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GE Power Management
215 Anderson Avenue, Markham, Ontario,
Canada L6E 1B3
Tel: (905) 294-6222, 1-800-547-8629 (North America)
4. USER INTERFACES 4.1 FACEPLATE INTERFACE4.1.1 DISPLAY.............................................................................................................4-14.1.2 LED INDICATORS..............................................................................................4-14.1.3 RS232 PROGRAM PORT ..................................................................................4-14.1.4 KEYPAD .............................................................................................................4-24.1.5 SETPOINT ENTRY.............................................................................................4-2
4.2 369PC INTERFACE4.2.1 HARDWARE & SOFTWARE REQUIREMENTS ................................................4-34.2.2 INSTALLING 369PC...........................................................................................4-34.2.3 UPGRADING 369PC ..........................................................................................4-34.2.4 CONFIGURATION..............................................................................................4-44.2.5 UPGRADING RELAY FIRMWARE.....................................................................4-44.2.6 CREATING A NEW SETPOINT FILE.................................................................4-54.2.7 EDITING A SETPOINT FILE ..............................................................................4-64.2.8 DOWNLOADING A SETPOINT FILE TO THE 369 ............................................4-64.2.9 UPGRADING SETPOINT FILE TO NEW REVISION.........................................4-74.2.10 CONVERTING 269 SETPOINT FILES TO 369..................................................4-84.2.11 PRINTING...........................................................................................................4-84.2.12 TRENDING .........................................................................................................4-94.2.13 WAVEFORM CAPTURE ..................................................................................4-104.2.14 PHASORS ........................................................................................................4-114.2.15 EVENT RECORDING.......................................................................................4-124.2.16 TROUBLESHOOTING......................................................................................4-12
5. SETPOINTS 5.1 OVERVIEW5.1.1 SETPOINTS MAIN MENU..................................................................................5-1
a STANDARD OVERLOAD CURVE:.......................................................... 5-24b CUSTOM OVERLOAD CURVE: .............................................................. 5-27
5.9 S8 POWER ELEMENTS5.9.1 SETPOINTS PAGE 8 MENU ........................................................................... 5-505.9.2 LEAD POWER FACTOR ................................................................................. 5-515.9.3 LAG POWER FACTOR.................................................................................... 5-515.9.4 POSITIVE REACTIVE POWER ....................................................................... 5-525.9.5 NEGATIVE REACTIVE POWER ..................................................................... 5-535.9.6 UNDERPOWER............................................................................................... 5-535.9.7 REVERSE POWER ......................................................................................... 5-54
a GENERAL................................................................................................ 5-57b DIGITAL COUNTER ................................................................................ 5-57c WAVEFORM CAPTURE.......................................................................... 5-58d SIMULATE PRE-FAULT.......................................................................... 5-58e SIMULATE FAULT................................................................................... 5-58f SIMULATE PRE-FAULT to FAULT.......................................................... 5-58
5.11 S10 ANALOG OUTPUTS5.11.1 SETPOINTS PAGE 10 MENU ......................................................................... 5-595.11.2 ANALOG OUTPUTS ........................................................................................ 5-595.11.3 ANALOG OUTPUT PARAMETER SELECTION.............................................. 5-60
5.12 S11 369 TESTING5.12.1 SETPOINTS PAGE 11 MENU ......................................................................... 5-615.12.2 SIMULATION MODE ....................................................................................... 5-615.12.3 PRE-FAULT SETUP ........................................................................................ 5-625.12.4 FAULT SETUP................................................................................................. 5-635.12.5 POST- FAULT SETUP..................................................................................... 5-645.12.6 TEST OUTPUT RELAYS ................................................................................. 5-655.12.7 TEST ANALOG OUTPUTS.............................................................................. 5-65
6. ACTUAL VALUES 6.1 OVERVIEW6.1.1 ACTUAL VALUES MAIN MENU.........................................................................6-1
6.2 A1 STATUS6.2.1 ACTUAL VALUES PAGE 1 MENU.....................................................................6-36.2.2 MOTOR STATUS ...............................................................................................6-36.2.3 LAST TRIP DATA ...............................................................................................6-46.2.4 ALARM STATUS ................................................................................................6-46.2.5 START INHIBIT STATUS ...................................................................................6-56.2.6 DIGITAL INPUT STATUS...................................................................................6-56.2.7 OUTPUT RELAY STATUS .................................................................................6-66.2.8 REAL TIME CLOCK ...........................................................................................6-6
6.3 A2 METERING DATA6.3.1 ACTUAL VALUES PAGE 2 MENU.....................................................................6-76.3.2 CURRENT METERING ......................................................................................6-76.3.3 VOLTAGE METERING.......................................................................................6-86.3.4 POWER METERING ..........................................................................................6-86.3.5 BACKSPIN METERING......................................................................................6-96.3.6 LOCAL RTD........................................................................................................6-96.3.7 REMOTE RTD ..................................................................................................6-106.3.8 DEMAND METERING ......................................................................................6-116.3.9 PHASORS ........................................................................................................6-11
6.4 A3 LEARNED DATA6.4.1 ACTUAL VALUES PAGE 3 MENU...................................................................6-136.4.2 MOTOR DATA..................................................................................................6-136.4.3 LOCAL RTD MAXIMUMS.................................................................................6-146.4.4 REMOTE RTD MAXIMUMS .............................................................................6-15
6.5 A4 STATISTICAL DATA6.5.1 ACTUAL VALUES PAGE 4 MENU...................................................................6-166.5.2 TRIP COUNTERS ............................................................................................6-166.5.3 MOTOR STATISTICS.......................................................................................6-17
6.7 A6 RELAY INFORMATION6.7.1 ACTUAL VALUES PAGE 6 MENU...................................................................6-196.7.2 MODEL INFORMATION...................................................................................6-196.7.3 FIRMWARE VERSION .....................................................................................6-19
7. APPLICATIONS 7.1 269-369 COMPARISON7.1.1 369 AND 269PLUS COMPARISON ...................................................................7-1
7.6 APPLICATIONS7.6.1 MOTOR STATUS DETECTION........................................................................7-137.6.2 SELECTION OF COOL TIME CONSTANTS....................................................7-147.6.3 THERMAL MODEL...........................................................................................7-15
7.6.4 RTD BIAS FEATURE....................................................................................... 7-167.6.5 THERMAL CAPACITY USED CALCULATION................................................ 7-177.6.6 START INHIBIT................................................................................................ 7-187.6.7 2φ CT CONFIGURATION ................................................................................ 7-207.6.8 GROUND FAULT DETECTION ON UNGROUNDED SYSTEMS ................... 7-217.6.9 RTD CIRCUITRY ............................................................................................. 7-227.6.10 REDUCED RTD LEAD NUMBER APPLICATION ........................................... 7-237.6.11 TWO WIRE RTD LEAD COMPENSATION ..................................................... 7-247.6.12 AUTO TRANSFORMER STARTER WIRING .................................................. 7-24
8. TESTING 8.1 TEST SETUP8.1.1 INTRODUCTION................................................................................................ 8-18.1.2 SECONDARY INJECTION TEST SETUP ......................................................... 8-1
8.2 HARDWARE FUNCTIONAL TESTING8.2.1 PHASE CURRENT ACCURACY TEST ............................................................. 8-28.2.2 VOLTAGE INPUT ACCURACY TEST ............................................................... 8-28.2.3 GROUND (1A/5A) ACCURACY TEST............................................................... 8-38.2.4 50:0.025 GROUND ACCURACY TEST............................................................. 8-38.2.5 RTD ACCURACY TEST .................................................................................... 8-48.2.6 DIGITAL INPUTS AND TRIP COIL SUPERVISION .......................................... 8-58.2.7 ANALOG INPUTS AND OUTPUTS ................................................................... 8-58.2.8 OUTPUT RELAYS ............................................................................................. 8-6
8.3 ADDITIONAL FUNCTIONAL TESTING8.3.1 OVERLOAD CURVE TEST ............................................................................... 8-78.3.2 POWER MEASUREMENT TEST ...................................................................... 8-78.3.3 VOLTAGE PHASE REVERSAL TEST............................................................... 8-88.3.4 SHORT CIRCUIT TEST..................................................................................... 8-8
A. REVISIONS A.1 CHANGE NOTESA.1.1 REVISION HISTORY .............................................................A-1A.1.2 MAJOR UPDATES FOR 369-BC ...........................................A-1A.1.3 MAJOR UPDATES FOR 369-BB ...........................................A-1A.1.4 MAJOR UPDATES FOR 369-BA ...........................................A-1A.1.5 MAJOR UPDATES FOR 369-B9............................................A-2A.1.6 MAJOR UPDATES FOR 369-B8............................................A-2A.1.7 MAJOR UPDATES FOR 369-B7............................................A-2
GE Power Management 369 Motor Management Relay 1-1
1 INTRODUCTION 1.1 ORDERING
11 INTRODUCTION 1.1 ORDERING 1.1.1 GENERAL OVERVIEW
The 369 Motor Management Relay is a digital relay that provides protection and monitoring for three phase motors andtheir associated mechanical systems. A unique feature of the 369 is its ability to ‘learn’ individual motor parameters and toadapt itself to each application. Values such as motor inrush current, cooling rates and acceleration time may be used toimprove the 369’s protective capabilities.
The 369 offers optimum motor protection where other relays cannot, by using the FlexCurve™ custom overload curve, orone of the fifteen standard curves.
The 369 has one RS232 front panel port and three RS485 rear ports. The Modbus RTU protocol is standard to all ports.Setpoints can be entered via the front keypad or by using the 369PC software and a computer. Status, actual values andtroubleshooting information are also available via the front panel display or via communications. A simulation mode andpickup indicator allow testing and verification of correct operation without requiring a relay test set.
As an option, the 369 can individually monitor up to 12 RTDs. These can be from the stator, bearings, ambient or drivenequipment. The type of RTD used is software selectable. Optionally available as an accessory is the remote RTD modulewhich can be linked to the 369 via a fibre optic or RS485 connection.
The optional metering package provides VT inputs for voltage and power elements. It also provides metering of V, kW, kvar,kVA, PF, Hz, and MWhrs. Three additional user configurable analog outputs are included with this option along with oneanalog output included as part of the base unit.
The Back-Spin Detection (B) option enables the 369 to detect the flow reversal of a pump motor and enable timely and safemotor restarting. 369 options are available when ordering the relay or as upgrades to the relay in the field. Field upgradesare via an option enabling passcode available from GE Power Management, which is unique to each relay and option.
1.1.2 ORDERING
Select the basic model and the desired features from the selection guide below:
Notes: One Analog Output is now available with the 369 base model. The other three Analog Outputs canbe obtained by purchasing the metering or backspin options.The control power (HI or LO) must be specified with all orders. If a feature is not required, a 0 must beplaced in the order code. All order codes have 9 digits. The 369 is available in a non-drawout version only.
Examples: 369-HI-R-0-0-0 369 with HI voltage control power and 12 RTD inputs369-LO-0-M-0-0 369 relay with LO voltage control power and metering option
Location: GE Power Management215 Anderson AvenueMarkham, OntarioCanada L6E 1B3Tel: (905) 294-6222, 1-800-547-8629 (North America)Fax: (905) 201-2098Web Page: http://www.GEindustrial.com/pm; e-mail: [email protected]
369 S S S S S
369 | | | | | Base unit (no RTD)
HI | | | | 50-300 VDC / 40-265 VAC control power
LO | | | | 20-60 VDC / 20-48 VAC control power
R | | | Optional 12 RTD inputs (built-in)
0 | | | No optional RTD inputs
M | | Optional metering package
B | | Optional backspin detection (incl. metering)
1-2 369 Motor Management Relay GE Power Management
1.1 ORDERING 1 INTRODUCTION
11.1.3 ACCESSORIES
369PC software: Setup and monitoring software provided free with each relay.
RRTD: Remote RTD Module. Connects to the 369 via a fibre optic or RS485 connection. Allows remote meter-ing and programming for up to 12 RTDs. Complete with connecting fiber optic cable.
F485: Converts communications between RS232 and RS485 / fibre optic. Used to interface a computer tothe relay.
1-4 369 Motor Management Relay GE Power Management
1.1 ORDERING 1 INTRODUCTION
11.1.7 RELAY LABEL DEFINITION
1. The 369 order code at the time of leaving the factory.
2. The serial number of the 369.
3. The firmware installed in the 369 at the factory. Note that this may no longer be the currently installed firmware as itmay upgraded in the field. The current firmware revision may be checked in the Actual Values section of the 369.
4. Specifications for the output relay contacts.
5. Certifications the 369 conforms with or has been approved to.
6. Factory installed options. These are based on the order code. Note that the 369 may have had options upgraded in thefield. The Actual Values section of the 369 may be checked to verify this.
7. Control power ratings for the 369 as ordered. Based on the HI/LO rating from the order code.
8. Pollution degree.
9. Overvoltage Category.
10. IP code.
11. Modification number for any factory ordered mods. Note that the 369 may have had modifications added in the field.The Actual Values section of the 369 may be checked to verify this.
• ability to learn, display and integrate critical parame-ters to maximize motor protection
• a keypad with 40 character display
• flash memory
The relay shall be capable of displaying important metering functions, including phase voltages, kilowatts, kvars, power fac-tor, frequency and MWhr. In addition, undervoltage and low power factor alarm and trip levels shall be field programmable.The communications interface shall include one front RS232 port and three independent rear RS485 ports with supportingPC software, thus allowing easy setpoint programming, local retrieval of information and flexibility in communication withSCADA and engineering workstations.
AMBIENT TEMPERATUREOperating Range: –40°C to +60°CStorage Range: –40°C to +80°C
NOTE: For 369 units with the Profibus option, the Operating andStorage ranges are as follows:
Operating Range: +5°C to +60°C
Storage Range: +5°C to +80°C
HUMIDITYUp to 95% non condensing
DUST/MOISTUREIP50
VENTILATION
No special ventilation required as long as ambient temperatureremains within specifications. Ventilation may be required in enclo-sures exposed to direct sunlight.
OVERVOLTAGE CATEGORY II
CLEANINGMay be cleaned with a damp cloth.
The 369 must be powered up at least once per year to prevent deterioration of electrolytic capacitors.
2.2.9 APPROVALS / CERTIFICATION
ISO: Designed and manufactured to an ISO9001 registered process.
CSA: CSA approved
UL: UL recognized
CE: Conforms to EN 55011/CISPR 11, EN50082-2, IEC 947-1, 1010-1
The 369 is contained in a compact plastic housing with the keypad, display, communication port, and indicators/targets onthe front panel. The unit should be positioned so the display and keypad are accessible. To mount the relay, make cutoutand drill mounting holes as shown below. Mounting hardware (bolts and washers) is provided with the relay. Although therelay is internally shielded to minimize noise pickup and interference, it should be mounted away from high current conduc-tors or sources of strong magnetic fields.
GE Power Management 369 Motor Management Relay 3-7
3 INSTALLATION 3.3 ELECTRICAL INSTALLATION
3
3.3.2 TYPICAL WIRING
The 369 can be connected to cover a broad range of applications and wiring will vary depending upon the user’s protectionscheme. This section will cover most of the typical 369 interconnections.
In this section, the terminals have been logically grouped together for explanatory purposes. A typical wiring diagram forthe 369 is shown above in Figure 3–4: TYPICAL WIRING on page 3–6 and the terminal arrangement has been detailed inFigure 3–3: TERMINAL LAYOUT on page 3–5. For further information on applications not covered here, refer to Chapter 7:APPLICATIONS or contact the factory for further information.
Hazard may result if the product is not used for intended purposes. This equipment can only be servicedby trained personnel.
3.3.3 CONTROL POWER
VERIFY THAT THE CONTROL POWER SUPPLIED TO THE RELAY IS WITHIN THE RANGE COVERED BYTHE ORDERED 369 RELAY’S CONTROL POWER.
The 369 has a built-in switchmode supply. It can operate with either AC or DC voltage applied to it.
Extensive filtering and transient protection has been incorporated into the 369 to ensure reliable operation in harsh indus-trial environments. Transient energy is removed from the relay and conducted to ground via the ground terminal. This termi-nal must be connected to the cubicle ground bus using a 10 AWG wire or a ground braid. Do not daisy-chain grounds withother relays or devices. Each should have its own connection to the ground bus.
The internal supply is protected via a 3.15 A slo-blo fuse that is accessible for replacement. If it must be replaced ensurethat it is replaced with a fuse of equal size (see FUSE on page 2–4).
3.3.4 PHASE CURRENT (CT) INPUTS
The 369 requires one CT for each of the three motor phase currents to be input into the relay. There are no internal groundconnections for the CT inputs. Refer to Chapter 7: APPLICATIONS for a information on two CT connections.
The phase CTs should be chosen such that the FLA of the motor being protected is no less than 50% of the rated CT pri-mary. Ideally, to ensure maximum accuracy and resolution, the CTs should be chosen such that the FLA is 100% of CT pri-mary or slightly less. The maximum CT primary is 5000 A.
The 369 will measure 0.05 to 20 × CT primary rated current. The CTs chosen must be capable of driving the 369 burden(see specifications) during normal and fault conditions to ensure correct operation. See Section 7.4: CT SPECIFICATIONAND SELECTION on page 7–7 for information on calculating total burden and CT rating.
For the correct operation of many protective elements, the phase sequence and CT polarity is critical. Ensure that the con-vention illustrated in Figure 3–4: TYPICAL WIRING on page 3–6 is followed.
3-8 369 Motor Management Relay GE Power Management
3.3 ELECTRICAL INSTALLATION 3 INSTALLATION
3
3.3.5 GROUND CURRENT INPUTS
The 369 has an isolating transformer with separate 1 A, 5 A, and sensitive HGF (50:0.025) ground terminals. Only oneground terminal type can be used at a time. There are no internal ground connections on the ground current inputs.
The maximum ground CT primary for the 1 A and 5 A taps is 5000 A. Alternatively the sensitive ground input, 50:0.025, canbe used to detect ground current on high resistance grounded systems.
The ground CT connection can either be a zero sequence (core balance) installation or a residual connection. Note thatonly 1 A and 5 A secondary CTs may be used for the residual connection. A typical residual connection is illustrated inbelow. The zero-sequence connection is shown in the typical wiring diagram. The zero-sequence connection is recom-mended. Unequal saturation of CTs, CT mismatch, size and location of motor, resistance of the power system, motor coresaturation density, etc. may cause false readings in the residually connected ground fault circuit.
Figure 3–5: TYPICAL RESIDUAL CONNECTION
3.3.6 ZERO SEQUENCE GROUND CT PLACEMENT
The exact placement of a zero sequence CT to properly detect ground fault current is shown below. If the CT is placed overa shielded cable, capacitive coupling of phase current into the cable shield during motor starts may be detected as groundcurrent unless the shield wire is also passed through the CT window. Twisted pair cabling on the zero sequence CT is rec-ommended.
GE Power Management 369 Motor Management Relay 3-9
3 INSTALLATION 3.3 ELECTRICAL INSTALLATION
3
3.3.7 PHASE VOLTAGE (VT/PT) INPUTS
The 369 has three channels for AC voltage inputs each with an internal isolating transformer. There are no internal fuses orground connections on these inputs. The maximum VT ratio is 240:1. These inputs are only enabled when the meteringoption (M) is ordered.
The 369 accepts either open delta or wye connected VTs (see Figure 3–7: WYE/DELTA CONNECTION below). The volt-age channels are connected wye internally, which means that the jumper shown on the delta connection between thephase B input and the VT neutral terminals must be installed.
Polarity and phase sequence for the VTs is critical for correct power and rotation measurement and should be verifiedbefore starting the motor. As long as the polarity markings on the primary and secondary windings of the VT are aligned,there is no phase shift. The markings can be aligned on either side of the VT. VTs are typically mounted upstream of themotor breaker or contactor. Typically, a 1 A fuse is used to protect the voltage inputs.
Figure 3–7: WYE/DELTA CONNECTION
3.3.8 BACKSPIN VOLTAGE INPUTS
The Backspin voltage input is only operational if the optional backspin detection (B) feature has been purchased for therelay. This input allows the 369 to sense whether the motor is spinning after the primary power has been removed (breakeror contactor opened).
These inputs must be supplied by a separate VT mounted downstream (motor side) of the breaker or contactor. The correctwiring is illustrated below.
3-10 369 Motor Management Relay GE Power Management
3.3 ELECTRICAL INSTALLATION 3 INSTALLATION
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3.3.9 RTD INPUTS
The 369 can monitor up to 12 RTD inputs for Stator, Bearing, Ambient, or Other temperature applications. The type of eachRTD is field programmable as: 100 Ω Platinum (DIN 43760), 100 Ω Nickel, 120 Ω Nickel, or 10 Ω Copper. RTDs must bethe three wire type. There are no provisions for the connection of thermistors.
The 369 RTD circuitry compensates for lead resistance, provided that each of the three leads is the same length. Leadresistance should not exceed 25 Ω per lead for platinum and nickel type RTDs or 3 Ω per lead for Copper type RTDs.
Shielded cable should be used to prevent noise pickup in industrial environments. RTD cables should be kept close togrounded metal casings and avoid areas of high electromagnetic or radio interference. RTD leads should not be run adja-cent to or in the same conduit as high current carrying wires.
The shield connection terminal of the RTD is grounded in the 369 and should not be connected to ground at the motor oranywhere else to prevent noise pickup from circulating currents.
If 10 Ω Copper RTDs are used special care should be taken to keep the lead resistance as low as possible to maintainaccurate readings.
Figure 3–9: RTD INPUTS
3.3.10 DIGITAL INPUTS
DO NOT CONNECT LIVE CIRCUITS TO THE 369 DIGITAL INPUTS. THEY ARE DESIGNED FOR DRY CON-TACT CONNECTIONS ONLY.
Other than the ACCESS switch input the other 5 digital inputs are programmable. These programmable digital inputs havedefault settings to match the functions of the 269Plus switch inputs (differential, speed, emergency restart, remote resetand spare). However in addition to their default settings they can also be programmed for use as generic inputs to set uptrips and alarms or for monitoring purposes based on external contact inputs.
A twisted pair of wires should be used for digital input connections.
