERSAL TRIP Vb = 120 V∠240° lag Vc = 120 V∠120° lag 7.3.5 INJECTION TEST SETUP #2 Setup the 489 device as follows for the following tests. Figure 7–2: SECONDARY INJECTION SETUP #2 7-12 489 Generator Management Relay GE Power Management...
Page 213: Ge Power Management Hgf Ground Accuracy Test
5 mA 10.00 A 7.3.7 NEUTRAL VOLTAGE (3RD HARMONIC) ACCURACY TEST The 489 specification for neutral voltage (3rd harmonic) accuracy is ±0.5% of full scale (100 V). Perform the steps below to verify accuracy. Alter the following setpoints: S2 SYSTEM SETUP\VOLTAGE SENSING\NEUTRAL VOLTAGE TRANSFORMER: 10.00:1...
Page 214: Phase Differential Trip Test
7.3 ADDITIONAL FUNCTIONAL TESTING 7 TESTING 7.3.8 PHASE DIFFERENTIAL TRIP TEST The 489 phase differential compares the current level at terminal end with the current level at neutral end. The differential element will trip when: > × diff restraint given –...
Page 215: Injection Test Setup #3
TRIP Repeat for phases B & C. Rewiring of Figure 7–2: SECONDARY INJECTION SETUP #2 on page 7–12 is required. 7.3.9 INJECTION TEST SETUP #3 Figure 7–4: SECONDARY INJECTION TEST SETUP #3 GE Power Management 489 Generator Management Relay 7-15...
Page 216: Voltage Restrained Overcurrent Test
Ian = 10 A∠0° Vab = 60 V∠0° Ibn = 10 A∠120° lag Vbc = 60 V∠120° lag 1.7 sec. Icn = 10 A∠240° lag Vca = 60 V∠240° lag activated; Not Activated 7-16 489 Generator Management Relay GE Power Management...
Page 217: Pc Software
Windows 3.1, Windows 3.11 for Workgroups, Windows 95/98, or Windows NT. Windows 3.1 users must ensure that SHARE.EXE is installed. 489PC may be installed from either the GE Power Management Products CD or the GE Power Management web- NOTE site at www.GEindustrial.com/pm. If you are using legacy equipment without web access or a CD, 3.5”...
Page 218: Checking If Installation/Upgrade Is Required
If 489PC is already installed, run the program and use the following procedure to check if it needs upgrading: While 489PC is running, insert the GE Power Management Products CD and allow it to autostart (alternately, load the D:\index.htm file from the CD into your default web browser), OR Go to the GE Power Management website at www.GEindustrial.com/pm (preferred method)
Page 219: Installing/Upgrading 489Pc
Figure 8–1: GE POWER MANAGEMENT WELCOME SCREEN Click the Index by Product Name item from the Products menu of the left side of the page then select 489 Generator Management Relay from the product list to open the 489 product page.
Page 220: Configuration
To begin communications, click the ON button. The status section indicates the communications status. The message “489PC is now talking to a 489” is displayed when communications are established. As well, the bottom right corner of the 489PC window will indicate “Communicating.”...
Page 221: Using 489Pc
When the correct firmware version is chosen, select the File > Save As menu item. This launches the dialog box shown below. Enter or select the filename under which the setpoints are to be saved. All 489 setpoint files should have the extension 489 (for example, gen1.489).
Page 222: Upgrading The 489 Firmware
8.3.2 UPGRADING THE 489 FIRMWARE Prior to downloading new firmware into the 489, it is necessary to save the 489 setpoints to a file (see Section 8.3.1: SAV- ING SETPOINTS TO A FILE on page 8–5. Loading new firmware into the 489 flash memory is accomplished as follows: Ensure the computer is connected to the 489 via the front RS232 port and that communications have been estab- lished.
Page 223: Loading Setpoints From A File
The following procedure demonstrates how to load setpoints from a file: Select the File > Open menu item. 489PC will launch the Open window and list all filenames in the 489 default directory with the 489 extension. Select the setpoint file to download and click OK to continue.
Page 224 GROUND CT TYPE point value box displays a drop down selection menu. For setpoints requiring an alphanumeric text string (e.g. message scratchpad messages), the value may be entered directly within the setpoint value box. 489 Generator Management Relay GE Power Management...
Page 225: Upgrading Setpoint Files To New Revision
8 489PC SOFTWARE 8.3 USING 489PC 8.3.5 UPGRADING SETPOINT FILES TO NEW REVISION It may be necessary to upgrade the revision code for a previously saved setpoint file after the 489 firmware has been upgraded. Establish communications with the 489 relay.
Page 226 8 489PC SOFTWARE 8.3.7 TRENDING Trending from the 489 can be accomplished via the 489PC program. Many different parameters can be trended and graphed at sampling periods ranging from 1 second up to 1 hour. The parameters which can be Trended by the 489PC software are:...
Page 227 Click on these buttons to view Displays the value of the graph The trended data Cursor Line 1, Cursor Line 2, or at the active Cursor Line from the 489 relay Delta (difference) values for the graph CHECK BOXES BUTTONS CURSOR LINES...
Page 228 The phase A current waveform for the last 489 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.
Page 229: Phasors
CURRENT PHASOR VOLTAGE PHASOR Displays the value and Short arrow Long arrow the angle of the voltage phasors CURRENT LEVEL Displays the value and angle of the current phasors Figure 8–7: PHASORS GE Power Management 489 Generator Management Relay 8-13...
Page 230: Event Recorder
8.3.10 EVENT RECORDER The 489 event recorder can be viewed through the 489PC software. The event recorder stores generator and system infor- mation each time an event occurs (e.g. a generator trip). Up to 40 events can be stored, where EVENT01 is the most recent and EVENT40 is the oldest.
Page 231: Troubleshooting
If Windows™ prevents the replacing of this file, restart the PC and replace the file before any programs are opened. Restart Windows™ for these changes to take full effect. GE Power Management 489 Generator Management Relay 8-15...
Page 232 8.3 USING 489PC 8 489PC SOFTWARE 8-16 489 Generator Management Relay GE Power Management...
Page 233: Setpoints Summary
APPENDIX A A.1 COMMISSIONING APPENDIX A COMMISSIONINGA.1 COMMISSIONING A.1.1 SETPOINTS SUMMARY Table A–1: SETPOINTS PAGE 1 – 489 SETUP Table A–2: SETPOINTS PAGE 2 – SYSTEM SETUP DESCRIPTION DEFAULT USER VALUE DESCRIPTION DEFAULT USER VALUE PASSCODE CURRENT SENSING Passcode ------...
Page 234 General Input B Alarm Events Assign Trip Relays ---- General Input B Trip General Input D Trip Delay 5.0 sec. Assign Trip Relays ---- Assign Trip Relays General Input B Trip Delay 5.0 sec. 489 Generator Management Relay GE Power Management...