GE Power Management 369 Motor Management Relay 3-11
3 INSTALLATION 3.3 ELECTRICAL INSTALLATION
3
3.3.11 ANALOG OUTPUTS
The 369 provides 1 analog current output channel as part of the base unit and 3 additional analog outputs with the meteringoption (M). These outputs are field programmable to a full-scale range of either 0 to 1 mA (into a maximum 2.4 kΩ imped-ance) and 4 to 20 mA or 0 to 20 mA (into a maximum 600 Ω impedance).
As shown in the typical wiring diagram (Figure 3–4: TYPICAL WIRING on page 3–6), these outputs share one commonreturn. Polarity of these outputs must be observed for proper operation.
Shielded cable should be used for connections, with only one end of the shield grounded, to minimize noise effects. Theanalog output circuitry is isolated. Transorbs limit this isolation to ±36 V with respect to the 369 safety ground.
If an analog voltage output is required, a burden resistor must be connected across the input of the SCADA or measuringdevice (see the figure below). Ignoring the input impedance of the input,
For 0-1 mA, for example, if 5 V full scale is required to correspond to 1 mA
For 4-20 mA, this resistor would be
Figure 3–10: ANALOG OUTPUT VOLTAGE CONNECTION
3.3.12 REMOTE DISPLAY
The 369 display can be separated and mounted remotely up to 15 feet away from the main relay. No separate source ofcontrol power is required for the display module. A 15 feet standard shielded network cable is used to make the connectionbetween the display module and the main relay. A recommended and tested cable is available from GE Power Manage-ment. The cable should be wired as far away as possible from high current or voltage carrying cables or other sources ofelectrical noise.
In addition the display module must be grounded if mounted remotely. A ground screw is provided on the back of the dis-play module to facilitate this. A 12 AWG wire is recommended and should be connected to the same ground bus as themain relay unit.
The 369 relay will still function and protect the motor without the display connected.
3-12 369 Motor Management Relay GE Power Management
3.3 ELECTRICAL INSTALLATION 3 INSTALLATION
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3.3.13 OUTPUT RELAYS
The 369 provides four (4) form C output relays. They are labeled Trip, Aux 1, Aux 2, and Alarm. Each relay has normallyopen (NO) and normally closed (NC) contacts and can switch up to 8 A at either 250 V AC or 30 V DC with a resistive load.The NO or NC state is determined by the ‘no power’ state of the relay outputs.
All four output relays may be programmed for fail-safe or non-fail-safe operation. When in fail-safe mode, output relay acti-vation or a loss of control power will cause the contacts to go to their power down state.
For example:
• A fail-safe NO contact closes when the 369 is powered up (if no prior unreset trip conditions) and will open when acti-vated (tripped) or when the 369 loses control power.
• A non-fail-safe NO contact remains open when the 369 is powered up (unless a prior unreset trip condition) and willclose only when activated (tripped). If control power is lost while the output relay is activated (NO contacts closed) theNO contacts will open.
Thus, in order to cause a trip on loss of control power to the 369, the Trip relay should be programmed as fail-safe. See thefigure below for typical wiring of contactors and breakers for fail-safe and non-fail-safe operation. Output relays remainlatched after activation if the fault condition persists or the protection element has been programmed as latched. Thismeans that once this relay has been activated it remains in the active state until the 369 is manually reset.
The Trip relay cannot be reset if a timed lockout is in effect. Lockout time will be adhered to regardless of whether controlpower is present or not. The relay contacts may be reset if motor conditions allow, by pressing the RESET key, using theREMOTE RESET switch or via communications. The Emergency Restart feature overrides all features to reset the 369.
The rear of the 369 relay shows output relay contacts in their power down state.
In locations where system voltage disturbances cause voltage levels to dip below the control powerrange listed in specifications, any relay contact programmed as fail-safe may change state. Therefore, inany application where the ‘process’ is more critical than the motor, it is recommended that the trip relaycontacts be programmed as non-fail-safe. If, however, the motor is more critical than the ‘process’ thenprogram the trip contacts as fail-safe.
GE Power Management 369 Motor Management Relay 3-13
3 INSTALLATION 3.3 ELECTRICAL INSTALLATION
3
3.3.14 RS485 COMMUNICATIONS
Three independent two-wire RS485 ports are provided. If option (F), the fiber optic port, is installed and used the COMM 3,RS485 port, may not be used. The RS485 ports are isolated as a group.
Up to 32 369s (or other devices) can be daisy-chained together on a single serial communication channel without exceed-ing the driver capability. For larger systems, additional serial channels must be added. Commercially available repeatersmay also be used to increase the number of relays on a single channel to a maximum of 254. Note that there may only beone master device per serial communication link.
Connections should be made using shielded twisted pair cables (typically 24 AWG). Suitable cables should have a charac-teristic impedance of 120 Ω (e.g. Belden #9841) and total wire length should not exceed 4000 ft. Commercially availablerepeaters can be used to extend transmission distances.
Voltage differences between remote ends of the communication link are not uncommon. For this reason, surge protectiondevices are internally installed across all RS485 terminals. Internally, an isolated power supply with an optocoupled datainterface is used to prevent noise coupling. The source computer/PLC/SCADA system should have similar transient protec-tion devices installed, either internally or externally, to ensure maximum reliability.
To ensure that all devices in a daisy-chain are at the same potential, it is imperative that the common ter-minals of each RS485 port are tied together and grounded in one location only, at the master. Failure todo so may result in intermittent or failed communications.
Correct polarity is also essential. 369 relays must be wired with all ‘+’ terminals connected together, and all ‘–’terminals connected together. Each relay must be daisy-chained to the next one. Avoid star or stub connected configura-tions. The last device at each end of the daisy-chain should be terminated with a 120 Ω ¼ watt resistor in series with a 1 nFcapacitor across the ‘+’ and ‘–’ terminals. Observing these guidelines will result in a reliable communication system that isimmune to system transients.
The optional remote RTD module is designed to be mounted near the motor. This eliminates the need for multiple RTDcables to run back from the motor which may be in a remote location to the switchgear. Although the module is internallyshielded to minimize noise pickup and interference, it should be mounted away from high current conductors or sources ofstrong magnetic fields.
The remote RTD module physical dimensions and mounting (drill diagram) are shown below. Mounting hardware (bolts andwashers) and instructions are provided with the module.
Figure 3–13: REMOTE RTD DIMENSIONS
Figure 3–14: REMOTE RTD REAR VIEW
FIBER OPTIC DATA LINK (F)For harsh environments
DIGITAL INPUTS(IO)
Communications(3)-RS485 Com Ports
ANALOG OUTPUT(IO)
813701A4.CDR
CONTROL POWERHI: 50-300VDC/40-265VACLO: 20-60VDC/20-48VAC
GE Power Management 369 Motor Management Relay 4-1
4 USER INTERFACES 4.1 FACEPLATE INTERFACE
4
4 USER INTERFACES 4.1 FACEPLATE INTERFACE 4.1.1 DISPLAY
All messages are displayed on a 40-character LCD display to make them visible under poor lighting conditions and fromvarious viewing angles. Messages are displayed in plain English and do not require the aid of an instruction manual fordeciphering. While the keypad and display are not actively being used, the display will default to user defined status mes-sages. Any trip, alarm, or start inhibit will automatically override the default messages and appear on the display.
Contrast Adjustment and Lamp Test: Press the [HELP] key for 2 seconds to initiate lamp test. The contrast can also beadjusted now as required. Use the [VALUE] up and down keys to adjust the contrast. Press the [ENTER] key to save theadjustment when completed.
4.1.2 LED INDICATORS
There are ten LED indicators, as follows:
• TRIP Trip relay has operated (energized)
• ALARM Alarm relay has operated (energized)
• AUX 1 Auxiliary relay has operated (energized)
• AUX 2 Auxiliary relay has operated (energized)
• SERVICE Relay in need of technical service.
• BSD Relay has detected a backspin condition on a stopped motor
• RRTD RRTD module communication indication
• METERING 369 has option M or B installed
• COM 1 Channel 1 RS485 communication indication
• COM 2 Channel 2 RS485 communication indication
Figure 4–1: LED INDICATORS
4.1.3 RS232 PROGRAM PORT
This port is intended for connection to a portable PC. Setpoint files may be created at any location and downloaded throughthis port using the 369PC software. Local interrogation of Setpoints and Actual Values is also possible. New firmware maybe downloaded to the 369 flash memory through this port. Upgrading of the relay firmware does not require a hardwareEPROM change.
4-2 369 Motor Management Relay GE Power Management
4.1 FACEPLATE INTERFACE 4 USER INTERFACES
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4.1.4 KEYPAD
The 369 messages are organized into pages under the main headings, Setpoints and Actual Values. The [SETPOINTS]key is used to navigate through the page headers of the programmable parameters. The [ACTUAL VALUES] key is used tonavigate through the page headers of the measured parameters.
Each page is broken down further into logical subgroups of messages. The [PAGE] up and down keys may be used to nav-igate through the subgroups.
• [SETPOINTS]: This key may be used to navigate through the page headers of the programmable parameters. Alter-nately, one can press this key followed by using the Page Up / Page Down keys.
• [ACTUAL VALUES]: This key is used to navigate through the page headers of the measured parameters. Alternately,one can scroll through the pages by pressing the Actual Values key followed by using the Page Up / Page Down keys.
• [PAGE]: The Page Up/ Page Down keys may be used to scroll through page headers for both Setpoints and ActualValues.
• [LINE]: Once the required page is found, the Line Up/ Line Down keys may be used to scroll through the sub-headings.
• [VALUE]: The Value Up and Value Down keys are used to scroll through variables in the Setpoint programming mode.It will increment and decrement numerical Setpoint values, or alter yes/no options.
• [RESET]: The reset key may be used to reset a trip or latched alarm, provided it has been activated by selecting thelocal reset.
• [ENTER] The key is dual purpose. It is used to enter the subgroups or store altered setpoint values.
• [CLEAR] The key is also dual purpose. It may be used to exit the subgroups or to return an altered setpoint to its origi-nal value before it has been stored.
• [HELP]: The help key may be pressed at any time for context sensitive help messages; such as the Setpoint range,etc.
To enter setpoints, select the desired page header. Then press the [LINE UP] / [LINE DOWN] keys to scroll through thepage and find the desired subgroup. Once the desired subgroup is found, press the [VALUE UP] / [VALUE DOWN] keys toadjust the setpoints. Press the [ENTER] key to save the setpoint or the [CLEAR] key to revert back to the old setpoint.
4.1.5 SETPOINT ENTRY
In order to store any setpoints, Terminals 57 and 58 (access terminals) must be shorted (a key switch may be used forsecurity). There is also a Setpoint Passcode feature that may be enabled to restrict access to setpoints. The passcodemust be entered to allow the changing of setpoint values. A passcode of 0 effectively turns off the passcode feature andonly the access jumper is required for changing setpoints.
If no key is pressed for 30 minutes, access to setpoint values will be restricted until the passcode is entered again. To pre-vent setpoint access before the 30 minutes expires, the unit may be turned off and back on, the access jumper may beremoved, or the SETPOINT ACCESS setpoint may be changed to Restricted. The passcode cannot be entered until termi-nals 57 and 58 (access terminals) are shorted.
Setpoint changes take effect immediately, even when motor is running. It is not recommended, however, to change set-points while the motor is running as any mistake could cause a nuisance trip.
Refer to Section 5.2.2: SETPOINT ACCESS on page 5–4 for a detailed description of the setpoint access procedure.
The following minimum requirements must be met for the 369PC Program to properly operate on a computer.
Processor: Minimum 486, Pentium or higher recommended.
Memory: Minimum 4 MB RAM, 16 MB recommended. Minimum 540 K of conventional memory.
Hard Drive: 20 MB free space required before installation of PC program.
O/S: Minimum Windows 3.1 or Windows 3.11 for Workgroups, Windows NT or Windows 95/98 (recommended). Windows 2000/MEWindows 3.1 users must ensure that SHARE.EXE is installed.
Other: CD-ROM or internet capability to load 369PC(if neither is available, 3.5” floppy disks can be ordered from the factory)
If 369PC is currently installed, note the path and directory name. It will be required during upgrading.
The 369PC software is included on the GE Power Management Products CD that accompanied the 369. If your PC doesnot have CD-ROM capability, the software may be downloaded from the GE Power Management website at www.GEin-dustrial.com/pm or ordered on 3.5” floppy disks from the nearest GE Power Management office.
All 369 relays come with the GE Power Management Products CD. Since this CD is essentially a “snapshot” ofthe GE Power Management website, the procedures for installation from the CD and the Web are identical. How-ever, the website will always contain the newest versions and is recommended for upgrading the software.
4.2.2 INSTALLING 369PC
Installation of the 369PC software is accomplished as follows.
1. Ensure that Windows is running and functional on the local PC
2. Insert the GE Power Management Products CD into your CD-ROM drive or point your web browser to the GE PowerManagement website at www.GEindustrial.com/pm . With Windows 95/98, the Products CD will launch the welcomescreen automatically (alternately, you may open the index.htm file in the Products CD root directory). Since theProducts CD is essentially a “snapshot” of the GE Power Management website, the procedures for installation from theCD and the Web are identical from this point forward.
3. Click the Index By Product Name item from the main page menu and select the 369 Motor Management Relay fromthe product list to open the 369 product page.
4. Click the Software menu item from the Product Resources list to proceed to the 369 software page.
5. The latest version of the 369PC software will be shown. Click the 369PC Program item to download the installationprogram to your local PC. Run the installation program and follow the prompts to install the software to the desireddirectory. When complete, a new GE Power Management group window will appear containing the 369PC icon.
4.2.3 UPGRADING 369PC
The following procedure determines if the currently installed version of 369PC requires upgrading:
1. Run the 369PC software.
2. Select the Help > About 369PC menu item.
3. Compare the version shown in this window with the version on the Products CD or website. If the installed version islower than the version on the CD or web, then 369PC needs to be upgraded.
4. To upgrade the 369PC software, follow the installation instructions shown in Section 4.2.2: INSTALLING 369PC onpage 4–3. The installation program will automatically upgrade the 369PC software.
4-4 369 Motor Management Relay GE Power Management
4.2 369PC INTERFACE 4 USER INTERFACES
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4.2.4 CONFIGURATION
1. Connect the computer containing the 369PC software to the relay via one of the RS485 ports or directly via the RS232faceplate port.
2. Run the 369PC software. Once the 369PC program starts to operate, it does not automatically communicate with therelay unless it is enabled to do so (see the Startup Mode option below). The LED status and display message shownwill match actual relay state if communications is established.
3. To setup communications, select Communication > Computer menu item.
Figure 4–2: COMMUNICATION / COMPUTER WINDOW
4. Set Slave Address to match that programmed into relay.
5. Set Communication Port# to the computer port connected to the relay.
6. Set Baud Rate and Parity to match that programmed into relay.
7. Set Control Type to type used.
8. Set Startup Mode to the desired startup (communicate or file)
9. Select ON to enable communications with new settings.
4.2.5 UPGRADING RELAY FIRMWARE
1. To upgrade the relay firmware, connect a computer to the 369 via the front RS232 port. Then run the 369PC programand establish communications with the relay.
2. Select the Communication > Upgrade Firmware menu item. The following window will appear:
3. Select Yes to proceed or No to abort. Remember, all previously programmed setpoints will be erased! If you have notalready created a setpoint file, it is highly recommended that the current setpoints be saved to disk by following theprocedure in Section 4.2.6: CREATING A NEW SETPOINT FILE on page 4–5 before continuing with the firmwareupgrade.
4. The Load Firmware window will appear. Locate the firmware file to load into the relay and select OK to proceed orCancel to quit the firmware upgrade.
GE Power Management 369 Motor Management Relay 4-5
4 USER INTERFACES 4.2 369PC INTERFACE
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5. The Upload Firmware dialog box shown below will appear. This provides one last chance to cancel the firmwareupgrade. Select Yes to proceed, No to load a different firmware file, or Cancel to end the firmware upgrade. This willbe the last chance to cancel the firmware upgrade – all previously programmed setpoints will be erased!
6. The 369PC software automatically puts the relay into upload mode and then begin loading the file selected.
7. When loading is complete, the relay will require programming. To reload the previously programmed setpoints, see theprocedure in Section 4.2.8: DOWNLOADING A SETPOINT FILE TO THE 369 on page 4–6.
4.2.6 CREATING A NEW SETPOINT FILE
1. To create a new setpoint file, run the 369PC Program. It is not necessary to have a 369 relay connected to the com-puter to create the file. The 369PC status bar will indicate that the program is in “Editing File” mode and “Not Commu-nicating”.
2. From the Setpoint menu, choose the appropriate setpoints section to program, for example, S2 System Setup > Out-put Relay Setup to enter output relay setup setpoints.
Figure 4–3: OUTPUT RELAY SETUP WINDOW
3. When you are finished programming a page, select OK and store the information to the PC’s scratchpad memory(note: this action does store the information as a file on a disk).
4. Repeat steps 2 to 3 until all the desired setpoints are programmed.
5. Select the File > Save As menu item to store these setpoints to the disk. Enter the location and file name of the set-point file with a file extension of ‘.369’ and select OK.
6. The file is now saved. See Section 4.2.8: DOWNLOADING A SETPOINT FILE TO THE 369 on page 4–6 for instruc-tions on reloading this file to the 369.
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4.2.7 EDITING A SETPOINT FILE
The following procedure describes how to edit setpoint files.
1. Run the 369PC software. It is not necessary to have a 369 relay connected to the computer. If 369PC is not communi-cating with the relay, the status bar will indicate that the program is in “Editing File” mode and “Not Communicating”.
2. If the 369PC program is communicating, select the Communication > Computer menu item to launch the COMMU-NICATION/COMPUTER window (see Figure 4–2: COMMUNICATION / COMPUTER WINDOW on page 4–4) and setCommunicate to Off . Click OK to turn off communications to the relay and place 369PC in “Editing File” mode.
3. Open a setpoint file by selecting the File > Open menu item. Locate the appropriate 369 setpoint files (ending with theextension 369) and select OK.
Note that 369PC can open both 369 and 269 setpoint files. For instructions on using 269 setpoint files with the 369,see Section 4.2.10: CONVERTING 269 SETPOINT FILES TO 369 on page 4–8.
4. From the Setpoints menu item, choose the appropriate setpoints section to program; for example, System Setup >Output Relay Setup to edit the output relay setup setpoints. When you have finished editing a page, select OK tostore the information to the PC’s scratchpad memory (NOTE: this action does store the information as a file on a disk).
5. Repeat Step 4 until all the desired setpoints are edited. Select the File > Save As menu item to store this file to disk.Enter the location and file name of the setpoint file with a file extension of ‘.369’.
6. The file is now saved to disk. See Section 4.2.8: DOWNLOADING A SETPOINT FILE TO THE 369 on page 4–6 forinstructions on downloading this file to the 369.
4.2.8 DOWNLOADING A SETPOINT FILE TO THE 369
The following procedure describes how to download setpoint files to the 369.
1. To download a pre-programmed setpoint file to the 369, run 369PC and establish communications with the connectedrelay via the faceplate RS232 port or through the RS485 connector.
2. Select the File > Open menu item to locate the setpoint file to be loaded into the relay. Click OK to load.
3. When the file is completely loaded, the 369PC software will break communications with the connected relay and thestatus bar changes to indicate “Editing File”, “Not Communicating”.
4. Select the File > Send Info To Relay menu item to download the setpoint file to the connected relay.
5. When the file is completely downloaded, the status bar will revert back to “Communicating”. The relay now contains allthe setpoints as programmed in the setpoint file.
If an attempt is made to download a setpoint file with a revision number that does not match the relay firmwarerevision, the following message type will appear:
See Section 4.2.9: UPGRADING SETPOINT FILE TO NEW REVISION on page 4–7 for instructions on upgrad-ing the setpoint file.
GE Power Management 369 Motor Management Relay 4-7
4 USER INTERFACES 4.2 369PC INTERFACE
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4.2.9 UPGRADING SETPOINT FILE TO NEW REVISION
The following procedure describes how to upgrade setpoint file revisions. It may be necessary to upgrade the revision codefor a previously saved setpoint file when the 369 firmware is upgraded.
1. To upgrade the revision of a previously saved setpoint file, run the 369PC software and establish communications withthe 369 through the front RS232 port or through the RS485 connector.
2. Select the Actual > A6 Relay Information menu item and record the Main Software revision number (for example,53CMB130.000, where 130 is the main revision identifier and refers to firmware version 1.30).
Figure 4–4: RELAY INFORMATION WINDOW
3. Select the File > Open menu item and select the setpoint file to be downloaded to the connected relay. When the file isopen, the 369PC software will be in “File Editing” mode and “Not Communicating”.
4. Select the File > Properties menu item and note the version code of the setpoint file.
Figure 4–5: SETPOINT FILE PROPERTIES
5. If the Version code (e.g. 1.4X above) differs the firmware revision (noted in step 2 as 130), select the revision codethat matches the firmware from the pull-down tab. For example: for firmware revision 53CMB170.000 and current set-point revision as 1.61; change the Version code to 1.7X to upgrade.
369 firmware versions 1.10 and 1.12 are not compatible with newer versions. A new setpoint file mustbe created!
6. Select the File > Save menu item to save the setpoint file.
7. To download the upgraded setpoint file to the 369, see Section 4.2.8: DOWNLOADING A SETPOINT FILE TO THE369 on page 4–6.
4-8 369 Motor Management Relay GE Power Management
4.2 369PC INTERFACE 4 USER INTERFACES
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4.2.10 CONVERTING 269 SETPOINT FILES TO 369
The 369PC software can convert a 269 setpoint file to a 369 setpoint file. These feature makes it extremely easy to replacea 269 with a 369.
1. Load a 269 setpoint file by selecting the File > Open menu item. Select the path where the 269 setpoint file is locatedand click OK to open.
2. The following warning may appear alerting you that not all of the setpoints can be converted. Click Yes to continue.
3. A second warning appears alerting you to the exceptions or the setpoints that could not be converted. Take note ofthese setpoints and enter the affected setpoints after conversion is complete. Click OK to continue.
4. The setpoint file has now been converted. Manual configure the setpoints that did not convert in Steps 2 and 3. Savethe file under a different name with the File > Save As menu item. Select the path to save the file and the name of thefile. Click OK when complete.
5. The setpoint can now be downloaded to the 369. Refer to 4.2.8: DOWNLOADING A SETPOINT FILE TO THE 369 onpage 4–6 for more information.