Page 235 Low Fwd Pwr General Input F Trip Assign Trip Relays ---- 0.05 × Rated Assign Trip Relays ---- Sequential Trip Level General Input F Trip Delay 5.0 sec. Sequential Trip Delay 1.0 sec. GE Power Management 489 Generator Management Relay...
Page 236: Description
Table A–4: SETPOINTS PAGE 4 – OUTPUT RELAYS DESCRIPTION DEFAULT USER VALUE RELAY RESET MODE R1 Trip All Resets R2 Auxiliary All Resets R3 Auxiliary All Resets R4 Auxiliary All Resets R5 Alarm All Resets R6 Service All Resets 489 Generator Management Relay GE Power Management...
Page 237 Flexcurve Trip Time at 2.00 x PU 65535 ms Flexcurve Trip Time at 2.10 x PU 65535 ms Flexcurve Trip Time at 2.20 x PU 65535 ms Flexcurve Trip Time at 2.30 x PU 65535 ms GE Power Management 489 Generator Management Relay...
Page 238 Flexcurve Trip Time at 5.90 x PU 65535 ms Flexcurve Trip Time at 6.00 x PU 65535 ms Flexcurve Trip Time at 6.50 x PU 65535 ms Flexcurve Trip Time at 7.00 x PU 65535 ms 489 Generator Management Relay GE Power Management...
Page 239 Flexcurve Trip Time at 19.00 x PU 65535 ms Flexcurve Trip Time at 19.50 x PU 65535 ms Flexcurve Trip Time at 20.00 x PU 65535 ms Overcurrent Curve Multiplier 1.00 Overcurrent Curve Reset Instantaneous GE Power Management 489 Generator Management Relay...
Page 240 Flexcurve Trip Time at 2.00 x PU 65535 ms Flexcurve Trip Time at 2.10 x PU 65535 ms Flexcurve Trip Time at 2.20 x PU 65535 ms Flexcurve Trip Time at 2.30 x PU 65535 ms 489 Generator Management Relay GE Power Management...
Page 241 Flexcurve Trip Time at 5.90 x PU 65535 ms Flexcurve Trip Time at 6.00 x PU 65535 ms Flexcurve Trip Time at 6.50 x PU 65535 ms Flexcurve Trip Time at 7.00 x PU 65535 ms GE Power Management 489 Generator Management Relay...
Page 242 Flexcurve Trip Time at 19.00 x PU 65535 ms Flexcurve Trip Time at 19.50 x PU 65535 ms Flexcurve Trip Time at 20.00 x PU 65535 ms Overcurrent Curve Multiplier 1.00 Overcurrent Curve Reset Instantaneous A-10 489 Generator Management Relay GE Power Management...
Page 243 Ground Directional Trip Pickup Ground Directional Trip Delay 3.0 sec. HIGH-SET PHASE OVERCURRENT High-Set Phase Overcurrent Trip Assign Trip Relays 1--- 5.00 × CT High-Set Phase O/C Pickup High-Set Phase O/C Delay 1.00 sec. GE Power Management 489 Generator Management Relay A-11...
Page 244 1.00 x Nominal Volts/Hertz Trip Delay 1.0 sec. Volts/Hertz Curve Reset Rate 1.4 sec. Volts/Hertz Trip Element Curve #1 UNDERFREQUENCY Block Underfrequency From Online 1.0 sec 0.50 × Rated Voltage Level Cutoff A-12 489 Generator Management Relay GE Power Management...
Page 245 Neutral Overvoltage Alarm Events Neutral Overvoltage Trip Assign Trip Relays 1--- Neutral Overvoltage Trip Level 5.0 Vsec. Neutral Overvoltage Trip Delay 1.0 sec. Neutral O/V Curve Reset Rate Neutral Overvoltage Trip Element Definite Time GE Power Management 489 Generator Management Relay A-13...
Page 246 Zone #1 Angel 75° Zone #1 Trip Delay 0.4 sec. Zone #2 Trip Assign Zone #2 Trip Relays 1--- 15.0 Ωsec. Zone #2 Reach Zone #2 Angle 75° Zone #2 Trip Delay 2.0 sec. A-14 489 Generator Management Relay GE Power Management...
Page 247 Low Forward Power Alarm Delay 10.0 sec. Low Forward Power Alarm Events Low Forward Power Trip Assign Trip Relays 1--- 0.05 × Rated MW Low Forward Power Trip Level Low Forward Power Trip Delay 20.0 sec. GE Power Management 489 Generator Management Relay A-15...