4.2.11 PRINTING
This procedure describes how to print a list of the 369 setpoints and/or actual values.
1. Start 369PC. It is not necessary to establish communications.
2. Select the File > Open menu item to open a previously saved setpoint file, orestablish communications with a connected 369 unit.
3. Select the File > Print Setup menu item. The following window will appear.
• Select Actual Values to print a list of actual values.
• Select Setpoints (All) or Setpoints (Enabled Features) to print a list of setpoints.
• Select User Definable Memory Map to print the user-definable memory map.
4. Click OK to close the Window.
5. Select the File > Print menu item to send the setpoint/actual values file to the connected printer.
GE Power Management 369 Motor Management Relay 4-9
4 USER INTERFACES 4.2 369PC INTERFACE
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4.2.12 TRENDING
Trending from the 369 can be accomplished via the 369PC. Many different parameters can be trended and graphed atsampling periods from 1 second up to 1 hour. The parameters which can be trended by 369PC are:
1. To use the Trending function, run the 369PC program and establish communications with a connected 369 relay.Select the Actual > Trending menu item to open the Trending window (see Figure 4–7: TRENDING VIEW on page 4–10).
2. Press the Setup button to enter the Graph Attribute page shown below.
Figure 4–6: GRAPH ATTRIBUTE PAGE
3. Program the Graphs to display by selecting the pull down menu beside each Graph Description. Change the Color ,Style, Width, Group #, and Spline selection as desired.
4. Select the same Group # for all parameters to be scaled together.
5. Select Save to store these Graph Attributes, and OK to close this window.
6. In the Trending window, select the Sample Rate , click the check boxes of the Graphs to be displayed, and select RUNto begin the trending sampling.
7. Print will copy the window to the system printer. More information for navigating through Trending can be found underHelp .
8. The Trending File Setup button can be used to write the graph data to a file in a standard spreadsheet format. Ensurethat the Write Trended Data to File box is checked, and that the Sample Rate is at a minimum of 5 seconds. Set thefile capacity limit to the amount of memory available for trended data.
Currents/Voltages
Phase Currents A,B,C Avg. Phase Current Motor Load Current Unbalance
Ground Current Voltages Vab, Vbc, Vca Van, Vbn & Vcn
Power
Power Factor Real Power (kW) Reactive Power (kvar) Apparent Power (kVA)
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Figure 4–7: TRENDING VIEW
4.2.13 WAVEFORM CAPTURE
The 369PC software can capture waveforms from the 369 at the instant of a trip. Sixteen (16) cycles can be captured andthe trigger point can be adjusted to anywhere within the set cycles. The last 3 waveform events are viewable.
The waveforms captured are:
• Phase Currents A, B, and C
• Ground Current
• Voltages AN, BN, CN if Wye connected or AB and CB if open delta connected.
1. To use the Waveform Capture function, run 369PC and establish communications with the 369 relay.
2. Select the Actual > Waveform Capture menu item to open the Waveform Capture window (see Figure 4–8: WAVE-FORM CAPTURE VIEW on page 4–11)
3. The waveform of phase A current of the last trip of the 369 will appear. The date and time of this trip is displayed on thetop of the window. The RED vertical line indicates the trigger point of the relay.
4. Press the Setup button to enter the Graph Attribute page.
5. Program the graphs to display by selecting the pull down menu beside each Graph Description. Change the Color ,Style, Width, Group #, and Spline selection as desired.
6. Select the same Group # for all parameters to be scaled together.
7. Select Save to store these Graph Attributes, and OK to close this window.
8. In the Waveform Capture window, click the check boxes of the Graphs to be displayed,
9. The Save button can be used to store the current image on the screen, and Open can be used to recall a savedimage. Print will copy the window to the system printer. More information for navigating through Waveform Capture canbe found under Help .
Mode SelectClick on these buttons to view
Cursor Line 1, Cursor Line 2, or Delta (difference)
GE Power Management 369 Motor Management Relay 4-11
4 USER INTERFACES 4.2 369PC INTERFACE
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Figure 4–8: WAVEFORM CAPTURE VIEW
4.2.14 PHASORS
The 369PC program can be used to view the phasor diagram of three phase currents and voltages. The phasors are forphase voltages A, B, and C, and phase currents A, B, and C
1. To use the Phasor Metering function, run 369PC and establish communications with the 369 relay.
2. Select the Actual > Metering Data menu item then click on the Phasors tab on the Metering Data Window. The phasordiagram and the values of voltage phasors, and current phasors are displayed.
Figure 4–9: PHASOR DATA VIEW
3. Note that the longer arrows are the voltage phasors and the shorter arrows are the current phasors. Va and Ia are thereferences (i.e. zero degree phase) and the lagging angle is clockwise.
WaveformThe waveform data
from the 369.
Trigger AgentDisplay the cause of
Trip.
Date/TimeDisplays the Date and
Time of the Trip.
TriggerClick to manually Trigger and
Capture waveforms.
Mode SelectClick on these buttons to view
Cursor Line 1, Cursor Line 2, or Delta (difference)
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4.2.15 EVENT RECORDING
The 369PC software can be used to view the 369 Event Recorder. The Event Recorder stores motor and system informa-tion each time an event occurs (i.e. motor trip). The Event Recorder stores up to 40 events, where EVENT01 is the oldestevent. EVENT01 is overwritten when the number of events exceeds 40.
1. To use the Event Recording function, run 369PC and establish communications with the 369 relay.
2. Select the Actual > Event Recording menu item to open the Event Recording Window. The Event Recording Windowdisplays the list of events with the most current event displayed on top.
Figure 4–10: EVENT RECORDER VIEW
3. Press the View Data button to view the details of selected events. The Event Record Selector at the top of the ViewData Window allows the user to scroll through different events.
4. Select Save to store the details of the selected events to a file, Print to send the events to the system printer, and OKto close the window.
4.2.16 TROUBLESHOOTING
This section provides some procedures for troubleshooting the 369PC when troubles are encountered within the Window-sTM Environment, e.g. General Protection Fault (GPF), Missing Window, Problems in Opening/Saving Files, andApplication Error .
If the 369 program causes WindowsTM system errors:
• Make sure the PC computer program is installed and meets the minimum requirements.
• Make sure only one copy of 369PC is running at a given time: 369PC cannot multi-task.
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5.2 S1 369 SETUP 5 SETPOINTS
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5.2 S1 369 SETUP 5.2.1 SETPOINTS PAGE 1 MENU
These setpoints deal with the non-protective setup and operation of the 369.
5.2.2 SETPOINT ACCESS
PATH: S1 369 SETUP SETPOINT ACCESS
There are two levels of access security: Read Only and Read & Write. The access terminals (Terminals 57 and 58) must beshorted to gain read/write access via the front panel. The Front Panel Access displays the level of access based on thecondition of the access switch.
Read Only: Setpoints and Actual Values may be viewed but, not changed.Read & Write: Permits viewing of Actual Values as well as changing and storing of Setpoints
Communication access can be changed with the 369PC. The setpoint access menu is located in the Setpoint > S1 Setupmenu item. An access tab is shown only when communicating with a relay. To set a password, click on the Change Pass-word button, then enter and verify a new passcode when prompted. After a passcode is entered, Setpoint Access changesto Read Only. When setpoints are changed through 369PC during Read Only access, the passcode must be enteredbefore the new setpoint is stored. To allow extended write access, click Allow Write Access and enter the passcode. Tochange the access level back to Read Only, click Restrict Write Access . If no setpoints are stored for longer than 30 min-utes, or if control power is cycled, access automatically reverts to Read Only.
If the access level is Read/Write, write access to setpoints is automatic and a 0 password need not be entered. If the pass-word is not known, consult the factory service department with the ENCRYPTED COMM PASSCODE value to be decoded.
GE Power Management 369 Motor Management Relay 5-5
5 SETPOINTS 5.2 S1 369 SETUP
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5.2.3 DISPLAY PREFERENCES
PATH: S1 369 SETUP DISPLAY PREFERENCES
Some of the message characteristics can be modified to suit different situations preferences setpoints.
If no keys are pressed for a period of time longer than the default message timeout, the 369 automatically displays a seriesof default messages. This time can be modified to ensure messages remain on the screen long enough during program-ming or reading of actual values. Each default message remains on the screen for the default message cycle time.
The contrast of the LCD display can be changed for different lighting conditions. If the display is unreadable (dark or light)press the [HELP] key for 2 seconds. This will put the relay in manual contrast adjustment mode. Use the value up or downkeys to adjust the contrast level. Press the [ENTER] key when complete.
The display update interval controls how often the display is updated. If the displayed readings are fluctuating, the time maybe increased to smooth out the readings. Temperatures may be displayed in either Celsius or Fahrenheit degrees. RTDsetpoints are programmed in Celsius only.
DISPLAY PREFERENCES DEFAULT MESSAGECYCLE TIME: 20 s
Range: 5 to 100 s in steps of 1
DEFAULT MESSAGETIMEOUT: 300 s
Range: 10 to 900 s in steps of 1
CONTRAST ADJUSTMENT:145
Range: 0 to 255Display darkens as number is increased.
FLASH MESSAGEDURATION: 2s
Range: 1-10 s in steps of 1
TEMPERATURE DISPLAY:Celsius
Range: Celsius, FahrenheitShown if option R installed or RRTD added
GE Power Management 369 Motor Management Relay 5-7
5 SETPOINTS 5.2 S1 369 SETUP
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The 369 is equipped with four independent serial ports. The RS232 port is for local use and responds regardless of the pro-grammed slave address. The rear RS485 communication ports are addressed. If an RRTD module is used in conjunctionwith the 369, channel 3 must be used for communication between the two devices and the CHANNEL 3 APPLICATION set-point must be set to "RRTD" (note that the corresponding setting on the RRTD must be set to "MODBUS"). A fiber optic port(Option F) may be ordered for channel 3. If the channel 3 fiber optic port is used, the channel 3 RS485 connection is dis-abled.
The RS232 port may be connected to a personal computer running 369PC. This may be used for downloading and upload-ing setpoints files, viewing actual values, and upgrading the 369 firmware. See Section 4.2: 369PC INTERFACE on page4–3 for details on using 369PC.
The RS485 ports support a subset of the Modbus RTU protocol. Each port must have a unique address between 1 and254. Address 0 is the broadcast address listened to by all relays. Addresses need not be sequential; however, no twodevices can have the same address. Generally, each addition to the link uses the next higher address, starting at 1. A max-imum of 32 devices can be daisy-chained and connected to a DCS, PLC, or PC using the RS485 ports. A repeater may beused to allow more than 32 relays on a single link.
The Profibus-DP protocol is supported with the optional Profibus protocol interface (option P). The bus address as Profi-bus-DP node is set with the PROFIBUS ADDRESS setpoint, with an address range from 1 to 126. Address 126 is used onlyfor commissioning purposes and should not be used to exchange user data.
The Modbus/TCP protocol is also supported with the optional Modbus/TCP protocol interface (option E).
GATEWAY ADD.OCTET 1: 127
Range: 0 to 255 in steps of 1Shown only in models with Modbus/TCP (Option E)
GATEWAY ADD.OCTET 2: 0
Range: 0 to 255 in steps of 1Shown only in models with Modbus/TCP (Option E)
GATEWAY ADD.OCTET 3: 0
Range: 0 to 255 in steps of 1Shown only in models with Modbus/TCP (Option E)
GATEWAY ADD.OCTET 4: 1
Range: 0 to 255 in steps of 1Shown only in models with Modbus/TCP (Option E)
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5.2 S1 369 SETUP 5 SETPOINTS
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5.2.5 REAL TIME CLOCK
PATH: S1 369 SETUP REAL TIME CLOCK
The time/date stamp is used to track events for diagnostic purposes. The date and time are preset but may be enteredmanually. A battery backed internal clock runs continuously even when power is off. It has the same accuracy as an elec-tronic watch approximately ±1 minute per month. It may be periodically corrected either manually through the keypad or viathe clock update command over the serial link using 369PC.
Enter the current date using two digits for the month, two digits for the day, and four digits for the year. For example, July15, 2001 is entered as "07 15 2001". If entered from the keypad, the new date takes effect the moment the [ENTER] key ispressed. Enter the current time, by using two digits for the hour in 24 hour time, two digits for the minutes, and two digits forthe seconds. If entered from the keypad, the new time will take effect the moment the [ENTER] key is pressed.
If the serial communication link is used, then all the relays can keep time in synchronization with each other. A new clocktime is pre-loaded into the memory map via the communications port by a remote computer to each relay connected on thecommunications channel. The computer broadcasts (address 0) a “set clock” command to all relays. Then all relays in thesystem begin timing at the exact same instant. There can be up to 100 ms of delay in receiving serial commands so theclock time in each relay is ±100 ms, ± the absolute clock accuracy, in the PLC or PC (see Chapter 10: COMMUNICATIONSfor information on programming the time and synchronizing commands.)
5.2.6 WAVEFORM CAPTURE
PATH: S1 369 SETUP WAVEFORM CAPTURE
Waveform capture records contain waveforms captured at the sampling rate as well as contextual information at the pointof trigger. These records are triggered by trip functions, digital input set to capture or via the PC program.
Multiple waveforms are captured simultaneously for each record: Ia, Ib, Ic, Ig, Va, Vb, and Vc.
The trigger position is programmable as a percent of the total buffer size (e.g. 10%, 50%, 75%, etc.). The trigger positiondetermines the number of pre and post fault cycles the record will be divided into. The relay sampling rate is 16 samplesper cycle.
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5.2.7 MESSAGE SCRATCHPAD
PATH: S1 369 SETUP MESSAGE SCRATCHPAD
Five different 40-character message screens can be programmed. These messages may be notes that pertain to the 369installation. This can be useful for reminding operators to perform certain tasks. The messages are entered through the anyof the communications ports. The 369PC software should be used to enter these messages.
5.2.8 DEFAULT MESSAGES
PATH: S1 369 SETUP DEFAULT MESSAGES
MESSAGE SCRATCHPAD Text 1 Range: 2 x 20 alphanumeric
Text 2 Range: 2 x 20 alphanumeric
Text 3 Range: 2 x 20 alphanumeric
Text 4 Range: 2 x 20 alphanumeric
Text 5 Range: 2 x 20 alphanumeric
DEFAULT MESSAGES DEFAULT TO CURRENTMETERING: No
Range: Yes, No
DEFAULT TO MOTORLOAD: No
Range: Yes, No
DEFAULT TO DELTAVOLTAGE METERING: No
Range: Yes, NoOnly shown if option M installed
DEFAULT TO POWERFACTOR: No
Range: Yes, NoOnly shown if option M installed
DEFAULT TO POSITIVEWATTHOURS: No
Range: Yes, NoOnly shown if option M installed
DEFAULT TO REALPOWER: No
Range: Yes, NoOnly shown if option M installed
DEFAULT TO REACTIVEPOWER: No
Range: Yes, No Only shown if option M installed
DEFAULT TO HOTTESTSTATOR RTD: No
Range: Yes, NoOnly shown if option R or RRTD installed
5-10 369 Motor Management Relay GE Power Management
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The 369 displays a series of default messages. These default messages appear after the value for the DEFAULT MESSAGECYCLE TIME expires and there are no active trips, alarms or start inhibits. See Section 5.2.3: DISPLAY PREFERENCES onpage 5–5 for details on setting time delays and message durations.
The default messages can be selected from the list above including the five user definable messages from the messagescratchpad.
5.2.9 CLEAR/PRESET DATA
PATH: S1 369 SETUP CLEAR/PRESET DATA
These commands may be used to clear various historical data. This is useful on new installations or to preset informationon existing installations where new equipment has been installed. The PRESET DIGITAL COUNTER setpoint appears only ifone of the digital inputs has been configured as a digital input counter.
5.2.10 FACTORY SERVICE
PATH: S1 369 SETUP FACTORY SERVICE
This section is for use by GE Power Management personnel for testing and calibration purposes.
DEFAULT TO TEXTMESSAGE 5: No
Range: Yes, No
CLEAR/PRESET DATA CLEAR ALL DATA:No
Range: No, Yes
CLEAR LAST TRIPDATA: No
Range: No, Yes
CLEAR TRIPCOUNTERS: No
Range: No, Yes
CLEAR EVENTRECORD: No
Range: No, YesClears all 40 events
CLEAR RTDMAXIMUMS: No
Range: No, Yes
CLEAR PEAK DEMANDDATA: No
Range: No, Yes
CLEAR MOTORDATA: No
Range: No, Yes. Clears learned acceleration time,starting current, thermal capacity, and statistics.
CLEAR ENERGY DATA:NO
Range: No, Yes
PRESET MWh:0
Range: 0 to 65535 MWh in steps of 1Can be preset or cleared by storing 0
PRESET POSITIVEkvarh: 0
Range: 0 to 65535 kvarh in steps of 1Can be preset or cleared by storing 0
PRESET NEGATIVEkvarh: 0
Range: 0 to 65535 kvarh in steps of 1Can be preset or cleared by storing 0
PRESET DIGITALCOUNTER: 0
Range: 0 to 65535 in steps of 1Can be preset or cleared by storing 0
GE Power Management 369 Motor Management Relay 5-11
5 SETPOINTS 5.3 S2 SYSTEM SETUP
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5.3 S2 SYSTEM SETUP 5.3.1 SETPOINTS PAGE 2 MENU
These setpoints are critical to the operation of the 369 protective and metering features and elements. Most protective ele-ments are based on the information input for the CT/VT SETUP and OUTPUT RELAY SETUP. Additional monitoring alarmsand control functions of the relay are also set here.
5.3.2 CT/VT SETUP
PATH: S2 SYSTEM SETUP CT/VT SETUP
PHASE CT PRIMARY:
Enter the phase CT primary here. The phase CT secondary (1 A or 5A) is determined by terminal connection to the 369.The phase CT should be chosen such that the motor FLA is between 50% and 100% of the phase CT primary. Ideally themotor FLA should be as close to 100% of phase CT primary as possible, never more. The phase CT class or type shouldalso be chosen such that the CT can handle the maximum potential fault current with the attached burden without having itsoutput saturate. Information on how to determine this if required is available in Section 7.4: CT SPECIFICATION ANDSELECTION on page 7–7.
MOTOR FLA:
The motor FLA (full load amps or full load current) must be entered. This value may be taken from the motor nameplate ormotor data sheets.
S2 SETPOINTSSYSTEM SETUP
CT/VT SETUPSee page 5–11.
MONITORING SETUPSee page 5–12.
OUTPUT RELAY SETUPSee page 5–16.
CONTROL FUNCTIONSSee page 5–17.
CT/VT SETUP PHASE CT PRIMARY:500
Range: 1 to 5000 in steps of 1
MOTOR FLA:10
Range: 1 to 5000 in steps of 1
GROUND CT TYPE:5
Range: None, 5A secondary, 1A secondary, 50:0.025
GROUND CT PRIMARY:100:5
Range: 1 to 5000 in steps of 1Only shown for 5A and 1A secondary CT
VT CONNECTION TYPE:None
Range: None, Open Delta, WyeOnly shown if option M or B installed
VT RATIO:35:1
Range: 1.00:1 to 240.00:1Not shown if VT Connection Type set to None
MOTOR RATED VOLTAGE:4160
Range: 100 to 20000 in steps of 1Not shown if VT Connection Type set to None
NOMINAL FREQUENCY:60 Hz
Range: 50, 60
SYSTEM PHASESEQUENCE: ABC
Range: ABC, ACBNot shown if VT Connection Type set to None
5-12 369 Motor Management Relay GE Power Management
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GROUND CT TYPE / GROUND CT PRIMARY:
The GROUND CT TYPE and GROUND CT PRIMARY (if 5 A or 1 A secondary) must be entered here. For high resistancegrounded systems, sensitive ground detection is possible with the 50:0.025 CT. On solidly or low resistance grounded sys-tems where fault current can be quite high, a 1 A or 5 A CT should be used for either zero-sequence (core balance) orresidual ground sensing. If a residual connection is used with the phase CTs, the phase CT primary must also be enteredfor the ground CT primary. As with the phase CTs the type of ground CT should be chosen to handle all potential fault levelswithout saturating.
VT CONNECTION TYPE / VT RATIO / MOTOR RATED VOLTAGE:
These voltage related setpoints are visible only if the 369 has metering installed.
The manner in which the voltage transformers are connected must be entered here or none if VTs are not used. The VTturns ratio must be chosen such that the secondary voltage of the VTs is between 40 and 240 V when the primary is atmotor nameplate voltage. All voltage protection features are programmed as a percent of motor nameplate or rated voltagewhich represents the rated motor design voltage line to line.
For example: If the motor nameplate voltage is 4160 V and the VTs are 4160/120 open-delta, program the following:
VT CONNECTION TYPE: Open DeltaVT RATIO: 34.67:1MOTOR RATED VOLTAGE: 4160 V
NOMINAL FREQUENCY:
Enter the nominal system frequency here. This setpoint allows the 369 to determine the internal sampling rate for maximumaccuracy. Frequency is normally determined from the Va voltage input. If however this voltage drops below the minimumvoltage threshold the Ia current input will be used.
SYSTEM PHASE SEQUENCE:
If the phase sequence for a given system is ACB rather than the standard ABC the phase sequence may be changed. Thissetpoint allows the 369 to properly calculate phase reversal and power quantities and is only visible if the 369 has meteringinstalled.
5.3.3 MONITORING SETUP
a) TRIP COUNTER
PATH: S2 SYSTEM SETUP MONITORING SETUP TRIP COUNTER
When the Trip Counter is enabled and the alarm pickup level is reached, an alarm will occur. To reset the alarm the tripcounter must be cleared (see Section 5.2.9: CLEAR/PRESET DATA on page 5–10 for details) or the pickup level increasedand the reset key pressed (if a latched alarm).
The trip counter alarm can be used to monitor and alarm when a predefined number of trips occur. This would then promptthe operator or supervisor to investigate the causes of the trips that have occurred. Details of individual trip counters can befound in the Motor Statistics section of Actual Values page 4 (see Section 6.5.3: MOTOR STATISTICS on page 6–17).