Page 248 OPEN RTD SENSOR Open RTD Sensor Alarm Assign Alarm Relays ---5 Open RTD Sensor Alarm Events APPLICATION NAME ALARM ASSIGN ALARM ALARM ALARM EVENTS RELAYS TEMPERATURE TRIP TRIP VOTING ASSIGN TRIP TRIP RELAYS TEMPERATURE A-16 489 Generator Management Relay GE Power Management...
Page 249 OPEN RTD SENSOR Open RTD Sensor Alarm Assign Alarm Relays ---5 Open RTD Sensor Alarm Events APPLICATION NAME ALARM ASSIGN ALARM ALARM ALARM EVENTS RELAYS TEMPERATURE TRIP TRIP VOTING ASSIGN TRIP TRIP RELAYS TEMPERATURE GE Power Management 489 Generator Management Relay A-17...
Page 250 Time to Trip at 6.00 × FLA 65535 ms Time to Trip at 6.50 × FLA 65535 ms Time to Trip at 7.00 × FLA 65535 ms Time to Trip at 7.50 × FLA 65535 ms A-18 489 Generator Management Relay GE Power Management...
Page 251 5.00 × FLA Accel. Intersect @ 100% Voltage THERMAL ELEMENTS Thermal Model Alarm Assign Alarm Relays ---5 Thermal Alarm Level 75% Used Thermal Model Alarm Events Thermal Model Trip Assign Trip Relays 1--- GE Power Management 489 Generator Management Relay A-19...
Page 252 Generator Running Hours Limit 1000 hrs Current Demand Alarm Events MW DEMAND MW Demand Period 15 min. MW Demand Alarm Assign Alarm Relays ---5 1.25 × Rated MW Demand Limit MW Demand Alarm Events A-20 489 Generator Management Relay GE Power Management...
Page 253 ANALOG INPUT 4 Setup Name Units Minimum Maximum Block From Online Alarm Assign Alarm Relays Alarm Level Alarm Pickup Alarm Delay Alarm Events Trip Assign Trip Relays Trip Level Trip Pickup Trip Delay GE Power Management 489 Generator Management Relay A-21...
Page 254 A.1 COMMISSIONING APPENDIX A A-22 489 Generator Management Relay GE Power Management...
Page 255 APPENDIX A A.1 COMMISSIONING APPENDIX A COMMISSIONINGA.1 COMMISSIONING A.1.1 SETPOINTS SUMMARY Table A–1: SETPOINTS PAGE 1 – 489 SETUP Table A–2: SETPOINTS PAGE 2 – SYSTEM SETUP DESCRIPTION DEFAULT USER VALUE DESCRIPTION DEFAULT USER VALUE PASSCODE CURRENT SENSING Passcode ------...
Page 256 General Input B Alarm Events Assign Trip Relays ---- General Input B Trip General Input D Trip Delay 5.0 sec. Assign Trip Relays ---- Assign Trip Relays General Input B Trip Delay 5.0 sec. 489 Generator Management Relay GE Power Management...
Page 257 Low Fwd Pwr General Input F Trip Assign Trip Relays ---- 0.05 × Rated Assign Trip Relays ---- Sequential Trip Level General Input F Trip Delay 5.0 sec. Sequential Trip Delay 1.0 sec. GE Power Management 489 Generator Management Relay...
Page 258 Table A–4: SETPOINTS PAGE 4 – OUTPUT RELAYS DESCRIPTION DEFAULT USER VALUE RELAY RESET MODE R1 Trip All Resets R2 Auxiliary All Resets R3 Auxiliary All Resets R4 Auxiliary All Resets R5 Alarm All Resets R6 Service All Resets 489 Generator Management Relay GE Power Management...
Page 259 Flexcurve Trip Time at 2.00 x PU 65535 ms Flexcurve Trip Time at 2.10 x PU 65535 ms Flexcurve Trip Time at 2.20 x PU 65535 ms Flexcurve Trip Time at 2.30 x PU 65535 ms GE Power Management 489 Generator Management Relay...
Page 260 Flexcurve Trip Time at 5.90 x PU 65535 ms Flexcurve Trip Time at 6.00 x PU 65535 ms Flexcurve Trip Time at 6.50 x PU 65535 ms Flexcurve Trip Time at 7.00 x PU 65535 ms 489 Generator Management Relay GE Power Management...
Page 261 Flexcurve Trip Time at 19.00 x PU 65535 ms Flexcurve Trip Time at 19.50 x PU 65535 ms Flexcurve Trip Time at 20.00 x PU 65535 ms Overcurrent Curve Multiplier 1.00 Overcurrent Curve Reset Instantaneous GE Power Management 489 Generator Management Relay...