MONITORING SETUP TRIP COUNTER
TRIP COUNTERALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, orcombinations of them
GE Power Management 369 Motor Management Relay 5-13
5 SETPOINTS 5.3 S2 SYSTEM SETUP
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b) STARTER FAILURE
PATH: S2 SYSTEM SETUP MONITORING SETUP STARTER FAILURE
If the Starter Failure alarm feature is enabled, any time the 369 initiates a trip, the 369 will monitor the Starter Status input(if assigned to "Spare Switch" in S9 DIGITAL INPUTS ) and the motor current. If the starter status contacts do not changestate or motor current does not drop to zero after the programmed time delay, an alarm will occur. The time delay should beslightly longer than the breaker or contactor operating time. In the event that an alarm does occur, if Breaker was chosen asthe starter type, the alarm will be Breaker Failure. If on the other hand, Contactor was chosen for starter type, the alarm willbe Welded Contactor.
c) DEMAND:
PATH: S2 SYSTEM SETUP MONITORING SETUP CURRENT DEMAND
MONITORING SETUP TRIP COUNTER
STARTER FAILURE
STARTER FAILERALARM: Off
Range: Off, Latched, Unlatched
STARTER TYPE:Breaker
Range: Breaker, Contactor
ASSIGN ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, orcombinations of them
STARTER FAILUREDELAY:100 ms
Range: 10 to 1000 ms in steps of 10
STARTER FAILUREALARM EVENTS:
Range: ON, OFF
MONITORING SETUP TRIP COUNTER
STARTER FAILURE
CURRENT DEMAND
CURRENT DEMANDPERIOD: 15 min
Range: 5 to 90 min in steps of 1
CURRENT DEMANDALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, orcombinations of them
5-14 369 Motor Management Relay GE Power Management
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The 369 can measure the demand of the motor for several parameters (current, kW, kvar, kVA). The demand values maybe of interest for energy management programs where processes may be altered or scheduled to reduce overall demandon a feeder. An alarm will occur if the limit of any of the enabled demand elements is reached.
Demand is calculated in the following manner. Every minute, an average magnitude is calculated for current, +kW, +kvar,and kVA based on samples taken every 5 seconds. These values are stored in a FIFO (First In, First Out buffer). The sizeof the buffer is determined by the period selected for the setpoint. The average value of the buffer contents is calculatedand stored as the new demand value every minute. Demand for real and reactive power is only positive quantities (+kWand +kvar).
kW DEMANDPERIOD: 15 min
Range: 5 to 90 min in steps of 1
kW DEMANDALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, orcombinations of them
kW DEMAND ALARMLEVEL: 100 kW
Range: 1 to 50000 kW in steps of 1
kW DEMAND ALARMEVENTS: Off
Range: On, Off
kvar DEMAND
kvar DEMANDPERIOD: 15 min
Range: 5 to 90 min. in steps of 1
kvar DEMANDALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, orcombinations of them
kvar DEMAND ALARMLEVEL: 100 kvar
Range: 1 to 50000 in steps of 1
kvar DEMAND ALARMEVENTS: Off
Range: On, Off
kVA DEMAND
kVA DEMANDPERIOD: 15 min
Range: 5 to 90 min in steps of 1
kVA DEMANDALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, orcombinations of them
GE Power Management 369 Motor Management Relay 5-15
5 SETPOINTS 5.3 S2 SYSTEM SETUP
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where: N = programmed demand period in minutes and n = time in minutes
d) SELF-TEST RELAY ASSIGNMENT:
PATH: S2 SYSTEM SETUP MONITORING SETUP TRIP COUNTER
The 369 performs self-diagnostics of the hardware circuitry. The relay programmed as the Self-Test relay activates upon afailure of any self-diagnostic tests.
MONITORING SETUP TRIP COUNTER
STARTER FAILURE
CURRENT DEMAND
kW DEMAND
kvar DEMAND
kVA DEMAND
SELF TEST MODE
RELAYS: None Range: None, Trip, Aux1, Aux2, or combinationsof them
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5.3.4 OUTPUT RELAY SETUP
PATH: S2 SYSTEM SETUP OUTPUT RELAY SETUP
TRIP / AUX1 / AUX2 / ALARM RELAY RESET MODE:
A latched relay (caused by a protective elements alarm or trip) may be reset at any time, providing that the condition thatcaused the relay operation is no longer present. Unlatched elements will automatically reset when the condition thatcaused them has cleared. Reset location is defined in the following table.
TRIP / AUX1 / AUX2 / ALARM OPERATION:
These setpoints allow the choice of relay output operation to fail-safe or non-failsafe. Relay latchcode however, is definedindividually for each protective element.
Failsafe operation causes the output relay to be energized in its normal state and de-energized when activated by a protec-tion element. A failsafe relay will also change state (if not already activated by a protection element) when control power isremoved from the 369. Conversely a non-failsafe relay is de-energized in its normal non-activated state and will not changestate when control power is removed from the 369 (if not already activated by a protection element).
The choice of failsafe or non-failsafe operation is usually determined by the motor’s application. In situations where the pro-cess is more critical than the motor, non-failsafe operation is typically programmed. In situations where the motor is morecritical than the process, failsafe operation is programmed.
OUTPUT RELAY SETUP TRIP RELAY RESETMODE: All Resets
GE Power Management 369 Motor Management Relay 5-17
5 SETPOINTS 5.3 S2 SYSTEM SETUP
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5.3.5 CONTROL FUNCTIONS
PATH: S2 SYSTEM SETUP CONTROL FUNCTIONS
SERIAL COMMUNICATION CONTROL:
If enabled, the motor may be remotely started and stopped via Modbus® communications. Refer to the Modbus ProtocolReference Guide (available from the Modbus website at www.modbus.org ) for details on sending commands (functioncode 5). When a Stop command is sent the Trip relay will activate for 1 second to complete the trip coil circuit for a breakerapplication or break the coil circuit for a contactor application. When a Start command is issued the relay assigned for start-ing control will activate for 1 second to complete the close coil circuit for a breaker application or complete the coil circuit fora contactor application.
The Serial Communication Control functions may also be used to reset the relay and activate a waveform capture. Refer tothe Modbus Protocol Reference Guide (available from the Modbus website at www.modbus.org ) for more information.
5.3.6 REDUCED VOLTAGE START TIMER
PATH: S2 SYSTEM SETUP CONTROL FUNCTIONS REDUCED VOLTAGE
The 369 is capable of controlling the transition of a reduced voltage starter from reduced to full voltage. That transition maybe based on "Current Only", "Current and Timer", or "Current or Timer" (whichever comes first). When the 369 measuresthe transition of no motor current to some value of motor current, a 'Start' is assumed to be occurring (typically current willrise quickly to a value in excess of FLA, e.g. 3 × FLA). At this point, the REDUCED VOLTAGE START TIMER will be initializedwith the programmed value in seconds.
CONTROL FUNCTIONS SERIAL COMMUNICATIONCONTROL
SERIAL COMMUNICATIONCONTROL: Off
Range: On, Off
ASSIGN STARTCONTROL RELAYS: Aux1
Range: None, Alarm, Aux1, Aux2 orcombinations of them
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• If "Current Only" is selected, when the motor current falls below the programmed Transition Level, transition will be ini-tiated by activating the assigned output relay for 1 second. If the timer expires before that transition is initiated, anIncomplete Sequence Trip will occur activating the assigned trip relay(s).
• If "Current or Timer" is selected, when the motor current falls below the programmed Transition Level, transition will beinitiated by activating the assigned output relay for 1 second. If the timer expires before that transition is initiated, thetransition will be initiated regardless.
• If "Current and Timer" is selected, when the motor current falls below the programmed Transition Level and the timerexpires, transition will be initiated by activating the assigned output relay for 1 second. If the timer expires before cur-rent falls below the Transition Level, an Incomplete Sequence Trip will occur activating the assigned trip relay(s).
Figure 5–1: REDUCED VOLTAGE START CONTACTOR CONTROL CIRCUIT
Figure 5–2: REDUCED VOLTAGE STARTING CURRENT CHARACTERISTIC
If this feature is used, Starter Status Switch input must be either from a common control contact or a parallelcombination of Auxiliary ‘a’ contacts or a series combination of Auxiliary ‘b’ contacts from the reduced voltagecontactor and the full voltage contactor. Once transition is initiated, the 369 will assume the motor is still runningfor at least 2 seconds. This will prevent the 369 from recognizing an additional start if motor current goes to zeroduring an open transition.
GE Power Management 369 Motor Management Relay 5-19
5 SETPOINTS 5.3 S2 SYSTEM SETUP
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Figure 5–3: REDUCED VOLTAGE STARTER AUXILIARY A STATUS INPUT
Figure 5–4: REDUCED VOLTAGE STARTER AUXILIARY B STATUS INPUT
5.3.7 AUTORESTART
PATH: S2 SYSTEM SETUP CONTROL FUNCTIONS AUTORESTART
The 369 can be configured to automatically restart a motor in the event of a trip. When enabled, a restart timer will beloaded with the programmed timer values and trigger a designated output contact to operate when the timer expires. Thiscontact can be wired with OR logic in the start circuit of the motor. This feature is very useful in remote pumping applica-tions where the pumping station may be unmanned and an autoreclosure of contacts or breakers is required.
The autorestart implementation requires specific criteria to be present to allow motor restarting. The 369 will not attempt torestart after any Short Circuit or Ground Fault trip, and only one autorestart is attempted after an Overload trip, provided theSingle Shot Restart feature is enabled. In this mode, the 369 start inhibit will be active for the lockout time upon the secondconsecutive Overload trip. The 369 also requires that TRIP RELAY RESET MODE be set to "Remote Only" or "All Resets".Upon determination of a successful restart attempt, the SERIAL COMMUNICATION CONTROL must be enabled and an outputcontact assigned in the ASSIGNED START CONTROL RELAYS setpoint (these settings are found in S2 SYSTEM SETUP \ CON-TROL FUNCTIONS). The 369 uses the logic shown in Figure 5–5: AUTORESTART LOGIC on the following page to deter-mine restart conditions.
The Autorestart Delay Timer is calculated as follows:
Total Delay = RESTART DELAY + (total restarts × PROGRESSIVE DELAY) + HOLD DELAY
AUTORESTART AUTORESTART ENABLED:No
Range: Yes, No
TOTAL RESTARTS:1
Range: 0 to 20000 in steps of 1
RESTART DELAYDELAY: 0 s
Range: 0 to 20000 s in steps of 1
PROGRESSIVE DELAYDELAY: 0 s
Range: 0 to 20000 s in steps of 1
HOLD DELAYDELAY: 0 s
Range: 0 to 20000 s in steps of 1
BUS VALID ENABLED:No
Range: Yes, No
BUS VALID LEVEL:100%
Range: 15 to 100% of Motor Rated Voltage, in steps of 1
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The base delay time is set with the RESTART DELAY setpoint. The PROGRESSIVE DELAY setpoint is used to progressivelyadd time to the total restart delay based upon the number of restarts. The HOLD DELAY is used to sequentially staggerrestarts of a series of motors on a bus in the event of the entire bus being brought online. For example, four motors on abus may have settings of 60, 120, 180, and 240 seconds, respectively. In the event of a common fault, the motors arebrought online in sequence. The minimizes the effect of voltage sag on the bus when each motor is brought online.
The last criteria for a valid restart attempt is determined by the BUS VALID ENABLED/LEVELS setpoints. When enabled, the369 determines the average line voltage at the motor prior to restart and blocks an attempt if the voltage is below the BUSVALID LEVEL setpoint. The setpoint is in terms of the S2 SYSTEM SETUP \ CT/VT SETUP \ MOTOR RATED VOLTAGE setpoint.The 369 only examines this threshold at the instant of issuing a restart command to the designated output contact. Thisgives time for the bus to settle after the trip has occurred. This setpoint is only available if the Metering Option (M) isenabled.
GE Power Management 369 Motor Management Relay 5-21
5 SETPOINTS 5.4 S3 OVERLOAD PROTECTION
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5.4 S3 OVERLOAD PROTECTION 5.4.1 SETPOINTS PAGE 3 MENU
Heat is one of the principle enemies of motor life. When a motor is specified, the purchaser communicates to the manufac-turer what the loading conditions, duty cycle, environment and pertinent information about the driven load such as startingtorque. The manufacturer then provides a stock motor or builds a motor that should have a reasonable life under those con-ditions. The purchaser should request all safe stall, acceleration and running thermal limits for all motors they receive inorder to effectively program the 369.
Motor thermal limits are dictated by the design of the stator and the rotor. Motors have three modes of operation: lockedrotor or stall (rotor is not turning), acceleration (rotor is coming up to speed), and running (rotor turns at near synchronousspeed). Heating occurs in the motor during each of these conditions in very distinct ways. Typically, during motor starting,locked rotor, and acceleration conditions, the motor is rotor limited. That is, the rotor approaches its thermal limit before thestator. Under locked rotor conditions, voltage is induced in the rotor at line frequency, 50 or 60 Hz. This voltage causes acurrent to flow in the rotor, also at line frequency, and the heat generated (I2R) is a function of the effective rotor resistance.At 50 / Hz, the rotor cage reactance causes the current to flow at the outer edges of the rotor bars. The effective resistanceof the rotor is therefore at a maximum during a locked rotor condition as is rotor heating. When the motor is running at ratedspeed, the voltage induced in the rotor is at a low frequency (approximately 1 Hz) and therefore, the effective resistance ofthe rotor is reduced quite dramatically. During running overloads, the motor thermal limit is typically dictated by statorparameters. Some special motors might be all stator or all rotor limited. During acceleration, the dynamic nature of themotor slip dictates that rotor impedance is also dynamic, and a third overload thermal limit characteristic is necessary.
Typical thermal limit curves are shown below. The motor starting characteristic is shown for a high inertia load at 80% volt-age. If the motor started quicker, the distinct characteristics of the thermal limit curves would not be required and the run-ning overload curve would be joined with locked rotor safe stall times to produce a single overload curve.
Figure 5–6: TYPICAL TIME-CURRENT AND THERMAL LIMIT CURVES (ANSI/IEEE C37.96)
5-22 369 Motor Management Relay GE Power Management
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5.4.2 THERMAL MODEL
PATH: S3 OVERLOAD PROTECTION THERMAL MODEL
The primary protective function of the 369 is the thermal model. It consists of five key elements: the overload curve andpickup level, unbalance biasing, motor cooling time constants, and temperature biasing based on Hot/Cold motor informa-tion and measured stator RTD temperature.
The 369 integrates both stator and rotor heating into one model. Motor heating is reflected in the THERMAL CAPACITYUSED actual value. If stopped for a long period of time, the motor will be at ambient temperature and THERMAL CAPACITYUSED should be zero. If the motor is in overload, a trip will occur once the thermal capacity used reaches 100%. Insulationdoes not immediately melt when a motor’s thermal limit is exceeded. Rather, the rate of insulation degradation reaches apoint where the motor life will be significantly reduced if the condition persists. The thermal capacity used alarm may beused as a warning of an impending overload trip.
THERMAL MODEL OVERLOAD PICKUPLEVEL: 1.01 x FLA
Range: 1.01 to 1.25 in steps of 0.01
THERMAL CAPACITYALARM: Off
Range: Off, Latched, Unlatched
ASSIGN TC ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, or combinations ofthem
TC ALARM LEVEL:75 % Used
Range: 1 to 100% in steps of 1
THERMAL CAPACITYALARM EVENTS: No
Range: No, Yes
ASSIGN TC TRIPRELAYS: Trip
Range: None, Trip, Aux1, Aux2 or combinations of them(TC trip always on and latched)
ENABLE UNBALANCEBIAS OF TC: No
Range: No, Yes
UNBALANCE BIASK FACTOR: Learned
Range: Learned, 1 to 29 in steps of 1Only shown if Unbalance Bias is enabled
HOT/COLD SAFE STALLRATIO: 1.00
Range: 0.01 to 1.00 in steps of 0.01
ENABLE LEARNED COOLTIME: No
Range: No, Yes
RUNNING COOL TIMECONSTANT: 15 min.
Range: 1 to 500 min. in steps of 1Not shown if Learned Cool time is enabled
STOPPED COOL TIMECONSTANT: 30 min.
Range: 1 to 500 min. in steps of 1Not shown if Learned Cool time is enabled
ENABLE RTD BIASING:No
Range: No, Yes
RTD BIAS MINIMUM:40 °C
Range: 1to RTD BIAS MID POINTOnly shown if RTD biasing is enabled
RTD BIAS MID POINT:120 °C
Range: RTD BIAS MINIMUM to MAXIMUM Only shown if RTD biasing is enabled
RTD BIAS MAXIMUM:155 °C
Range: RTD BIAS MID POINT to 200Only shown if RTD biasing is enabled
5-24 369 Motor Management Relay GE Power Management
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a) STANDARD OVERLOAD CURVE:
The overload curve accounts for motor heating during stall, acceleration, and running in both the stator and the rotor. TheOVERLOAD PICKUP setpoint dictates where the running overload curve begins as the motor enters an overload condition.This is useful for service factor motors as it allows the pickup level to be defined. The curve is effectively cut off at currentvalues below this pickup.
Motor thermal limits consist of three distinct parts based on the three conditions of operation, locked rotor or stall, accelera-tion, and running overload. Each of these curves may be provided for both a hot motor and a cold motor. A hot motor isdefined as one that has been running for a period of time at full load such that the stator and rotor temperatures have set-tled at their rated temperature. A cold motor is defined as a motor that has been stopped for a period of time such that thestator and rotor temperatures have settled at ambient temperature. For most motors, the distinct characteristics of themotor thermal limits are formed into one smooth homogeneous curve. Sometimes only a safe stall time is provided. This isacceptable if the motor has been designed conservatively and can easily perform its required duty without infringing on thethermal limit. In this case, the protection can be conservative and process integrity is not compromised. If a motor has beendesigned very close to its thermal limits when operated as required, then the distinct characteristics of the thermal limitsbecome important.
The 369 overload curve can take one of two formats: Standard or Custom Curve. Regardless of which curve style isselected, the 369 will retain thermal memory in the form of a register called THERMAL CAPACITY USED . This register isupdated every 100 ms using the following equation:
where: time_to_trip = time taken from the overload curve at Ieq as a function of FLA.
The overload protection curve should always be set slightly lower than the thermal limits provided by the manufacturer. Thiswill ensure that the motor is tripped before the thermal limit is reached.
TIME TO TRIP AT4.50xFLA: 18 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT4.75xFLA: 16 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT5.00xFLA: 15 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT5.50xFLA: 12 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT6.00xFLA: 10 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT6.50xFLA: 9 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT7.00xFLA: 7 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT7.50xFLA: 6 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT8.00xFLA: 6 S
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT10.0xFLA: 6 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT15.0xFLA: 6 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
TIME TO TRIP AT20.0xFLA: 6 s
Range: 0 to 32767 s in steps of 1Only seen if curve style is Custom
GE Power Management 369 Motor Management Relay 5-25
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If the motor starting times are well within the safe stall times, it is recommended that the 369 Standard Overload Curves beused. The standard overload curves are a series of 15 curves with a common curve shape based on typical motor thermallimit curves (see Figure 5–7: 369 STANDARD OVERLOAD CURVES on page 5–25 and Figure 5–7: 369 STANDARDOVERLOAD CURVES on page 5–25).
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b) CUSTOM OVERLOAD CURVE:
If the motor starting current begins to infringe on the thermal damage curves, it may be necessary to use a custom curve toensure successful starting without compromising motor protection. Furthermore, the characteristics of the starting thermaldamage curve (locked rotor and acceleration) and the running thermal damage curves may not fit together very smoothly.In this instance, it may be necessary to use a custom curve to tailor protection to the motor thermal limits so the motor maybe started successfully and used to its full potential without compromising protection. The distinct parts of the thermal limitcurves now become more critical. For these conditions, it is recommended that the 369 custom curve thermal model beused. The custom overload curve of the 369 allows the user to program their own curve by entering trip times for 30 pre-determined current levels. The 369 smooths the areas between these points to make the protection curve.
It can be seen below that if the running overload thermal limit curve were smoothed into one curve with the locked rotoroverload curve, the motor could not start at 80% line voltage. A custom curve is required.
Figure 5–8: CUSTOM CURVE EXAMPLE
During the interval of discontinuity, the longer of the two trip times is used to reduce the chance of nui-sance tripping during motor starts.
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5.4.4 UNBALANCE BIAS
Unbalanced phase currents cause additional rotor heating not accounted for by electromechanical relays and may not beaccounted for in some electronic protective relays. When the motor is running, the rotor rotates in the direction of the posi-tive-sequence current at near synchronous speed. Negative-sequence current, having a phase rotation opposite to thepositive sequence current, and hence, opposite to the rotor rotation, generates a rotor voltage that produces a substantialrotor current. This induced current has a frequency approximately twice the line frequency: 100 Hz for a 50 Hz system,120 Hz for a 60 Hz system. Skin effect in the rotor bars at this frequency causes a significant increase in rotor resistance,and therefore a significant increase in rotor heating. This extra heating is not accounted for in the motor manufacturer ther-mal limit curves, since these curves assume positive-sequence currents only from a perfectly balanced supply and motordesign.
The 369 measures the percentage unbalance for the phase currents. The thermal model may be biased to reflect the addi-tional heating caused by negative-sequence current, present during an unbalance when the motor is running. This is doneby creating an equivalent motor heating current that takes into account the unbalanced current effect along with the aver-age phase current. This current is calculated as follows:
where: Ieq = equivalent unbalance biased heating currentIavg = average RMS phase current measuredUB% = unbalance percentage measured (100% = 1, 50% = 0.5, etc.)k = unbalance bias k factor
The figure on the left shows motor derating as a function of voltage unbalance as recommended by the American organiza-tion NEMA (National Electrical Manufacturers Association). Assuming a typical induction motor with an inrush of 6 × FLAand a negative sequence impedance of 0.167, voltage unbalances of 1, 2, 3, 4, and 5% equal current unbalances of 6, 12,18, 24, and 30% respectively. Based on this assumption, the figure on the right below illustrates the amount of motor derat-ing for different values of k entered for the setpoint UNBALANCE BIAS K FACTOR . Note that the curve for k = 8 is almostidentical to the NEMA derating curve.