Page 262 Flexcurve Trip Time at 2.00 x PU 65535 ms Flexcurve Trip Time at 2.10 x PU 65535 ms Flexcurve Trip Time at 2.20 x PU 65535 ms Flexcurve Trip Time at 2.30 x PU 65535 ms 489 Generator Management Relay GE Power Management...
Page 263 Flexcurve Trip Time at 5.90 x PU 65535 ms Flexcurve Trip Time at 6.00 x PU 65535 ms Flexcurve Trip Time at 6.50 x PU 65535 ms Flexcurve Trip Time at 7.00 x PU 65535 ms GE Power Management 489 Generator Management Relay...
Page 264 Flexcurve Trip Time at 19.00 x PU 65535 ms Flexcurve Trip Time at 19.50 x PU 65535 ms Flexcurve Trip Time at 20.00 x PU 65535 ms Overcurrent Curve Multiplier 1.00 Overcurrent Curve Reset Instantaneous A-10 489 Generator Management Relay GE Power Management...
Page 265 Ground Directional Trip Pickup Ground Directional Trip Delay 3.0 sec. HIGH-SET PHASE OVERCURRENT High-Set Phase Overcurrent Trip Assign Trip Relays 1--- 5.00 × CT High-Set Phase O/C Pickup High-Set Phase O/C Delay 1.00 sec. GE Power Management 489 Generator Management Relay A-11...
Page 266 1.00 x Nominal Volts/Hertz Trip Delay 1.0 sec. Volts/Hertz Curve Reset Rate 1.4 sec. Volts/Hertz Trip Element Curve #1 UNDERFREQUENCY Block Underfrequency From Online 1.0 sec 0.50 × Rated Voltage Level Cutoff A-12 489 Generator Management Relay GE Power Management...
Page 267 Neutral Overvoltage Alarm Events Neutral Overvoltage Trip Assign Trip Relays 1--- Neutral Overvoltage Trip Level 5.0 Vsec. Neutral Overvoltage Trip Delay 1.0 sec. Neutral O/V Curve Reset Rate Neutral Overvoltage Trip Element Definite Time GE Power Management 489 Generator Management Relay A-13...
Page 268 Zone #1 Angel 75° Zone #1 Trip Delay 0.4 sec. Zone #2 Trip Assign Zone #2 Trip Relays 1--- 15.0 Ωsec. Zone #2 Reach Zone #2 Angle 75° Zone #2 Trip Delay 2.0 sec. A-14 489 Generator Management Relay GE Power Management...
Page 269 Low Forward Power Alarm Delay 10.0 sec. Low Forward Power Alarm Events Low Forward Power Trip Assign Trip Relays 1--- 0.05 × Rated MW Low Forward Power Trip Level Low Forward Power Trip Delay 20.0 sec. GE Power Management 489 Generator Management Relay A-15...
Page 270 OPEN RTD SENSOR Open RTD Sensor Alarm Assign Alarm Relays ---5 Open RTD Sensor Alarm Events APPLICATION NAME ALARM ASSIGN ALARM ALARM ALARM EVENTS RELAYS TEMPERATURE TRIP TRIP VOTING ASSIGN TRIP TRIP RELAYS TEMPERATURE A-16 489 Generator Management Relay GE Power Management...
Page 271 OPEN RTD SENSOR Open RTD Sensor Alarm Assign Alarm Relays ---5 Open RTD Sensor Alarm Events APPLICATION NAME ALARM ASSIGN ALARM ALARM ALARM EVENTS RELAYS TEMPERATURE TRIP TRIP VOTING ASSIGN TRIP TRIP RELAYS TEMPERATURE GE Power Management 489 Generator Management Relay A-17...
Page 272 Time to Trip at 6.00 × FLA 65535 ms Time to Trip at 6.50 × FLA 65535 ms Time to Trip at 7.00 × FLA 65535 ms Time to Trip at 7.50 × FLA 65535 ms A-18 489 Generator Management Relay GE Power Management...
Page 273 5.00 × FLA Accel. Intersect @ 100% Voltage THERMAL ELEMENTS Thermal Model Alarm Assign Alarm Relays ---5 Thermal Alarm Level 75% Used Thermal Model Alarm Events Thermal Model Trip Assign Trip Relays 1--- GE Power Management 489 Generator Management Relay A-19...
Page 274 Generator Running Hours Limit 1000 hrs Current Demand Alarm Events MW DEMAND MW Demand Period 15 min. MW Demand Alarm Assign Alarm Relays ---5 1.25 × Rated MW Demand Limit MW Demand Alarm Events A-20 489 Generator Management Relay GE Power Management...
Page 275 ANALOG INPUT 4 Setup Name Units Minimum Maximum Block From Online Alarm Assign Alarm Relays Alarm Level Alarm Pickup Alarm Delay Alarm Events Trip Assign Trip Relays Trip Level Trip Pickup Trip Delay GE Power Management 489 Generator Management Relay A-21...
Page 276 A.1 COMMISSIONING APPENDIX A A-22 489 Generator Management Relay GE Power Management...
Page 277: Neutral Overvoltage Element
5% of the stator. The fault detection methods depend on the grounding arrangement, the availability of core bal- ance CT, and the size of the unit. With modern full-featured digital generator protection relays such as the 489, users do not incur additional costs for extra protection elements as they are all part of the same device.
Page 278 Aux. Contact Aux. Isolating Contact Trans. Relay neutral Breaker Grounding Switch Aux. Aux. Contact Contact Relay neutral Other Generators, as the case may be PARGEN1R2.CDR Figure B–2: PARALLEL GENERATORS WITH COMMON GROUNDING IMPEDANCE 489 Generator Management Relay GE Power Management...
Page 279: Ground Overcurrent Element
Breaker (similar to Aux. Option 4) Option 1 Option 4 Ground Ground current input Overcurrent from one of the five options Element GNDCUR1R2.CDR Figure B–3: GROUND OVERCURRENT ELEMENT WITH DIFFERENT CURRENT SOURCE SIGNALS GE Power Management 489 Generator Management Relay...
Page 280: B.1.4 Ground Directional Element
B.1 STATOR GROUND FAULT PROTECTION APPENDIX B B.1.4 GROUND DIRECTIONAL ELEMENT The 489 can detect internal stator ground faults using a Ground Directional element implemented using the V and the neutral ground current inputs. The voltage signal is obtained across the grounding impedance of the generator. The ground, or...
Page 281 In-service (but will not In-service In-service grounded operate due to lack of LO) Loaded and Closed Closed In-service In-service In-service Grounded Loaded and Not Closed Open In service as a simple Out-of-service In-service Grounded overcurrent element GE Power Management 489 Generator Management Relay...
Page 282: Third Harmonic Voltage Element
[4]. In the 489 relay, the third-harmonic voltage element, Neutral Undervoltage (3rd Harmonic) derives the third harmonic com- ponent of the neutral-point voltage signal from the V signal as one signal, called V .
Page 283: Time Overcurrent Curves
C.1 TIME OVERCURRENT CURVES APPENDIX C CURVESC.1 TIME OVERCURRENT CURVES C.1.1 ANSI CURVES 489 ANSI MODERATELY INVERSE GE Power Management 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 808802A3.CDR CURRENT (I/Ipu) Figure C–1: ANSI MODERATELY INVERSE CURVE GE Power Management 489 Generator Management Relay...
Page 284 C.1 TIME OVERCURRENT CURVES APPENDIX C 489 ANSI NORMALLY INVERSE GE Power Management 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 CURRENT (I/Ipu) 808801A3.CDR Figure C–2: ANSI NORMALLY INVERSE CURVE 489 Generator Management Relay GE Power Management...
Page 285 APPENDIX C C.1 TIME OVERCURRENT CURVES 489 ANSI GE Power Management VERY INVERSE 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 808800A3.DWG CURRENT (I/Ipu) Figure C–3: ANSI VERY INVERSE CURVE GE Power Management 489 Generator Management Relay...