Figure 5–9: MEDIUM MOTOR DERATING FACTOR DUE TO UNBALANCED VOLTAGE
If a k value of 0 is entered, the unbalance biasing is defeated and the overload curve will time out against the measured perunit motor current. The k value may be calculated as:
The 369 can also learn the unbalance bias k factor. It is recommended that the learned k factor not be enable until themotor has had at least five successful starts. The calculation of the learned k factor is as follows:
GE Power Management 369 Motor Management Relay 5-29
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5.4.5 MOTOR COOLING
The thermal capacity used quantity is reduced in an exponential manner when the motor is stopped or current is below theoverload pickup setpoint. This reduction simulates motor cooling. The motor cooling time constants should be entered forboth the stopped and running cases. A stopped motor will normally cool significantly slower than a running motor. Note thatthe cool time constant is one fifth the total cool time from 100% thermal capacity used down to 0% thermal capacity used.
The 369 can learn and estimate the stopped and running cool time constants for a motor. Calculation of a cool time con-stant is performed whenever the motor state transitions from starting to running or from running to stopped. The learnedcool times are based on the cooling rate of the hottest stator RTD, the hot/cold ratio, the ambient temperature (40 if noambient RTD), the measured motor load and the programmed service factor or overload pickup. Learned values shouldonly be enabled for motors that have been started, stopped and run at least five times.
Note that any learned cool time constants are mainly based on stator RTD information. Cool time, for starting, is typically arotor limit. The use of stator RTDs can only render an approximation. The learned values should only be used if the real val-ues are not available from the motor manufacturer. Motor cooling is calculated using the following formulas:
where: TCused = thermal capacity usedTCused_start = TC used value caused by overload conditionTCused_end = TC used value set by the hot/cold curve ratio when motor is running = '0' when motor is stopped.t = time in minutesτ = cool time constant (running or stopped)Ieq = equivalent motor heating currentoverload_pickup = overload pickup setpoint as a multiple of FLAhot/cold = hot/cold curve ratio
5.4.6 HOT/COLD CURVE RATIO
The motor manufacturer will sometimes provide thermal limit information for a hot/cold motor. The 369 thermal model willadapt for these conditions if the Hot/Cold Curve Ratio is programmed. The value entered for this setpoint dictates the levelof thermal capacity used that the relay will settle at for levels of current that are below the Overload Pickup Level. When themotor is running at a level that is below the Overload Pickup Level, the thermal capacity used will rise or fall to a valuebased on the average phase current and the entered Hot/Cold Curve Ratio. Thermal capacity used will either rise at a fixedrate of 5% per minute or fall as dictated by the running cool time constant.
where: TCused_end = Thermal Capacity Used if Iper_unit remains steady stateIeq = equivalent motor heating currenthot/cold = HOT/COLD CURVE RATIO setpoint
The hot/cold curve ratio may be determined from the thermal limit curves if provided or the hot and cold safe stall times.Simply divide the hot safe stall time by the cold safe stall time. If hot and cold times are not provided, there can be no differ-entiation and the hot/cold curve ratio should be entered as 1.00.
TCused TCused_start TCused_end–( ) e t– τ⁄( )⋅ TCused_end+=
5-30 369 Motor Management Relay GE Power Management
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Figure 5–10: THERMAL MODEL COOLING
5.4.7 RTD BIAS
The 369 thermal replica operates as a complete and independent model. The thermal overload curves however, are basedsolely on measured current, assuming a normal 40°C ambient and normal motor cooling. If there is an unusually high ambi-ent temperature, or if motor cooling is blocked, motor temperature will increase. If the motor stator has embedded RTDs,the 369 RTD bias feature should be used to correct the thermal model.
The RTD bias feature is a two part curve constructed using three points. If the maximum stator RTD temperature is belowthe RTD Bias Minimum setpoint (typically 40°C), no biasing occurs. If the maximum stator RTD temperature is above theRTD Bias Maximum setpoint (typically at the stator insulation rating or slightly higher), then the thermal memory is fullybiased and thermal capacity is forced to 100% used. At values in between, the present thermal capacity used created bythe overload curve and other elements of the thermal model is compared to the RTD Bias thermal capacity used from theRTD Bias curve. If the RTD Bias thermal capacity used value is higher, then that value is used from that point onward. TheRTD Bias Center point should be set at the rated running temperature of the motor. The 369 will automatically determinethe thermal capacity used value for the center point using the Hot/Cold Safe stall ratio setpoint.
At temperatures less than the RTD_Bias_Center temperature,
At temperatures greater than the RTD_Bias_Center temperature,
0
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d Cool Time Constant= 30 minTCused_start= 85%Hot/Cold Ratio= 80%Motor Stopped after running Rated LoadTCused_end= 0%
GE Power Management 369 Motor Management Relay 5-31
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where: RTD_Bias_TCused = TC used due to hottest stator RTDTactual = Actual present temperature of hottest stator RTDTmin = RTD Bias minimum setpoint (ambient temperature)Tcenter = RTD Bias center setpoint (motor running temperature)Tmax = RTD Bias max setpoint (winding insulation rating temperature)TCused@RTD_Bias_Center = TC used defined by HOT/COLD SAFE STALL RATIO setpoint
In simple terms, the RTD bias feature is real feedback of measured stator temperature. This feedback acts as correction ofthe thermal model for unforeseen situations. Since RTDs are relatively slow to respond, RTD biasing is good for correctionand slow motor heating. The rest of the thermal model is required during starting and heavy overload conditions whenmotor heating is relatively fast.
It should be noted that the RTD bias feature alone cannot create a trip. If the RTD bias feature forces the thermal capacityused to 100%, the motor current must be above the overload pickup before an overload trip occurs. Presumably, the motorwould trip on programmed stator RTD temperature setpoint at that time.
Figure 5–11: RTD BIAS CURVE
5.4.8 OVERLOAD ALARM
PATH: S3 OVERLOAD PROTECTION OVERLOAD ALARM
An overload alarm will occur only when the motor is running and the current rises above the programmed OVERLOADALARM LEVEL . The overload alarm is disabled during a start. An application of an unlatched overload alarm is to signal aPLC that controls the load on the motor, whenever the motor is too heavily loaded.
OVERLOAD ALARM OVERLOADALARM: Off
Range: Off, Latched, Unlatched
OVERLOAD ALARMLEVEL: 1.01 x FLA
Range: 1.01 to 1.50 in steps of 0.01
ASSIGN O/L ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, or combinations ofthem
5-32 369 Motor Management Relay GE Power Management
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5.5 S4 CURRENT ELEMENTS 5.5.1 SETPOINTS PAGE 4 MENU
These elements deal with functions that are based on the current readings of the 369 from the external phase and/orground CTs. All models of the 369 include these features.
5.5.2 SHORT CIRCUIT
PATH: S4 CURRENT ELEMENTS SHORT CIRCUIT
Care must be taken when turning on this feature. If the interrupting device (contactor or circuit breaker) isnot rated to break the fault current, this feature should be disabled. Alternatively, this feature may beassigned to an auxiliary relay and connected such that it trips an upstream device that is capable of break-ing the fault current.
Once the magnitude of either phase A, B, or C exceeds the Pickup Level × Phase CT Primary for a period of time specifiedby the delay, a trip will occur. Note the delay is in addition to the 45 ms instantaneous operate time.
There is also a backup trip feature that can be enabled. The backup delay should be greater than the short circuit delayplus the breaker clearing time. If a short circuit trip occurs with the backup on, and the phase current to the motor persistsfor a period of time that exceeds the backup delay, a second backup trip will occur. It is intended that this second trip beassigned to Aux1 or Aux2 which would be dedicated as an upstream breaker trip relay.
S4 SETPOINTSCURRENT ELEMENTS
SHORT CIRCUITSee page 5–32.
MECHANICAL JAMSee page 5–33.
UNDERCURRENTSee page 5–34.
CURRENT UNBALANCESee page 5–35.
GROUND FAULTSee page 5–36.
SHORT CIRCUIT SHORT CIRCUITTRIP: Off
Range: Off, Latched, Unlatched
ASSIGN TRIP RELAYS:Trip
Range: None, Trip, Aux1, Aux2, or combinations of them
SHORT CIRCUIT TRIPLEVEL: 10.0 x CT
Range: 2.0 to 20.0 x CT in steps of 0.1
ADD S/C TRIPDELAY: 0.00 s
Range: 0 to 255.00 s in steps of 0.010 = Instantaneous
GE Power Management 369 Motor Management Relay 5-33
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Various situations (e.g. charging a long line to the motor or power factor correction capacitors) may cause transient inrushcurrents during motor starting that may exceed the Short Circuit Pickup level for a very short period of time. The Short Cir-cuit time delay is adjustable in 10 ms increments. The delay can be fine tuned to an application such that it still respondsvery fast, but rides through normal operational disturbances. Normally, the Phase Short Circuit time delay will be set asquick as possible, 0 ms. Time may have to be increased if nuisance tripping occurs.
When a motor starts, the starting current (typically 6 × FLA for an induction motor) has an asymmetrical component. Thisasymmetrical current may cause one phase to see as much as 1.6 times the normal RMS starting current. If the short cir-cuit level was set at 1.25 times the symmetrical starting current, it is probable that there would be nuisance trips duringmotor starting. As a rule of thumb the short circuit protection is typically set to at least 1.6 times the symmetrical startingcurrent value. This allows the motor to start without nuisance tripping.
Both the main Short Circuit delay and the backup delay start timing when the current exceeds the Short CircuitPickup level.
5.5.3 MECHANICAL JAM
PATH: S4 CURRENT ELEMENTS MECHANICAL JAM
After a motor start, once the magnitude of any one of either phase A, B, or C exceeds the Trip/Alarm Pickup Level × FLA fora period of time specified by the Delay, a Trip/Alarm will occur. This feature may be used to indicate a stall condition whenrunning. Not only does it protect the motor by taking it off-line quicker than the thermal model (overload curve), it may alsoprevent or limit damage to the driven equipment that may occur if motor starting torque persists on jammed or brokenequipment.
The pickup level for the Mechanical Jam Trip should be set higher than motor loading during normal operations, but lowerthan the motor stall level. Normally the delay would be set to the minimum time delay, or set such that no nuisance tripsoccur due to momentary load fluctuations.
MECHANICAL JAM MECHANICAL JAMALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARM RELAYS:Alarm
Range: None, Alarm, Aux1, Aux2, or combinations ofthem
MECHANICAL JAM ALARMLEVEL: 1.50 x FLA
Range: 1.01 to 6.00 in steps of 0.01
MECHANICAL JAM ALARMDELAY: 1.0 s
Range: 0.5 to 125.0 s in steps of 0.5
MECHANICAL JAM ALARMEVENTS: Off
Range: On, Off
MECHANICAL JAMTRIP: Off
Range: Off, Latched, Unlatched
ASSIGN TRIP RELAYS:Trip
Range: None, Trip, Aux1, Aux2, or combinations of them
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5.5.4 UNDERCURRENT
PATH: S4 CURRENT ELEMENTS UNDERCURRENT
If enabled, once the magnitude of either phase A, B or C falls below the pickup level × FLA for a period of time specified bythe Delay, a trip or alarm will occur. The undercurrent element is an indication of loss of load to the motor. Thus, the pickuplevel should be set lower than motor loading levels during normal operations. The undercurrent element is active when themotor is starting or running.
The undercurrent element can be blocked upon the initiation of a motor start for a period of time specified by the U/C BlockFrom Start setpoint (e.g. this block may be used to allow pumps to build up head before the undercurrent element trips). Avalue of 0 means undercurrent protection is immediately enabled upon motor starting (no block). If a value other than 0 isentered, the feature will be disabled from the time a start is detected until the time entered expires.
APPLICATION EXAMPLE:
If a pump is cooled by the liquid it pumps, loss of load may cause the pump to overheat. Undercurrent protection shouldthus be enabled. If the motor loading should never fall below 0.75 × FLA, even for short durations, the Undercurrent Trippickup could be set to 0.70 and the Undercurrent Alarm to 0.75. If the pump is always started loaded, the block from startfeature should be disabled (programmed as 0).
Time delay is typically set as quick as possible, 1 second.
UNDERCURRENT BLOCK UNDERCURRENTFROM START: 0 s
Range: 0 to 15000 s in steps of 1
UNDERCURRENTALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARM RELAYS:Alarm
Range: None, Alarm, Aux1, Aux2, or combinations ofthem
UNDERCURRENT ALARMLEVEL: 0.70 x FLA
Range: 0.10 to 0.99 in steps of 0.01
UNDERCURRENT ALARMDELAY: 1 s
Range: 1 to 255 s in steps of 1
UNDERCURRENT ALARMEVENTS: Off
Range: On, Off
UNDERCURRENTTRIP: Off
Range: Off, Latched, Unlatched
ASSIGN TRIP RELAYS:Trip
Range: None, Trip, Aux1, Aux2, or combinations of them
GE Power Management 369 Motor Management Relay 5-35
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5.5.5 CURRENT UNBALANCE
PATH: S4 CURRENT ELEMENTS CURRENT UNBALANCE
Unbalanced three phase supply voltages are a major cause of induction motor thermal damage. Causes of unbalance caninclude: increased resistance in one phase due to a pitted or faulty contactor, loose connections, unequal tap settings in atransformer, non-uniformly distributed three phase loads, or varying single phase loads within a plant. The most seriouscase of unbalance is single phasing – that is, the complete loss of one phase. This can be caused by a utility supply prob-lem or a blown fuse in one phase and can seriously damage a three phase motor. A single phase trip will occur in 2 sec-onds if the Unbalance trip is on and the level exceeds 30%. A single phase trip will also activate if the Motor Load is above30% and at least one of the phase currents is zero. Single phasing protection is disabled if the Unbalance Trip is turned Off.
During balanced conditions in the stator, current in each motor phase is equal, and the rotor current is just sufficient to pro-vide the turning torque. When the stator currents are unbalanced, a much higher current is induced into the rotor due to itslower impedance to the negative sequence current component present. This current is at twice the power supply frequencyand produces a torque in the opposite direction to the desired motor output. Usually the increase in stator current is smalland timed overcurrent protection takes a long time to trip. However, the much higher induced rotor current can cause exten-sive rotor damage in a short period of time. Motors can tolerate different levels of current unbalance depending on the rotordesign and heat dissipation characteristics.
To prevent nuisance trips/alarms on lightly loaded motors when a much larger unbalance level will not damage the rotor,the unbalance protection will automatically be defeated if the average motor current is less than 30% of the full load current(IFLA) setting. Unbalance is calculated as follows:
where: Iavg = average phase currentImax = current in a phase with maximum deviation from IavgIFLA = motor full load amps setting
CURRENT UNBALANCE BLOCK UNBALANCE FROMSTART: 0 s
Range: 0 to 5000 s in steps of 1
CURRENT UNBALANCEALARM: Off
Range: Off, Latched, Unlatched
ASSIGN ALARM RELAYS:Alarm
Range: None, Alarm, Aux1, Aux2, or combinations ofthem
UNBALANCE ALARMLEVEL: 15 %
Range: 4 to 30% in steps of 1
UNBALANCE ALARMDELAY: 1 s
Range: 1 to 255 s in steps of 1
UNBALANCE ALARMEVENTS: Off
Range: On, Off
CURRENT UNBALANCETRIP: Off
Range: Off, Latched, Unlatched
ASSIGN TRIP RELAYS:Trip
Range: None, Trip, Aux1, Aux2, or combinations of them
UNBALANCE TRIPLEVEL: 20 %
Range: 4 to 30% in steps of 1
UNBALANCE TRIPDELAY: 1 s
Range: 1 to 255 s in steps of 1
If Iavg IFLA, Unbalance≥Imax Iavg–
Iavg----------------------------- 100×= If Iavg IFLA, Unbalance<
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Unbalance protection is recommended at all times. When setting the unbalance pickup level, it should be noted that a 1%voltage unbalance typically translates into a 6% current unbalance. Therefore, in order to prevent nuisance trips or alarms,the pickup level should not be set too low. Also, since short term unbalances are common, a reasonable delay should beset to avoid nuisance trips or alarms. It is recommended that the unbalance thermal bias feature be used to bias the Ther-mal Model to account for rotor heating that may be caused by cyclic short term unbalances.
5.5.6 GROUND FAULT
PATH: S4 CURRENT ELEMENTS GROUND FAULT
Once the magnitude of ground current exceeds the Pickup Level for a period of time specified by the Delay, a trip and/oralarm will occur. There is also a backup trip feature that can be enabled. If the backup is On, and a Ground Fault trip hasinitiated, and the ground current persists for a period of time that exceeds the backup delay, a second ‘backup’ trip willoccur. It is intended that this second trip be assigned to Aux1 or Aux2 which would be dedicated as an upstream breakertrip relay. The Ground Fault Trip Backup delay must be set to a time longer than the breaker clearing time.
Care must be taken when turning On this feature. If the interrupting device (contactor or circuit breaker)is not rated to break ground fault current (low resistance or solidly grounded systems), the featureshould be disabled. Alternately, the feature may be assigned to an auxiliary relay and connected suchthat it trips an upstream device that is capable of breaking the fault current.
GROUND FAULT GROUND FAULTALARM: Off
Range: Off, Latched, Unlatched
ASSIGN G/F ALARMRELAYS: Alarm
Range: None, Alarm, Aux1, Aux2, or combinations ofthem
GROUND FAULT ALARMLEVEL: 0.10 x CT
Range: 0.10 to 1.00 x CT in steps of 0.01Only shown if G/F CT is 1A or 5A
GROUND FAULT ALARMLEVEL: 0.25 A
Range:0.25 to 25.00 A in steps of 0.01Only shown if G/F CT is 50:0.025
GROUND FAULT ALARMDELAY: 0.00 s
Range: 0.00 to 255.00 s in steps of 0.01s
GROUND FAULT ALARMEVENTS: Off
Range: On, Off
GROUND FAULTTRIP: Off
Range: Off, Latched, Unlatched
ASSIGN TRIP RELAYS:Trip
Range: None, Trip, Aux1, Aux2, or combinations of them
GROUND FAULT TRIPLEVEL: 0.20 x CT
Range: 0.10 to 1.00 x CT in steps of 0.01Only shown if G/F CT is 1A or 5A
GROUND FAULT TRIPLEVEL: 0.25 A
Range: 0.25 to 25.00 A in steps of 0.01Only shown if G/F CT is 50:0.025
GE Power Management 369 Motor Management Relay 5-37
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Various situations (e.g. contactor bounce) may cause transient ground currents during motor starting that may exceed theGround Fault Pickup levels for a very short period of time. The delay can be fine tuned to an application such that it stillresponds very fast, but rides through normal operational disturbances. Normally, the Ground Fault time delays will be set asquick as possible, 0 ms. Time may have to be increased if nuisance tripping occurs.
Special care must be taken when the ground input is wired to the phase CTs in a residual connection. When a motor starts,the starting current (typically 6 × FLA for an induction motor) has an asymmetrical component. This asymmetrical currentmay cause one phase to see as much as 1.6 times the normal RMS starting current. This momentary DC component willcause each of the phase CTs to react differently and the net current into the ground input of the 369 will not be negligible. A20 ms block of the ground fault elements when the motor starts enables the 369 to ride through this momentary ground cur-rent signal.
Both the main Ground Fault delay and the backup delay start timing when the Ground Fault current exceeds thepickup level.
5-38 369 Motor Management Relay GE Power Management
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5.6 S5 MOTOR START / INHIBITS 5.6.1 SETPOINTS PAGE 5 MENU
These setpoints deal with those functions that prevent the motor from restarting once stopped until a set condition clearsand/or a set time expires. None of these functions will trip a motor that is already running.
5.6.2 ACCELERATION TRIP
PATH: S5 MOTOR START/INHIBITS ACCELERATION TRIP
The 369 Thermal Model is designed to protect the motor under both starting and overload conditions. The AccelerationTimer trip feature may be used in addition to that protection. If for example, the motor should always start in 2 seconds, butthe safe stall time is 8 seconds, there is no point letting the motor remain in a stall condition for 7 or 8 seconds when thethermal model would take it off line. Furthermore, the starting torque applied to the driven equipment for that period of timecould cause severe damage.
If enabled, the Acceleration Timer trip element will function as follows: A motor start is assumed to be occurring when the369 measures the transition of no motor current to some value of motor current. Typically current will rise quickly to a valuein excess of FLA (e.g. 6 x FLA). At this point, the Acceleration Timer will be initialized with the entered value in seconds. Ifthe current does not fall below the overload curve pickup level before the timer expires, an acceleration trip will occur. If theacceleration time of the motor is variable, this feature should be set just beyond the longest acceleration time.
Some motor soft starters may allow current to ramp up slowly while others may limit current to less thanFull Load Amps throughout the start. In these cases, as a generic relay that must protect all motors, the369 cannot differentiate between a motor that has a slow ramp up time and one that has completed a startand gone into an overload condition. Therefore, if the motor current does not rise to greater than full loadwithin 1 second on start, the acceleration timer feature is ignored. In any case, the motor is still protectedby the overload curve.
S5 SETPOINTSMOTOR START/INHIBITS
ACCELERATION TRIPSee page 5–38.
START INHIBITSSee page 5–39.
BACKSPIN DETECTION See page 5–40.Only shown if option B installed
ACCELERATION TRIP ACCELERATIONTRIP: Off
Range: Off, Latched, Unlatched
ASSIGN TRIP RELAYS:Trip
Range: None, Trip, Aux1, Aux2, or combinations of them
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5.6.3 START INHIBITS
PATH: S5 MOTOR START/INHIBITS START INHIBITS
SINGLE SHOT RESTART: Enabling this feature will allow the motor to be restarted immediately after an overload trip hasoccurred. To accomplish this, a reset will cause the 369 to decrease the accumulated thermal capacity to zero. However, ifa second overload trip occurs within one hour of the first, another immediate restart will not be permitted. The displayedlockout time must then be allowed to expire before the motor can be started.
START INHIBIT: The Start Inhibit feature is intended to help prevent tripping of the motor during a start if there is insufficientthermal capacity for a start. The average value of thermal capacity used from the last five successful starts is multiplied by1.25 and stored as thermal capacity used on start. This 25% margin is used to ensure that a motor start will be successful.If the number is greater than 100%, 100% is stored as thermal capacity used on start. A successful motor start is one inwhich phase current rises from 0 to greater than overload pickup and then, after acceleration, falls below the overloadcurve pickup level. If the Start Inhibit feature is enabled, each time the motor is stopped, the amount of thermal capacityavailable (100% – Thermal Capacity Used) is compared to the THERMAL CAPACITY USED ON START . If the thermal capac-ity available does not exceed the THERMAL CAPACITY USED ON START , or is not equal to 100%, the Start Inhibit willbecome active until there is sufficient thermal capacity. When an inhibit occurs, the lockout time will be equal to the timerequired for the motor to cool to an acceptable temperature for a start. This time will be a function of the COOL TIME CON-STANT STOPPED programmed. If this feature is turned Off, thermal capacity used must reduce to 15% before an overloadlockout resets. This feature should be turned off if the load varies for different starts.
MAX STARTS/HOUR PERMISSIBLE: A motor start is assumed to be occurring when the 369 measures the transition of nomotor current to some value of motor current. At this point, one of the STARTS/HOUR timers is loaded with 60 minutes.Even unsuccessful start attempts will be logged as starts for this feature. Once the motor is stopped, the number of startswithin the past hour is compared to the number of starts allowable. If the two are the same, an inhibit will occur. If an inhibitoccurs, the lockout time will be equal to one hour less the longest time elapsed since a start within the past hour. An Emer-gency restart will clear the oldest start time remaining.
TIME BETWEEN STARTS: A motor start is assumed to be occurring when the 369 measures the transition of no motor cur-rent to some value of motor current. At this point, the Time Between Starts timer is loaded with the entered time. Evenunsuccessful start attempts will be logged as starts for this feature. Once the motor is stopped, if the time elapsed since themost recent start is less than the TIME BETWEEN STARTS setpoint, an inhibit will occur. If an inhibit occurs, the lockout timewill be equal to the time elapsed since the most recent start subtracted from the TIME BETWEEN STARTS setpoint.
RESTART BLOCK: Restart Block may be used to ensure that a certain amount of time passes between stopping a motorand restarting that motor. This timer feature may be very useful for some process applications or motor considerations. If amotor is on a down-hole pump, after the motor stops, the liquid may fall back down the pipe and spin the rotor backwards.It would be very undesirable to start the motor at this time. In another scenario, a motor may be driving a very high inertiaload. Once the supply to the motor is disconnected, the rotor may continue to turn for a long period of time as it decelerates.The motor has now become a generator and applying supply voltage out of phase may result in catastrophic failure.
ASSIGN INHIBIT RELAY: The relay(s) assigned here will be used for all blocking/inhibit elements in this section. Theassigned relay will activate only when the motor is stopped. When a block/inhibit condition times out or is cleared, theassigned relay will automatically reset itself.
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NOTES FOR ALL INHIBITS AND BLOCKS:
1. In the event of control power loss, all lockout times will be saved. Elapsed time will be recorded and decremented fromthe inhibit times whether control power is applied or not. Upon control power being re-established to the 369, allremaining inhibits (have not time out) will be re-activated.
2. If the motor is started while an inhibit is active an event titled ‘Start while Blocked’ will be recorded.
5.6.4 BACKSPIN DETECTION
PATH: S5 MOTOR START/INHIBITS BACKSPIN DETECTION
Immediately after the motor is stopped, backspin detection commences and a backspin start inhibit is activated to preventthe motor from being restarted. The backspin frequency is sensed through the BSD voltage input. If the measured fre-quency is below the programmed Minimum Permissible Frequency, the backspin start inhibit will be removed. The time forthe motor to reach the Minimum Permissible Frequency is calculated throughout the backspin state. If the BSD frequencysignal is lost prior to reaching the Minimum Permissible Frequency, the inhibit remains active until the predication time hasexpired. The calculated Predication Time and the Backspin State can be viewed in Voltage metering section of Actual Val-ues page 2.
APPLICATION:
Backspin protection is typically used on down hole pump motors which can be located several kilometers underground.Check valves are often used to prevent flow reversal when the pump stops. Very often however, the flow reverses due tofaulty or non existent check valves, causing the pump impeller to rotate the motor in the reverse direction. Starting themotor during this period of reverse rotation (back-spinning) may result in motor damage. Backspin detection ensures thatthe motor can only be started when the motor has slowed to within acceptable limits. Without backspin detection a longtime delay had to be used as a start permissive to ensure the motor had slowed to a safe speed.
These setpoints are only visible when option B has been installed.
BACKSPIN DETECTION ENABLE BACKSPINSTART INHIBIT: No
Range: No, YesOnly shown if B option installed
MINIMUM PERMISSIBLEFREQUENCY: 0.00 Hz
Range: 0 to 9.99 Hz in steps of 0.01Shown only if backspin start inhibit is enabled
PREDICTION ALGORITHMEnabled
Range: Disabled, EnabledShown only if backspin start inhibit is enabled
ASSIGN BSD RELAY:Aux2
Range: None, Trip, Aux1, Aux2, or combinationsSeen only if backspin start inhibit is enabled
NUM OF MOTOR POLES:2
Range: 2 to 16 in steps of 2Shown only if backspin start inhibit is enabled
GE Power Management 369 Motor Management Relay 5-41
5 SETPOINTS 5.7 S6 RTD TEMPERATURE
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5.7 S6 RTD TEMPERATURE 5.7.1 SETPOINTS PAGE 6 MENU
These setpoints deal with the RTD overtemperature elements of the 369. The Local RTD Protection setpoints will only beseen if the 369 has option R installed. The Remote RTD Protection setpoints will only be seen if the 369 has the RRTDaccessory enabled. Both can be enabled and used at the same time and have the same functionality.
5.7.2 LOCAL RTD PROTECTION
PATH: S6 RTD TEMPERATURE LOCAL RTD PROTECTION
S6 SETPOINTSRTD TEMPERATURE
LOCAL RTDPROTECTION
See page 5–41.
REMOTE RTDPROTECTION
See page 5–42.
REMOTE RTD MODULE 1
REMOTE RTD MODULE 2
REMOTE RTD MODULE 3
REMOTE RTD MODULE 4
OPEN RTD ALARMSee page 5–44.
SHORT/LOW TEMP RTDALARM
See page 5–45.
LOSS OF RRTDCOMMS ALARM
See page 5–45.
LOCAL RTDPROTECTION
LOCAL RTD 1
RTD 1 APPLICATION:None
Range: None, Stator, Bearing, Ambient, Other
RTD 1 TYPE:100 Ohm Platinum
Range: 10 Ohm Copper, 100 Ohm Nickel, 120Ohm Nickel, 100 Ohm Platinum; seen only ifRTD 1 Application is other than None.
RTD 1 NAME:RTD 1
Range: 8 character alphanumeric; seen only ifRTD 1 Application is other than None.
RTD 1 ALARM:Off
Range: Off, Latched, Unlatched; seen only ifRTD 1 Application is other than None.
RTD 1 ALARM RELAYS:Alarm
Range: None, Alarm, Aux1, Aux2, orcombinations; seen only if RTD 1Application is other than None.
RTD 1 ALARMLEVEL: 130 °C
Range: 1 to 200°C in steps of 134 to 392°F in steps of 1;
only if RTD 1 Application is other than None.
RTD 1 HI ALARM:Off
Range: Off, Latched, Unlatched; seen only ifRTD 1 Application is other than None.
GE Power Management 369 Motor Management Relay 5-43
5 SETPOINTS 5.7 S6 RTD TEMPERATURE
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APPLICATION: Each individual RTD may be assigned an application. A setting of "None" turns an individual RTD off. OnlyRTDs with the application set to "Stator" are used for RTD biasing of the thermal model. If an RTD application is set to"Ambient", then its is used in calculating the learned cool time of the motor.
TYPE: Each RTD is individually assigned the RTD type it is connected to. Multiple types may be used with a single 369.
NAME: Each RTD may have 8 character name assigned to it. This name is used in alarm and trip messages.
ALARM / HI ALARM / TRIP: Each RTD can be programmed for separate Alarm, Hi Alarm and Trip levels and relays. Tripsare automatically stored as events. Alarms and Hi Alarms are stored as events only if the Record Alarms as Events set-point for that RTD is set to Yes.
TRIP VOTING: This feature provides added RTD trip reliability in situations where malfunction and nuisance tripping iscommon. If enabled, the RTD trips only if the RTD (or RTDs) to be voted with are also above their trip level. For example, ifRTD 1 is set to vote with All Stator RTDs, the 369 will only trip if RTD 1 is above its trip level and any one of the other statorRTDs is also above its own trip level. RTD voting is typically only used on Stator RTDs and typically done between adjacentRTDs to detect hot spots.
Stator RTDs can detect heating due to non overload (current) conditions such as blocked or inadequate cooling and venti-lation or high ambient temperature as well as heating due to overload conditions. Bearing or other RTDs can detect over-heating of bearings or auxiliary equipment.
RRTD1 HI ALARMRELAY: Aux1
Range: None, Alarm, Aux1, Aux2, or combinationsSeen only if RRTD 1 Application is other than None
RRTD 1 HI ALARMLEVEL: 130 °C
Range: 1 to 200°C or 34 to 392°F in steps of 1Seen only if RRTD 1 Application is other than None
RECORD RRTD 1 ALARMSAS EVENTS: No
Range: No, YesSeen only if RRTD 1 Application is other than None
RRTD 1 TRIP:Off
Range: Off, Latched, UnlatchedSeen only if RRTD 1 Application is other than None
RRTD 1 TRIP RELAYS:Trip
Range: None, Trip, Aux1, Aux2, or combinationsSeen only if RRTD 1 Application is other than None
RRTD 1 TRIPLEVEL: 130 °C
Range: 1 to 200°C or 34 to 392°F in steps of 1Seen only if RRTD 1 Application is other than None
ENABLE RRTD 1 TRIPVOTING: Off
Range: Off, RRTD 1 to 12, All StatorSeen only if RRTD 1 Application is other than None
5-44 369 Motor Management Relay GE Power Management
5.7 S6 RTD TEMPERATURE 5 SETPOINTS
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5.7.4 OPEN RTD ALARM
PATH: S6 RTD TEMPERATURE OPEN RTD ALARM
The 369 has an Open RTD Sensor Alarm. This alarm will look at all RTDs that have been assigned an application otherthan "None" and determine if an RTD connection has been broken. When a broken sensor is detected, the assigned outputrelay will operate and a message will appear on the display identifying the RTD that is broken. It is recommended that if thisfeature is used, the alarm be programmed as latched so that intermittent RTDs are detected and corrective action may betaken.
GE Power Management 369 Motor Management Relay 5-45
5 SETPOINTS 5.7 S6 RTD TEMPERATURE
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5.7.5 SHORT/LOW TEMP RTD ALARM
PATH: S6 RTD TEMPERATURE SHORT/LOW TEMP RTD ALARM
The 369 has an RTD Short/Low Temperature alarm. This function tracks all RTDs that have an application other than"None" to determine if an RTD has either a short or a very low temperature (less than –40°C). When a short/low tempera-ture is detected, the assigned output relay will operate and a message will appear on the display identifying the RTD thatcaused the alarm. It is recommended that if this feature is used, the alarm be programmed as latched so that intermittentRTDs are detected and corrective action may be taken.
5.7.6 LOSS OF RRTD COMMS ALARM
PATH: S6 RTD TEMPERATURE LOSS OF RRTD COMMS ALARM
The 369, if connected to a RRTD module, will monitor communications between them. If for some reason communicationsis lost or interrupted the 369 can issue an alarm indicating the failure. This feature is useful to ensure that the remote RTDsare continuously being monitored.
5-46 369 Motor Management Relay GE Power Management
5.8 S7 VOLTAGE ELEMENTS 5 SETPOINTS
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5.8 S7 VOLTAGE ELEMENTS 5.8.1 SETPOINTS PAGE 7 MENU
These elements are not used by the 369 unless the M or B option is installed and the VT CONNECTION TYPE setpoint (seeSection 5.3.2: CT/VT SETUP on page 5–11) is set to something other than "None".
GE Power Management 369 Motor Management Relay 5-47
5 SETPOINTS 5.8 S7 VOLTAGE ELEMENTS
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If enabled, an undervoltage trip or alarm occurs once the magnitude of either Vab, Vbc, or Vca falls below the runningpickup level while running or the starting pickup level while starting, for a period of time specified by the alarm or trip delay(pickup levels are multiples of motor nameplate voltage).
An undervoltage on a running motor with a constant load results in increased current. The relay thermal model typicallypicks up this condition and provides adequate protection. However, this setpoint may be used in conjunction with time delayto provide additional protection that may be programmed for advance warning by tripping.
The U/V ACTIVE IF MOTOR STOPPED setpoint may be used to prevent nuisance alarms or trips when the motor is stopped.If "No" is programmed the undervoltage element will be blocked from operating whenever the motor is stopped (no phasecurrent and starter status indicates breaker or contactor open). If the load is high inertia, it may be desirable to ensure thatthe motor is tripped off line or prevented from starting in the event of a total loss or decrease in line voltage. Programming"Yes" for the block setpoint will ensure that the motor is tripped and may be restarted only after the bus is re-energized.
APPLICATION:
An undervoltage of significant proportion that persists while starting a synchronous motor may prevent the motor from com-ing up to rated speed within the rated time. An undervoltage may be an indication of a system fault. To protect a synchro-nous motor from being restarted while out of step it may be necessary to use undervoltage to take the motor offline beforea reclose is attempted.
5.8.3 OVERVOLTAGE
PATH: S7 VOLTAGE ELEMENTS OVERVOLTAGE
If enabled, once the magnitude of either Vab, Vbc, or Vca rises above the Pickup Level for a period of time specified by theDelay, a trip or alarm will occur (pickup levels are multiples of motor nameplate voltage).
An overvoltage on running motor with a constant load will result in decreased current. However, iron and copper lossesincrease, causing an increase in motor temperature. The current overload relay will not pickup this condition and provideadequate protection. Therefore, the overvoltage element may be useful for protecting the motor in the event of a sustainedovervoltage condition.
The Undervoltage and Overvoltage alarms and trips are activated based upon the phase to phase voltageregardless of the VT connection type.
5-48 369 Motor Management Relay GE Power Management
5.8 S7 VOLTAGE ELEMENTS 5 SETPOINTS
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5.8.4 PHASE REVERSAL
PATH: S7 VOLTAGE ELEMENTS PHASE REVERSAL
The 369 can detect the phase rotation of the three phase voltage. If the phase reversal feature is turned on when all 3phase voltages are greater than 50% motor nameplate voltage and the phase rotation of the three phase voltages is not thesame as the setpoint, a trip and block start will occur in 500 ms to 700 ms.
5.8.5 UNDERFREQUENCY
PATH: S7 VOLTAGE ELEMENTS UNDERFREQUENCY
Once the frequency of the phase AN or AB voltage (depending on wye or delta connection) falls below the underfrequencypickup level, a trip or alarm will occur.
APPLICATION:
This feature may be useful for load shedding applications on large motors. It could also be used to load shed an entirefeeder if the trip was assigned to an upstream breaker. Underfrequency can also be used to detect loss of power to a syn-chronous motor. Due to motor generation, sustained voltage may prevent quick detection of power loss. Therefore, toquickly detect the loss of system power, the decaying frequency of the generated voltage as the motor slows can be used.
The Underfrequency element is not active when the motor is stopped.
GE Power Management 369 Motor Management Relay 5-49
5 SETPOINTS 5.8 S7 VOLTAGE ELEMENTS
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5.8.6 OVERFREQUENCY
PATH: S7 VOLTAGE ELEMENTS OVERFREQUENCY
Once the frequency of the phase AN or AB voltage (depending on wye or delta connection) rises above the overfrequencypickup level, a trip or alarm will occur.
APPLICATION:
This feature may be useful for load shedding applications on large motors. It could also be used to load shed an entirefeeder if the trip was assigned to an upstream breaker.
The Overfrequency element is not active when the motor is stopped.
5-50 369 Motor Management Relay GE Power Management
5.9 S8 POWER ELEMENTS 5 SETPOINTS
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5.9 S8 POWER ELEMENTS 5.9.1 SETPOINTS PAGE 8 MENU
These protective elements rely on CTs and VTs being installed and setpoints programmed. The power elements are onlyshown if the 369 has option M or B installed. By convention, an induction motor consumes Watts and vars. This condition isdisplayed on the 369 as +Watts and +vars. A synchronous motor can consume Watts and vars or consume Watts and gen-erate vars. These conditions are displayed on the 369 as +Watts, +vars, and +Watts, –vars respectively.
GE Power Management 369 Motor Management Relay 5-51
5 SETPOINTS 5.9 S8 POWER ELEMENTS
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5.9.2 LEAD POWER FACTOR
PATH: S8 POWER ELEMENTS LEAD POWER FACTOR
If the 369 is applied on a synchronous motor, it is desirable not to trip or alarm on power factor until the field has beenapplied. Therefore, this feature can be blocked until the motor comes up to speed and the field is applied. From that pointforward, the power factor trip and alarm elements will be active. Once the power factor is less than the lead level, for thespecified delay, a trip or alarm will occur indicating a lead condition.
The lead power factor alarm can be used to detect over-excitation or loss of load.
5-52 369 Motor Management Relay GE Power Management
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If the 369 is applied on a synchronous motor, it is desirable not to trip or alarm on power factor until the field has beenapplied. Therefore, this feature can be blocked until the motor comes up to speed and the field is applied. From that pointforward, the power factor trip and alarm elements will be active. Once the power factor is less than the lag level, for thespecified delay, a trip or alarm will occur indicating lag condition.
The power factor alarm can be used to detect loss of excitation and out of step for a synchronous motor.
5.9.4 POSITIVE REACTIVE POWER
PATH: S8 POWER ELEMENTS POSITIVE REACTIVE POWER
If the 369 is applied on a synchronous motor, it is desirable not to trip or alarm on kvar until the field has been applied.Therefore, this feature can be blocked until the motor comes up to speed and the field is applied. From that point forward,the kvar trip and alarm elements will be active. Once the kvar level exceeds the positive level, for the specified delay, a tripor alarm will occur indicating a positive kvar condition. The reactive power alarm can be used to detect loss of excitationand out of step.
GE Power Management 369 Motor Management Relay 5-53
5 SETPOINTS 5.9 S8 POWER ELEMENTS
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5.9.5 NEGATIVE REACTIVE POWER
PATH: S8 POWER ELEMENTS NEGATIVE REACTIVE POWER
When using the 369 on a synchronous motor, it is desirable not to trip or alarm on kvar until the field has been applied. Assuch, this feature can be blocked until the motor comes up to speed and the field is applied. From that point forward, thekvar trip and alarm elements will be active. Once the kvar level exceeds the negative level for the specified delay, a trip oralarm occurs, indicating a negative kvar condition. The reactive power alarm can be used to detect overexcitation or loss ofload.
5-54 369 Motor Management Relay GE Power Management
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If enabled, a trip or alarm occurs when the magnitude of 3∅ total real power falls below the pickup level for a period of timespecified by the delay. The underpower element is active only when the motor is running and will be blocked upon the initi-ation of a motor start for a period of time defined by the BLOCK UNDERPOWER FROM START setpoint (e.g. this block may beused to allow pumps to build up head before the underpower element trips or alarms). A value of 0 means the feature is notblocked from start; otherwise the feature is disabled when the motor is stopped and also from the time a start is detecteduntil the time entered expires. The pickup level should be set lower than motor loading during normal operations.
Underpower may be used to detect loss of load conditions. Loss of load conditions will not always cause a significant lossof current. Power is a more accurate representation of loading and may be used for more sensitive detection of load loss orpump cavitation. This may be especially useful for detecting process related problems.
5.9.7 REVERSE POWER
PATH: S8 POWER ELEMENTS REVERSE POWER
If enabled, once the magnitude of 3∅ total real power exceeds the pickup level in the reverse direction (negative kW) for aperiod of time specified by the delay, a trip or alarm will occur.
The minimum magnitude of power measurement is determined by the phase CT minimum of 5% rated CTprimary. If the level for reverse power is set below that level, a trip or alarm will only occur once the phasecurrent exceeds the 5% cutoff.
GE Power Management 369 Motor Management Relay 5-55
5 SETPOINTS 5.10 S9 DIGITAL INPUTS
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5.10 S9 DIGITAL INPUTS 5.10.1 SETPOINTS PAGE 9 MENU
The Access switch is predefined and is non programmable.
5.10.2 SPARE SWITCH
PATH: S9 DIGITAL INPUTS SPARE SWITCH
See Section 5.10.7: DIGITAL INPUT FUNCTIONS on page 5–57 for an explanation of the spare switch functions.
In addition to the normal selections, the Spare Switch may be used as a starter status contact input. An auxiliary ‘a’ typecontact follows the state of the main contactor or breaker and an auxiliary ‘b’ type contact is in the opposite state. This fea-ture is recommended for use on all motors. It is essential for proper operation of start inhibits (i.e., Starts/Hour, TimeBetween Starts, Start Inhibit, Restart Block, Backspin Start Inhibit), especially when the motor may be run lightly orunloaded.
A motor stop condition is detected when the current falls below 5% of CT. When SPARE SWITCH is programmed as "StarterStatus", motor stop conditions are detected when the current falls below 5% of CT and the breaker is open. Enabling theStarter Status and wiring the breaker contactor to the Spare Switch eliminates nuisance lockouts initiated by the 369 if themotor (synchronous or induction) is running unloaded or idling, and if the STARTS/HOUR, TIME BETWEEN STARTS , STARTINHIBIT, RESTART BLOCK , and BACKSPIN START INHIBIT are programmed.
5.10.3 EMERGENCY RESTART
PATH: S9 DIGITAL INPUTS EMERGENCY RESTART
See Section 5.10.7: DIGITAL INPUT FUNCTIONS on page 5–57 for an explanation of the emergency restart functions. Inaddition to the normal selections, the Emergency Restart Switch may be used as a emergency restart input to the 369 tooverride protection for the motor.
When the emergency restart switch is closed all trip and alarm functions are reset. Thermal capacity used is set to zero andall protective elements are disabled until the switch is opened. Starts per hour are also reduced by one each time the switchis closed.
S9 SETPOINTSDIGITAL INPUTS
SPARE SWITCHSee page 5–55.
EMERGENCY RESTARTSee page 5–55.
DIFFERENTIAL SWITCHSee page 5–56.
SPEED SWITCHSee page 5–56.
REMOTE RESETSee page 5–56.