Page 286 C.1 TIME OVERCURRENT CURVES APPENDIX C 489 ANSI GE Power Management EXTREME INVERSE 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 808799A3.CDR CURRENT (I/Ipu) Figure C–4: ANSI EXTREMEMLY INVERSE CURVE 489 Generator Management Relay GE Power Management...
Page 287 APPENDIX C C.1 TIME OVERCURRENT CURVES C.1.2 DEFINITE TIME CURVE GE Power Management DEFINITE TIME 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 808798A3.CDR CURRENT (I/Ipu) Figure C–5: DEFINITE TIME CURVE GE Power Management 489 Generator Management Relay...
Page 288: Iac Curves
C.1 TIME OVERCURRENT CURVES APPENDIX C C.1.3 IAC CURVES 489 IAC GE Power Management SHORT INVERSE 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 CURRENT (I/Ipu) 808811A3.CDR Figure C–6: IAC SHORT INVERSE CURVE 489 Generator Management Relay GE Power Management...
Page 289 APPENDIX C C.1 TIME OVERCURRENT CURVES 489 IAC GE Power Management INVERSE 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 CURRENT (I/Ipu) 808810A3.CDR Figure C–7: IAC INVERSE CURVE GE Power Management 489 Generator Management Relay...
Page 290 C.1 TIME OVERCURRENT CURVES APPENDIX C 489 IAC GE Power Management VERY INVERSE 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 808807A2.CDR CURRENT (I/Ipu) Figure C–8: IAC VERY INVERSE CURVE 489 Generator Management Relay GE Power Management...
Page 291 APPENDIX C C.1 TIME OVERCURRENT CURVES 489 IAC GE Power Management EXTREME INVERSE 1000 MULTIPLIER 30.0 20.0 15.0 10.0 0.01 808806A3.CDR CURRENT (I/Ipu) Figure C–9: IAC EXTREME INVERSE CURVE GE Power Management 489 Generator Management Relay...
Page 292: Iec Curves
C.1.4 IEC CURVES 489 IEC GE Power Management CURVE A (BS142) 1000 MULTIPLIER 1.00 0.80 0.60 0.50 0.40 0.30 0.20 0.15 0.10 0.05 0.01 CURRENT (I/Ipu) 808803A3.CDR Figure C–10: IEC CURVE A (BS142) C-10 489 Generator Management Relay GE Power Management...
Page 293 C.1 TIME OVERCURRENT CURVES 489 IEC GE Power Management CURVE B (BS142) 1000 MULTIPLIER 1.00 0.80 0.60 0.50 0.40 0.30 0.20 0.15 0.10 0.05 0.01 CURRENT (I/Ipu) 808804A3.CDR Figure C–11: IEC CURVE B (BS142) GE Power Management 489 Generator Management Relay C-11...
Page 294 APPENDIX C 489 IEC GE Power Management CURVE C (BS142) 1000 MULTIPLIER 1.00 0.80 0.60 0.50 0.40 0.30 0.20 0.15 0.10 0.05 0.01 808805A3.CDR CURRENT (I/Ipu) Figure C–12: IEC CURVE C (BS142) C-12 489 Generator Management Relay GE Power Management...
Page 295: Cts D.1 Current Transformers
D.1.1 GROUND FAULT CTs FOR 50:0.025 A CT CTs that are specially designed to match the ground fault input of GE Power Management motor protection relays should be used to ensure correct performance. These CTs have a 50:0.025A (2000:1 ratio) and can sense low leakage currents over the relay setting range with minimum error.
Page 296: Ground Fault Cts For 5 A Secondary Ct
For low resistance or solidly grounded systems, a 5 A secondary CT should be used. Two sizes are available with 5½” or 13” × 16” windows. Various Primary amp CTs can be chosen (50 to 250). GCT5 GCT16 DIMENSIONS DIMENSIONS 489 Generator Management Relay GE Power Management...
Page 297: Phase Cts
Current transformers in most common ratios from 50:5 to 1000:5 are available for use as phase current inputs with motor protection relays. These come with mounting hardware and are also available with 1 A secondaries. Voltage class: 600 V BIL, 10 KV. GE Power Management 489 Generator Management Relay...
Page 298 D.1 CURRENT TRANSFORMERS APPENDIX D 489 Generator Management Relay GE Power Management...
Page 299: Warranty Information
24 months from date of shipment from factory. In the event of a failure covered by warranty, GE Power Management will undertake to repair or replace the relay providing the warrantor determined that it is defective and it is returned with all transportation charges prepaid to an authorized service centre or the factory.
Page 300 E.1 WARRANTY INFORMATION APPENDIX E 489 Generator Management Relay GE Power Management...
Page 301: Appendix F F.1 Figures And Tables
2–14: LOOP POWERED TRANSDUCER CONNECTION ....................2-11 IGURE 2–15: RTD WIRING ................................2-12 IGURE 2–16: RS485 COMMUNICATIONS INTERFACE ......................... 2-14 IGURE 2–17: TESTING THE 489 FOR DIELECTRIC STRENGTH ....................2-15 IGURE 3–1: 489 FACEPLATE................................3-1 IGURE 3–2: 489 DISPLAY.................................. 3-2 IGURE 3–3: 489 LED INDICATORS..............................
Page 302: List Of Tables
: 7–4 ANALOG INPUT/OUTPUT TEST, 0 A INPUT ....................... 7-8 ABLE : 7–5 OUTPUT RELAYS................................7-8 ABLE : A–1 SETPOINTS PAGE 1 – 489 SETUP ..........................A-1 ABLE : A–2 SETPOINTS PAGE 2 – SYSTEM SETUP ........................A-1 ABLE : A–3 SETPOINTS PAGE 3 – DIGITAL INPUTS........................A-2 ABLE : A–4 SETPOINTS PAGE 4 –...
Page 303 ............6-49, 6-51, 6-52 point lists data rate ................6-1 ................4-4 setpoints error responses ..............6-8 DRAWOUT INDICATOR ............ 2-13 ..............4-76 monitoring ............... 6-10 passcode DUAL SETPOINTS ........... 4-2, 4-12, 6-10 ................4-4 setpoints GE Power Management 489 Generator Management Relay...
Page 304 Mvarh METERING ..........4-7, 4-12, 5-14 analog ..............1-4, 2-11 current ............. 1-4, 2-9, 2-10 MW DEMAND ............4-67, 5-16 ..............1-4, 2-11 digital MWh METERING ..........4-7, 4-12, 5-14 ................1-5 general ................ 1-4, 2-12 489 Generator Management Relay GE Power Management...
Page 305 ..............2-13 R3 AUXILIARY RELAY RESET MODE ............4-16 ..............2-13 R4 ALARM REMOTE RESET .............. 4-12 R6 SERVICE ..............2-13 RESETTING THE 489 ............4-16 setpoints ................ 4-16 RESIDUAL GROUND CONNECTION ......... 2-10 specifications ..............1-5 ................7-8 testing REVERSE POWER ............
Page 306 WIRING DIAGRAM ............2-8 ..............1-7 specifications WITHDRAWAL ..............2-3 ..............4-61 unbalance bias WYE ................2-11 THERMAL RESET ............4-12 WYE CONNECTED VTs ............4-37 THIRD HARMONIC VOLTAGE ........... B-6 TIME ................ 4-5, 5-11 489 Generator Management Relay GE Power Management...

GE 489 Instruction Manual

1 Introduction

2 Installation

3 Operation

4 Setpoint Programming

5 Actual Values

6 Communications

7 Testing

8 Pc Software

Time Overcurrent Curves

Cts D.1 CURRENT TRANSFORMERS

Warranty Information

Appendix F F.1 Figures and Tables

Quick Links

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Summary of Contents for GE 489