SPARE SWITCH SPARE SW FUNCTION:Off
Range: Off, Starter Status, General, Digital Counter,Waveform Capture, Simulate Pre-Fault, SimulateFault, Simulate Pre-Fault to Fault
STARTER AUX CONTACTTYPE: 52a
Range: 52a, 52bOnly seen if function is Starter Status
5-56 369 Motor Management Relay GE Power Management
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5.10.4 DIFFERENTIAL SWITCH
PATH: S9 DIGITAL INPUTS DIFFERENTIAL SWITCH
See Section 5.10.7: DIGITAL INPUT FUNCTIONS on page 5–57 for an explanation of differential switch functions.
In addition to the normal selections, the Differential Switch may be used as a contact input for a separate external 86 (differ-ential trip) relay. Contact closure will cause the 369 relay to issue a differential trip.
5.10.5 SPEED SWITCH
PATH: S9 DIGITAL INPUTS SPEED SWITCH
See Section 5.10.7: DIGITAL INPUT FUNCTIONS on page 5–57 for an explanation of speed switch functions.
In addition to the normal selections, the Speed Switch may be used as an input for an external speed switch. This allowsthe 369 to utilize a speed device for locked rotor protection. During a motor start, if no contact closure occurs within the pro-grammed time delay, a trip will occur. The speed input must be opened for a speed switch trip to be reset.
5.10.6 REMOTE RESET
PATH: S9 DIGITAL INPUTS REMOTE RESET
See Section 5.10.7: DIGITAL INPUT FUNCTIONS on page 5–57 for an explanation of remote reset functions.
In addition to the normal selections, the Remote Reset may be used as a contact input to reset the relay.
GE Power Management 369 Motor Management Relay 5-57
5 SETPOINTS 5.10 S9 DIGITAL INPUTS
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5.10.7 DIGITAL INPUT FUNCTIONS
a) GENERAL
Any of the programmable digital inputs may be selected and programmed as a separate General Switch Input.
xxxxx refers to the configurable switch input name which includes Spare, Emergency, Differential, Speed, or RemoteReset
b) DIGITAL COUNTER
Only one digital input may be selected as a digital counter at a time. User defined units and counter name may be definedand these will appear on all counter related actual value and alarm messages. To clear a digital counter alarm, the alarmlevel must be increased or the counter must be cleared or preset to a lower value.
xxxxx SW FUNCTION:General
GENERAL SWITCHNAME: General
Range: 12 character alphanumericOnly seen if function is selected as General
GENERAL SWITCHTYPE: NO
Range: NO (normally open), NC (normally closed)Only seen if function is selected as General
BLOCK INPUT FROMSTART: 0 s
Range: 0 - 5000 s in steps of 1Only seen if function is selected as General
GENERAL SWITCHALARM: Off
Range: Off, Latched, UnlatchedOnly seen if function is selected as General
ASSIGN ALARM RELAYS:Alarm
Range: None, Alarm, Aux1, Aux2, or combinationsOnly seen if function is selected as General
GENERAL SWITCHALARM DELAY: 5.0 s
Range: 0.1 to 5000.0 s in steps of 0.1Only seen if function is selected as General
RECORD ALARMS ASEVENTS: No
Range: No, YesOnly seen if function is selected as General
GENERAL SWITCHTRIP: Off
Range: Off, Latched, UnlatchedOnly seen if function is selected as General
ASSIGN TRIP RELAYS:Trip
Range: None, Trip, Aux1, Aux2, or combinationsOnly seen if function is selected as General
GENERAL SWITCHTRIP DELAY: 5.0 s
Range: 0.1 to 5000.0 s in steps of 0.1Only seen if function is selected as General
xxxxx SW FUNCTION:Digital Counter
COUNTERNAME: Counter
Range: 8 character alphanumericOnly seen if function is Digital Counter
COUNTERUNITS: Units
Range: 6 character alphanumericOnly seen if function is Digital Counter
COUNTERTYPE: Increment
Range: Increment, DecrementOnly seen if function is Digital Counter
DIGITAL COUNTERALARM: Off
Range: Off, Latched, UnlatchedOnly seen if function is Digital Counter
ASSIGN ALARM RELAYS:Alarm
Range: None, Alarm, Aux1, Aux2, or combinations. Onlyseen if function is Digital Counter
COUNTER ALARM LEVEL:100
Range: 0 to 65535 in steps of 1Only seen if function is Digital Counter
RECORD ALARMS ASEVENTS: No
Range: No, YesOnly seen if function is Digital Counter
5-58 369 Motor Management Relay GE Power Management
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c) WAVEFORM CAPTURE
The Waveform Capture setting for the digital inputs allows the 369 to capture a waveform upon command (contact closure).The captured waveforms can then be displayed via the 369PC program.
d) SIMULATE PRE-FAULT
The Simulate Pre-Fault setting for the digital inputs allows the 369 to start simulating the pre-fault settings as programmed.This is typically used for relay or system testing.
e) SIMULATE FAULT
The Simulate Fault setting for the digital inputs allows the 369 to start simulating the fault settings as programmed. This istypically used for relay or system testing.
f) SIMULATE PRE-FAULT to FAULT
The Simulate Pre-Fault to Fault setting for the digital inputs allows the 369 to start simulating the pre-fault to fault settingsas programmed. This is typically used for relay or system testing.
GE Power Management 369 Motor Management Relay 5-61
5 SETPOINTS 5.12 S11 369 TESTING
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5.12 S11 369 TESTING 5.12.1 SETPOINTS PAGE 11 MENU
5.12.2 SIMULATION MODE
PATH: S11 369 TESTING SIMULATION MODE
The 369 may be placed in several simulation modes. This simulation may be useful for several purposes. First, it may beused to understand the operation of the 369 for learning or training purposes. Second, simulation may be used during star-tup to verify that control circuitry operates as it should in the event of a trip, alarm, or block start. In addition, simulation maybe used to verify that setpoints had been set properly in the event of fault conditions.
Simulation mode may be entered only if the motor is stopped and there are no trips, alarms, or block starts active. The val-ues entered as Pre-Fault Values will be substituted for the measured values in the 369 when the simulation mode is 'Simu-late Pre-Fault'. The values entered as Fault Values will be substituted for the measured values in the 369 when thesimulation mode is 'Simulate Fault'. And, the values entered as Post-Fault Values will be substituted for the measured val-ues in the 369 when the simulation mode is 'Simulate Post-Fault'. If the simulation mode: Pre-Fault to Fault is selected, thePre-Fault values will be substituted for the period of time specified by the delay, followed by the Fault values. Likewise, ifthe simulation mode: Fault to Post-Fault is selected, the Fault values will be substituted for the period of time specified bythe delay, followed by the Post-Fault values. If a trip occurs, simulation mode will revert to Off. Selecting 'Off' for the simula-tion mode will also place the 369 back in service. If the 369 measures phase current or control power is cycled, simulationmode will automatically revert to Off.
S11 SETPOINTS369 TESTING
SIMULATION MODE
PRE-FAULT SETUPSee page 5–62.
FAULT SETUPSee page 5–63.
POST-FAULT SETUPSee page 5–64.
FORCE OUTPUT RELAYSSee page 5–65.
FORCE ANALOG OUTPUTSSee page 5–65.
SIMULATION MODE SIMULATION MODE:Off
Range: Off, Simulate Pre-Fault, Simulate Fault, SimulatePost Fault, Pre-Fault to Fault, Fault to Post-Fault
PRE-FAULT TO FAULTTIME DELAY: 10 s
Range: 0 to 300 s in steps of 1Only shown if in Pre-Fault to Fault mode
FAULT TO POST-FAULTTIME DELAY: 10 s
Range: 0 to 300 s in steps of 1Only shown if in Pre-Fault to Fault mode
GE Power Management 369 Motor Management Relay 5-65
5 SETPOINTS 5.12 S11 369 TESTING
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5.12.6 TEST OUTPUT RELAYS
PATH: S11 369 TESTING TEST OUTPUT RELAYS
The Test Output Relay feature provides a method of performing checks on all relay contact outputs. The feature can alsobe used for control purposes while the motor is running. The forced state overrides the normal operation of the relay out-put.
The forced state, if enabled (energized or de-energized), forces the selected relay into the programmed state for as long asthe programmed duration. After the programmed duration expires, the forced state will return to disabled and relay opera-tion will return to normal. If the duration is programmed as Static, the forced state will remain in effect until changed or dis-abled. If control power to the 369 is interrupted, any forced relay condition will be removed.
5.12.7 TEST ANALOG OUTPUTS
PATH: S11 369 TESTING TEST ANALOG OUTPUTS
In addition to the simulation modes, the Test Analog Output setpoints may be used during startup or testing to verify that theanalog outputs are functioning correctly. It may also be used when the motor is running to give manual or communicationcontrol of an analog output. Forcing an analog output overrides its normal functionality.
When the Force Analog Outputs Function is enabled, the output will reflect the forced value as a percentage of the range 4to 20 mA, 0 to 20 mA, or 0 to 1 mA. Selecting Off will place the analog output channels back in service, reflecting theparameters programmed to each.
GE Power Management 369 Motor Management Relay 6-3
6 ACTUAL VALUES 6.2 A1 STATUS
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6.2 A1 STATUS 6.2.1 ACTUAL VALUES PAGE 1 MENU
6.2.2 MOTOR STATUS
PATH: A1 STATUS MOTOR STATUS
These messages describe the status of the motor at the current point in time. The Motor Status message indicates the cur-rent state of the motor.
The Motor Thermal Capacity Used message indicates the current level which is used by the overload and cooling algo-rithms. The Estimated Trip Time On Overload is only active for the Overload motor status.
6-4 369 Motor Management Relay GE Power Management
6.2 A1 STATUS 6 ACTUAL VALUES
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6.2.3 LAST TRIP DATA
PATH: A1 STATUS LAST TRIP DATA
Immediately prior to a trip, the 369 takes a snapshot of the metered parameters along with the cause of trip and the dateand time and stores this as pre-trip values. This allows for ease of troubleshooting when a trip occurs. Instantaneous tripson starting (< 50 ms) may not allow all values to be captured. These values are overwritten when the next trip occurs. Theevent record shows details of the last 40 events including trips.
6.2.4 ALARM STATUS
PATH: A1 STATUS ALARM STATUS
Any active trips or alarms may be viewed here. If there is more than one active trip or alarm, using the Line Up and Downkeys will cycle through all the active alarm messages. If the [LINE UP] and [LINE DOWN] keys are not pressed, the activemessages will automatically cycle. The current level causing the alarm is displayed along with the alarm name.
LAST TRIP DATA CAUSE OF LAST TRIP:No Trip to date
Range: No Trip to Date, cause of trip
TIME OF LAST TRIP:00:00:00
Range: hour: min: seconds
DATE OF LAST TRIP:Jan 01 1999
Range: month day year
A: 0 B: 0C: 0 A Pretrip
Range: 0 to 100000 A in steps of 1
MOTOR LOADPretrip 0.00 x FLA
Range: 0.00 to 20.00 in steps of 0.01
CURRENT UNBALANCEPretrip: 0%
Range: 0 to 100% in steps of 1
GROUND CURRENTPretrip: 0.00 Amps
Range: 0.0 to 5000.0 in steps of 0.1 (1A/5A CT)0.00 to 25.00 in steps of 0.01 (50: 0.025 A CT)
HOTTEST STATOR RTDRTD#1 0°C Pretrip
Range: –40 to +200 °C in steps of 1Only shown if a stator RTD is programmed
Vab: 0 Vbc: 0Vca: 0 V Pretrip
Range: 0 to 20000 in steps of 1Only shown if VT connection is programmed
Van: 0 Vbn: 0Vcn: 0 V Pretrip
Range: 0 to 20000 in steps of 1Only shown if VT connection is Wye
SYSTEM FREQUENCYPretrip: 0.00 Hz
Range: 0.00, 15.00 to 120.00 in steps of 0.01Only shown if VT connection is programmed
0 kW 0 kVA0 kvar Pretrip
Range: –50000 to +50000 in steps of 1Only shown if VT connection is programmed
POWER FACTORPretrip: 1.00
Range: 0.00 lag to 1 to 0.00 leadOnly shown if VT connection is programmed
DIAGNOSTIC MESSAGES No Trips or Alarmsare Active
Range: No Trips or Alarms are Active, active alarmname and level, active trip name
GE Power Management 369 Motor Management Relay 6-5
6 ACTUAL VALUES 6.2 A1 STATUS
6
6.2.5 START INHIBIT STATUS
PATH: A1 STATUS START INHIBIT STATUS
OVERLOAD LOCKOUT TIMER: Determined from the thermal model, this is the remaining amount of time left before thethermal capacity available will be sufficient to allow another start and the start inhibit will be removed.
SELECT INHIBIT TIMER: If enabled this timer will indicate the remaining time for the Thermal Capacity to reduce to a levelto allow for a safe start according to the Start Inhibit setpoints.
STARTS/HOUR TIMER: If enabled this display will indicate the number of starts within the last hour by showing the timeremaining in each. The oldest start will be on the left. Once the time of one start reaches 0, it is no longer considered a startwithin the hour and is removed from the display and any remaining starts are shifted over to the left.
TIME BETWEEN STARTS TIMER: If enabled this timer will indicate the remaining time from the last start before the startinhibit will be removed and another start may be attempted. This time is measure from the beginning of the last motor start.
RESTART BLOCK TIMER: If enabled this display will reflect the amount of time since the last motor stop before the startblock will be removed and another start may be attempted.
6.2.6 DIGITAL INPUT STATUS
PATH: A1 STATUS DIGITAL INPUT STATUS
The present state of the digital inputs will be displayed here.
START INHIBIT STATUS OVERLOAD LOCKOUTTIMER: None
Range: 1 to 9999 min. in steps of 1
START INHIBITTIMER: None
Range: 1 to 999 min. in steps of 1
STARTS/HOUR TIMERS:0 0 0 0 0 min
Range: 1 to 60 min. in steps of 1
TIME BETWEEN STARTSTIMER: None
Range: 1 to 500 min. in steps of 1
RESTART BLOCK TIMER:None
Range: 1 to 50000 s in steps of 1
DIGITAL INPUT STATUS EMERGENCY RESTART:Open
Range: Open, ClosedNote: Programmed input name displayed
DIFFERENTIAL RELAY:Open
Range: Open, ClosedNote: Programmed input name displayed
SPEED SWITCH:Open
Range: Open, ClosedNote: Programmed input name displayed
RESET:Open
Range: Open, ClosedNote: Programmed input name displayed
ACCESS:Open
Range: Open, ClosedNote: Programmed input name displayed
SPARE:Open
Range: Open, ClosedNote: Programmed input name displayed
6-6 369 Motor Management Relay GE Power Management
6.2 A1 STATUS 6 ACTUAL VALUES
6
6.2.7 OUTPUT RELAY STATUS
PATH: A1 STATUS OUTPUT RELAY STATUS
The present state of the output relays will be displayed here. Energized indicates that the NO contacts are now closed andthe NC contacts are now open. De-energized indicates that the NO contacts are now open and the NC contacts are nowclosed. Forced indicates that the output relay has been commanded into a certain state.
6.2.8 REAL TIME CLOCK
PATH: A1 STATUS REAL TIME CLOCK
The date and time from the 369 real time clock may be viewed here.
OUTPUT RELAY STATUS TRIP: De–energized Range: Energized, De–energized, Forced
6-8 369 Motor Management Relay GE Power Management
6.3 A2 METERING DATA 6 ACTUAL VALUES
6
6.3.3 VOLTAGE METERING
PATH: A2 METERING DATA VOLTAGE METERING
Measured voltage parameters will be displayed here. If option M or B has not been installed, the following message willappear when attempting to enter this section.
6.3.4 POWER METERING
PATH: A2 METERING DATA POWER METERING
The values for three phase power metering, consumption and generation will be displayed here. If option M or B has notbeen installed the following message will appear when attempting to enter this section.
VOLTAGE METERING Vab: 0 Vbc: 0Vca: 0 V RMS φ- φ
Range: 0 to 20000 V in steps of 1Only shown if a VT connection programmed
AVERAGE LINEVOLTAGE: 0 V
Range: 0 to 20000 V in steps of 1Only shown if VT connection programmed
Va: 0 Vb: 0Vc: 0 V RMS φ-N
Range: 0 to 20000 V in steps of 1Only shown if a Wye connection programmed
AVERAGE PHASEVOLTAGE: 0 V
Range: 0 to 20000 V in steps of 1Only shown if a Wye connection programmed
SYSTEM FREQUENCY:0.00 Hz
Range: 0.00, 15.00 to 120.00 Hz in steps of 0.01
THIS FEATURE NOTINSTALLED
POWER METERING POWER FACTOR:1.00
Range: 0.00 to 1.00 lag or leadOnly shown if VT connection programmed
REAL POWER:0 kW
Range: 0 to ±50000 kW in steps of 1Only shown if VT connection programmed
REAL POWER:0 hp
Range: 0 to 65000 hp in steps of 1Only shown if VT connection programmed
REACTIVE POWER:0 kvar
Range: 0 to ±50000 kvar in steps of 1Only shown if VT connection programmed
APPARENT POWER:0 kVA
Range: 0 to 50000 kVA in steps of 1Only shown if VT connection programmed
POSITIVE WATTHOURS:0 MWh
Range: 0 to 65535 in steps of 1Only shown if VT connection programmed
POSITIVE VARHOURS:0 kvarh
Range: 0 to 65535 in steps of 1Only shown if VT connection programmed
NEGATIVE VARHOURS:0 kvarh
Range: 0 to 65535 in steps of 1Only shown if VT connection programmed
GE Power Management 369 Motor Management Relay 6-9
6 ACTUAL VALUES 6.3 A2 METERING DATA
6
6.3.5 BACKSPIN METERING
PATH: A2 METERING DATA BACKSPIN METERING
Backspin metering parameters will be displayed here. If option B has not been installed, the following message will appearwhen attempting to enter this section.
6.3.6 LOCAL RTD
PATH: A2 METERING DATA LOCAL RTD
BACKSPIN METERING BACKSPIN FREQUENCY:0.00 Hz
Range: 0 to 120 Hz in steps of 0.01Only shown if option B installed and enabled.
BACKSPIN DETECTIONSTATE:No_BSD_Running
Range: Motor Running, No Backspin, Slowdown,Acceleration, Backspinning, Prediction, Soon to Restart.Shown only if backspin start inhibit is enabled
BACKSPIN PREDICTIONTIMER:30 s
Range: 0 to 50000 s in steps of 1. Shown only if backspinstart inhibit is enabled and predication timer is enabled.
THIS FEATURE NOTINSTALLED
LOCAL RTD HOTTEST STATOR RTDNUMBER: 1
Range: None, 1 to 12 in steps of 1
HOTTEST STATOR RTDTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #1TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #2TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #3TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #4TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #5TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #6TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #7TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #8TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #9TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #10TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #11TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #12TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
6-10 369 Motor Management Relay GE Power Management
6.3 A2 METERING DATA 6 ACTUAL VALUES
6
The temperature level of all 12 internal RTDs will be displayed here if the 369 has option R enabled. The programmedname of each RTD (if changed from the default) will appear as the first line of each message. If option R has not beeninstalled, the following message appears when attempting to enter this section.
6.3.7 REMOTE RTD
PATH: A2 METERING DATA REMOTE RTD
The temperature level of all 12 remote RTDs will be displayed here if programmed and connected to a RRTD module. Thename of each RRTD (if changed from the default) will appear as the first line of each message. If option R has not beeninstalled, the following message will appear when attempting to enter this section.
If communications with the RRTD module is lost, the following message will appear:
THIS FEATURE NOTINSTALLED
REMOTE RTD HOTTEST STATOR RRTDNUMBER: 1
Range: None, 1 to 12 in steps of 1
HOTTEST STATOR RTDTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #1TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #2TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #3TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #4TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #5TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #6TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #7TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #8TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #9TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #10TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #11TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RRTD #12TEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
GE Power Management 369 Motor Management Relay 6-11
6 ACTUAL VALUES 6.3 A2 METERING DATA
6
6.3.8 DEMAND METERING
PATH: A2 METERING DATA DEMAND METERING
The values for current and power demand are displayed here. Peak demand information can be cleared using theCLEAR PEAK DEMAND command located in S1 369 SETUP \ CLEAR/PRESET DATA . Demand is only shown for positive real(kW) and reactive (kvar) powers. Only the current demand will be visible if options M or B are not installed.
6.3.9 PHASORS
PATH: A2 METERING DATA PHASORS
All angles shown are with respect to the reference phasor. The reference phasor is based on the VT connection type. In theevent that option M has not been installed, Van for Wye is 0 V, or Vab for Delta is 0 V, Ia will be used as the reference phasor.
DEMAND METERING CURRENTDEMAND: 0 Amps
Range: 0 to 65535 A in steps of 1
REAL POWERDEMAND: 0 kW
Range: 0 to 50000 kW in steps of 1Only shown if VT connection programmed
REACTIVE POWERDEMAND: 0 kvar
Range: –32000 to 32000 kvar in steps of 1Only shown if VT connection programmed
APPARENT POWERDEMAND: 0 kVA
Range: 0 to 50000 kVA in steps of 1Only shown if VT connection programmed
PEAK CURRENTDEMAND: 0 Amps
Range: 0 to 65535 A in steps of 1
PEAK REAL POWERDEMAND: 0 kW
Range: 0 to 50000 kW in steps of 1Only shown if VT connection programmed
PEAK REACTIVE POWERDEMAND: 0 kvar
Range: –32000 to 32000 kvar in steps of 1Only shown if VT connection programmed
PEAK APPARENT POWERDEMAND: 0 kVA
Range: 0 to 50000 kVA in steps of 1Only shown if VT connection programmed
PHASORS Ia PHASOR:0 Degrees Lag
Range: 0 to 359 degrees in steps of 1
Ib PHASOR:0 Degrees Lag
Range: 0 to 359 degrees in steps of 1
Ic PHASOR:0 Degrees Lag
Range: 0 to 359 degrees in steps of 1
Va PHASOR:0 Degrees Lag
Range: 0 to 359 degrees in steps of 1Only shown if VT connection programmed
Vb PHASOR:0 Degrees Lag
Range: 0 to 359 degrees in steps of 1Only shown if VT connection programmed
Vc PHASOR:0 Degrees Lag
Range: 0 to 359 degrees in steps of 1Only shown if VT connection programmed
6-12 369 Motor Management Relay GE Power Management
6.3 A2 METERING DATA 6 ACTUAL VALUES
6
Note that the phasor display is not intended to be used as a protective metering element. Its prime purpose is to diagnoseerrors in wiring connections.
To aid in wiring, the following tables can be used to determine if VTs and CTs are on the correct phase and their polarity iscorrect. Problems arising from incorrect wiring are extremely high unbalance levels (CTs), erroneous power readings (CTsand VTs), or phase reversal trips (VTs). To correct wiring, simply start the motor and record the phasors. Using the followingtables along with the recorded phasors, system rotation, VT connection type, and motor power factor, the correct phasorscan be determined. Note that Va (Vab if delta) is always assumed to be 0° and is the reference for all angle measurements.
Common problems include: Phase currents 180° from proper location (CT polarity reversed)Phase currents or voltages 120° or 240° out (CT/VT on wrong phase)
GE Power Management 369 Motor Management Relay 6-13
6 ACTUAL VALUES 6.4 A3 LEARNED DATA
6
6.4 A3 LEARNED DATA 6.4.1 ACTUAL VALUES PAGE 3 MENU
This page contains the data the 369 learns to adapt itself to the motor protected.
6.4.2 MOTOR DATA
PATH: A3 LEARNED DATA MOTOR DATA
The learned values for acceleration time and starting current are the average of the individual values acquired for the lastfive successful starts. The value for starting current is used when learned k factor is enabled.
The learned value for starting capacity is the amount of thermal capacity required for a start that has been determined bythe 369 from the last five successful motor starts. The last five learned start capacities are averaged and a 25% safety mar-gin is factored in. This is done to guarantee enough thermal capacity available to start the motor. The Start Inhibit feature,when enabled, uses this value in determining lockout time.
The learned cool time constants and unbalance k factor are displayed here. The learned value is the average of the last fivemeasured constants. These learned cool time constants are used only when ENABLE LEARNED COOL TIMES feature of thethermal model is set to "Yes". The learned unbalance k factor is the average of the last five calculated k factors. Thelearned k factor is only used when unbalance biasing of thermal capacity is set on and to learned.
It should be noted that learned values are calculated even when the features requiring them are turned off. None of thelearned features should be used until at least five successful motor starts and stops have been accomplished.
6-14 369 Motor Management Relay GE Power Management
6.4 A3 LEARNED DATA 6 ACTUAL VALUES
6
Values for starting capacity, starting current, and acceleration time are displayed for the last start. The average motor loadwhile running is also displayed here. The motor load is averaged over a 15 minute sliding window.
Clearing motor data (see Section 5.2.9: CLEAR/PRESET DATA on page 5–10) resets these values to their default settings.
6.4.3 LOCAL RTD MAXIMUMS
PATH: A3 LEARNED DATA LOCAL RTD MAXIMUMS
The maximum temperature level of all 12 internal RTDs will be displayed here if the 369 has option R enabled. The pro-grammed name of each RTD (if changed from the default) will appear as the first line of each message. If option R has notbeen installed, the following message will appear when attempting to enter this section.
If options R is enabled and no RTDs are programmed, the following message will appear when an attempt is made to enterthis group of messages.
LOCAL RTD MAXIMUMS RTD #1 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #2 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #3 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #4 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #5 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #6 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #7 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #8 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #9 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #10 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #11 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
RTD #12 MAXIMUMTEMPERATURE: 40°C
Range: –40 to 200°C or –40 to 392°FNo RTD = open, Shorted = shorted RTD
GE Power Management 369 Motor Management Relay 6-15
6 ACTUAL VALUES 6.4 A3 LEARNED DATA
6
6.4.4 REMOTE RTD MAXIMUMS
PATH: A3 LEARNED DATA REMOTE RTD MAXIMUMS
The maximum temperature level of all 12 remote RTDs will be displayed here if the 369 has been programmed and con-nected to a RRTD module. The programmed name of each RTD (if changed from the default) will appear as the first line ofeach message. If an RRTD module is connected and no RRTDs are programmed, the following message will appear whenan attempt is made to enter this group of messages.
GE Power Management 369 Motor Management Relay 6-17
6 ACTUAL VALUES 6.5 A4 STATISTICAL DATA
6
A breakdown of the number of trips by type is displayed here. When the total reaches 50000, the counter resets to 0 on thenext trip and continues counting. This information can be cleared in the Clear/Preset Data section of setpoints page one.The date the counters are cleared will be recorded.
6.5.3 MOTOR STATISTICS
PATH: A4 STATISTICAL DATA MOTOR STATISTICS
The number of motor starts and emergency restarts is recorded here. This information may be useful when troubleshootinga motor failure or in understanding the history and use of a motor for maintenance purposes. When either of these countersreaches 50000, it will automatically be reset to 0.
Motor running hours displays the amount of time that the 369 has detected the motor in a running state (current appliedand/or starter status indicating contactor/breaker closed).
The motor starts, emergency restarts and running hours counters may be cleared in setpoints page 1, preset/clear datasection, by clearing motor data.
The digital counter will be displayed when one of the digital inputs has been set up as a digital counter. The digital countermay be cleared in setpoints page 1, preset/clear data section, by clearing or presetting the digital counter. When the digitalcounter reaches 65535, it will automatically be reset by the 369 to 0.
PHASE REVERSALTRIPS: 0
Range: 0 to 50000 in steps of 1
UNDERFREQUENCYTRIPS: 0
Range: 0 to 50000 in steps of 1
OVERFREQUENCYTRIPS: 0
Range: 0 to 50000 in steps of 1
LEAD POWER FACTORTRIPS: 0
Range: 0 to 50000 in steps of 1
LAG POWER FACTORTRIPS: 0
Range: 0 to 50000 in steps of 1
POSITIVE REACTIVETRIPS: 0
Range: 0 to 50000 in steps of 1
NEGATIVE REACTIVETRIPS: 0
Range: 0 to 50000 in steps of 1
UNDERPOWER TRIPS:0
Range: 0 to 50000 in steps of 1
REVERSE POWER:0
Range: 0 to 50000 in steps of 1
TRIP COUNTERS LASTCLEARED: 01/01/1999
Range: 0 to 50000 in steps of 1
MOTOR STATISTICS NUMBER OF MOTORSTARTS: 0
Range: 0 to 50000 in steps of 1
NUMBER OF EMERGENCYRESTARTS: 0
Range: 0 to 50000 in steps of 1
MOTOR RUNNING HOURS:0 hrs
Range: 0 to 100000 in steps of 1
DIGITAL COUNTER:0
Range: 0 to 65535 in steps of 1Shown if counter set to a digital input
6-18 369 Motor Management Relay GE Power Management
6.6 A5 EVENT RECORD 6 ACTUAL VALUES
6
6.6 A5 EVENT RECORD 6.6.1 ACTUAL VALUES PAGE 5 MENU
6.6.2 EVENT 01
PATH: A5 EVENT RECORD EVENT 01
A breakdown of the last 65535 events is available here along with the cause of the event and the date and time. All tripsautomatically trigger an event. Alarms only trigger an event if turned on for that alarm. Loss or application of control power,service alarm and emergency restart opening and closing also triggers an event. After 65535 events have been recorded,the oldest one is removed when a new one is added. The event record may be cleared in the setpoints page 1, clear/presetdata, clear event record section.
A5 ACTUAL VALUESEVENT RECORD
EVENT: 40
EVENT: 39
EVENT: 02
EVENT: 01
EVENT 01 TIME OF EVENT 0100:00:00:00
Time: hours / minutes / seconds / hundreds of seconds
DATE OF EVENT 01Jan. 01, 1999
Date: month / day / year
A: 0 B: 0C: 0 A E: 01
Range: 0 to 65535 A in steps of 1
MOTOR LOAD0.00 X FLA E: 01
Range: 0.00 to 20.00 x FLA in steps of 0.01
CURRENT UNBALANCE:0% E: 01
Range: 0 to 100% in steps of 1
GROUND CURRENT:0.0 Amps E: 01
Range:0.0 to 5000.0 A steps of 0.1 (1A/5A CT)0.00 to 25.00 A steps of 0.01 (50: 0.025 A CT)
HOTTEST STATORRTD 1: 0°C E: 01
Range: –40 to 200°C or –40 to 392°F,No RTD = open, Shorted = shorted RTD
Vab: 0 Vbc: 0Vca: 0 V E: 01
Range: 0 to 20000 V in steps of 1Only shown if VT Connection Programmed Delta
Van: 0 Vbn: 0Vcn: 0 V E: 01
Range: 0 to 20000 V in steps of 1Only shown if VT Connection Programmed Wye
SYSTEM FREQUENCY:0.00 Hz E: 01
Range: 0.00, 15.00 to 120 Hz in steps of 1Only shown if VT Connection Programmed
0 kW 0 kVA0 kvar E: 01
Range: –50000 to +50000 in steps of 1Only shown if VT Connection Programmed
POWER FACTOR:1.00 E: 01
Range: 0.00 lag to 1 to 0.00 leadOnly shown if VT Connection Programmed
GE Power Management 369 Motor Management Relay 6-19
6 ACTUAL VALUES 6.7 A6 RELAY INFORMATION
6
6.7 A6 RELAY INFORMATION 6.7.1 ACTUAL VALUES PAGE 6 MENU
6.7.2 MODEL INFORMATION
PATH: A6 RELAY INFORMATION MODEL INFORMATION
369 model and manufacture information may be viewed here. The last calibration date is the date the relay was last cali-brated at GE Power Management.
6.7.3 FIRMWARE VERSION
PATH: A6 RELAY INFORMATION FIRMWARE VERSION
This information reflects the revisions of the software currently running in the 369. This information should be noted andrecorded before calling for technical support or service.
GE Power Management 369 Motor Management Relay 7-1
7 APPLICATIONS 7.1 269-369 COMPARISON
7
7 APPLICATIONS 7.1 269-369 COMPARISON 7.1.1 369 AND 269PLUS COMPARISON
Table 7–1: COMPARISON BETWEEN 369 AND 269Plus
369 269Plus
All options can be turned on or added in the field Must be returned for option change or add other devices
Current and optional voltage inputs are included on all relays Current inputs only. Must use additional meter device to obtain voltage and power measurements.
Optional 12 RTDs with an additional 12 RTDs available with the RRTD. All RTDs are individually configured(100P, 100N, 120N, 10C)
10 RTDs not programmable, must be specified at time of order.
Fully programmable digital inputs No programmable digital inputs
4 programmable analog outputs assignable to 49 parameters 1 Analog output programmable for 5 parameters
1 RS232 (19.2K baud), 3 RS485 (1200 TO 19.2K baud programmable) communication ports. Also Optional profibus port and optional fiber optics port
1 RS485 Communication port (2400 baud maximum)
Flash memory firmware upgrade thru PC software and comm port EPROM must be replaced to change firmware
EVENT RECORDER: time and date stamp last 40 events. Records all trips and selectable alarms
Displays cause of last trip and last event
OSCILLOGRAPHY: up to 64 cycles at 16 samples/cycle for last event(s)
N/A
TESTING\SIMULATION function to force relays, analog outputs and simulate metered values
Exercise relays, force RTDs, force analog output
Programmable text message(s) N/A
Backspin frequency detection and backspin timer Backspin timer
Starter failure indication N/A
Measures up to 20 x CT at 16 samples/cycle Measures up to 12 x CT at 12 samples/cycle
15 standard overload curves 8 standard overload curves
Remote display is standard Remote display with mod
1. What is the difference between Firmware and Software?
Firmware is the program running inside the relay, which is responsible for all relay protection and control elements.Software is the program running on the PC, which is used to communicate with the relay and provide relay controlremotely in a user friendly format.
2. How can I obtain copies of the latest manual and PC software?
I need it now!: via the GE Power Management website at http://www.GEindustrial.com/pm
I guess I can wait: fax a request to the GE Power Management Literature department at (905) 201-2113
3. Cannot communicate through the front port (RS232).
Check the following settings:
• Communication Port (COM1, COM2, COM3 etc.) on PC or PLC
• Parity settings must match between the relay and the master (PC or PLC)
• Baud rate setting on the master (PC or PLC) must match RS232 baud rate on the 369 relay.
• Cable has to be a straight through cable, do not use null modem cables where pin 2 and 3 are transposed
• Check the pin outs of RS232 cable (TX - pin 2, RX - pin 3, GND - pin 5)
4. Cannot communicate with RS485.
Check the following settings:
• Communication Port (COM1, COM2, COM3 etc.) on PC or PLC
• Parity settings must match between the relay and the master (PC or PLC)
• Baud rate must match between the relay and the master
• Slave address polled must match between the relay and the master
• Is terminating filter circuit present?
• Are you communicating in half duplex? (369 communicates in half duplex mode only)
• Is wiring correct? (“+” wire should go to “+” terminal of the relay, and “–” goes to “–” terminal)
• Is the RS485 cable shield grounded? (shielding diminishes noise from external EM radiation)
Check the appropriate communication port LED on the relay. The LED should be solidly lit when communicating prop-erly. The LED will blink on and off when the relay has communication difficulties and the LED will be off if no activitydetected on communication lines.
5. Can the 4 wire RS485 (full duplex) be used with 369?
No, the 369 communicates in 2-wire half duplex mode only. However, there are commercial RS485 converters that willconvert a 4 wire to a 2 wire system.
6. Can the 369 be used on Variable Frequency Drives (VFD)?
Yes. Consider the following tables showing the 369 input current frequency response at 50 and 60 Hz:
GE Power Management 369 Motor Management Relay 7-3
7 APPLICATIONS 7.2 369 FAQs
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The above results indicate a worst-case scenario at the lowest end of the frequency spectrum. Lower frequencies aretypically experienced during initial motor starting. The starting settings can be adjusted to compensate for these differ-ences during the short duration of the motor start. During normal motor operating conditions above 25 Hz, the 369 fre-quency response is such that compensation is not required for current-based protection elements.
7. Cannot store setpoint into the relay.
Check and ensure the ACCESS switch is shorted, and check for any PASSCODE restrictions.
8. The 369 relay displays incorrect power reading, yet the power system is balanced. What could be the possiblereasons?
It is highly possible that the secondary wiring to the relay is not correct. Incorrect power can be read when any of the A,B, or C phases are swapped, a CT or VT is wired backwards, or the relay is programmed as ABC sequence when thepower system is actually ACB and vice versa. The easiest way to verify is to check the voltage and the current phasorreadings on the 369 relay and ensure that each respective voltage and current angles match.
9. What are the merits of a residual ground fault connection versus a core balance connection?
The use of a zero sequence (core balance) CT to detect ground current is recommended over the G/F residual con-nection. This is especially true at motor starting. During across-the-line starting of large motors, care must be taken toprevent the high inrush current from operating the ground element of the 369. This is especially true when using theresidual connection of 2 or 3 CTs.
In a residual connection, the unequal saturation of the current transformers, size and location of motor, size of powersystem, resistance in the power system from the source to the motor, type of iron used in the motor core & saturationdensity, and residual flux levels may all contribute to the production of a false residual current in the secondary or relaycircuit. The common practice in medium and high voltage systems is to use low resistance grounding. By using the“doughnut CT” scheme, such systems offer the advantages of speed and reliability without much concern for startingcurrent, fault contribution by the motor, or false residual current.
When a zero sequence CT is used, a voltage is generated in the secondary winding only when zero sequence currentis flowing in the primary leads. Since virtually all motors have their neutrals ungrounded, no zero sequence current canflow in the motor leads unless there is a ground fault on the motor side.
10. Can I send a 269 setpoint file to a 369 relay?
Yes. Using the 369PC software, a 269 setpoint file can be sent to the 369. Note that any settings/features not in the269 setpoint file are set to default values on the 369. All setpoints should be confirmed before operating the relay.
11. Can I use an 86 lockout on the 369?
Yes, but if an external 86 lockout device is used and connected to the 369, ensure the 369 is reset prior to attemptingto reset the lockout switch. If the 369 is still tripped, it will immediately re-trip the lockout switch. Also, if the lockoutswitch is held reset, the high current draw of the switch coil may cause damage to itself and/or the 369 output relay.
12. Can I assign more than one output relay to be blocked when using Start Inhibits?
Yes, but keep in mind that if two output relays are wired in series to inhibit a start it is possible that another elementcould be programmed to control one or both of the relays. If this is happening and the other element is programmedwith a longer delay time, this will make it seem as if the Start Inhibit is not working properly when in fact, it is.
13. Can I name a digital input?
Yes. By configuring the digital input as "General" a menu will appear that will allow naming.
14. Can I apply an external voltage to the digital inputs on the 369?
No. The 369 uses an internal voltage to operate the digital inputs. Applying an external voltage may cause damage tothe internal circuitry.
15. No display, no characters on the display but there is a backlight.
Check the contrast using the help button. Press and hold the help button for 2 seconds. When all the LED’s are illumi-nated press the value up key to darken the contrast or value down key to lighten the contrast. When the desired con-trast is selected press the enter key to accept the change.
16. Can I upload setpoint files from previous versions to the latest version of firmware?
Yes, with the exception of setpoint files from versions 1.10 and 1.12. Unfortunately these setpoint files must be rewrit-ten, as they are not compatible.
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7.2 369 FAQs 7 APPLICATIONS
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17. What method does the 369 use to calculate current unbalance?
The 369 uses the NEMA method. Previous revisions of the 369 manual have incorrectly included a functional test thatmeasured the ratio of negative sequence current to positive sequence current. The NEMA method is as follows:
If Iavg ≥ IFLA, then
where: Iavg = average phase currentImax = current in a phase with maximum derivation from IavgIFLA = motor full load amps setting
If Iavg < IFLA, then
To prevent nuisance trips/alarms on lightly loaded motors when a much larger unbalance level will not damage therotor, the unbalance protection will automatically be defeated if the average motor current is less than 30% of the fullload current (IFLA) setting.
18. I need to update the options for my 369/RRTD in the field, can I do this?
Yes. All options of the 369/RRTD can be turned on or added in the field. To do this contact the factory.
19. Can I test my output relays?
Yes, but keep in mind that the output relays cannot be forced into a different state while the motor is running.
20. Is the communication interface for Profibus RS232 or RS485?
It is RS485. The 9-pin connector on the rear of the 369 is the connector used by the manufacturer of the Profibus cardand although it is a DB-9, the electrical interface is RS485.
21. Can I use the options enabler code to upgrade my 369 in the field to get the Profibus option?
Yes, but keep in mind that there is a Profibus card that is required and is not installed in units that were not orderedfrom the factory with the Profibus option.
22. Can the 369 be used as a remote unit, similar to the 269 remote?
Yes. Every 369 can be used as remote. When ordering the 369, an external 15 foot cable must be ordered.
23. Can the RRTD module be used as a standalone unit?
Yes. The RRTD unit with the IO option, has 4 output relays, 6 digital inputs and 4 analog outputs. With this option theRRTD can provide temperature protection.
GE Power Management 369 Motor Management Relay 7-5
7 APPLICATIONS 7.3 369 DOs and DON’Ts
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7.3 369 DOs and DON’Ts 7.3.1 DOs and DON’Ts
a) DOs
Always check the power supply rating before applying power to the relay
Applying voltage greater than the maximum rating to the power supply (e.g. 120 V AC to the low-voltage rated powersupply) could result in component damage to the relay's power supply. This will result in the unit no longer being ableto power up.
Ensure that the 369 nominal phase current of 1 A or 5 A matches the secondary rating and the connections of theconnected CTs
Unmatched CTs may result in equipment damage or inadequate protection.
Ensure that the source CT and VT polarity match the relay CT and VT polarity
Polarity of the Phase CTs is critical for power measurement, and residual ground current detection (if used). Polarity ofthe VTs is critical for correct power measurement and voltage phase reversal operation.
Properly ground the 369
Connect both the Filter Ground (terminal 123) and Safety Ground (terminal 126) of the 369 directly to the mainGROUND BUS. The benefits of proper grounding of the 369 are numerous, e.g,
• Elimination of nuisance tripping
• Elimination of internal hardware failures
• Reliable operation of the relay
• Higher MTBF (Mean Time Between Failures)
• It is recommended that a tinned copper braided shielding and bonding cable be used. A Belden 8660 cable orequivalent should be used as a minimum to connect the relay directly to the ground bus.
Grounding of Phase and Ground CTs
All Phase and Ground CTs must be grounded. The potential difference between the CT's ground and the ground busshould be minimal (ideally zero).
It is highly recommended that the two CT leads be twisted together to minimize noise pickup, especially when thehighly sensitive 50:0.025 Ground CT sensor is used.
RTDs
Consult the application notes of the 369 Instruction Manual for the full description of the 369 RTD circuitry and the dif-ferent RTD wiring schemes acceptable for proper operation. However, for best results the following recommendationsshould be adhered to:
a) Use a 3 wire twisted, shielded cable to connect the RTDs from the motor to the 369. The shields should be con-nected to the proper terminals on the back of the 369.
b) RTD shields are internally connected to the 369 ground (terminal #126) and must not be grounded anywhere else.
c) RTD signals can be characterized as very small, sensitive signals. Therefore, cables carrying RTD signals shouldbe routed as far away as possible from power carrying cables such as power supply and CT cables.
d) If after wiring the RTD leads to the 369, the RTD temperature displayed by the Relay is zero, then check for thefollowing conditions:
1. Shorted RTD2. RTD hot and compensation leads are reversed, i.e. hot lead in compensation terminal and compensation lead
in hot terminal.
RS485 Communications Port
The 369 can provide direct or remote communications (via a modem). An RS232 to RS485 converter is used to tie it toa PC/PLC or DCS system. The 369 uses the Modicon MODBUS® RTU protocol (functions 03, 04, & 16) to interfacewith PCs, PLCs, and DCS systems.
RS485 communications was chosen to be used with the 369 because it allows communications over long distances ofup to 4000 ft. However, care must be taken for it to operate properly and trouble free. The recommendations listedbelow must be followed to obtain reliable communications:
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7.3 369 DOs and DON’Ts 7 APPLICATIONS
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a) A twisted, shielded pair (preferably a 24 gauge Belden 9841 type or 120 equivalent) must be used and routedaway from power carrying cables, such as power supply and CT cables.
b) No more than 32 devices can co-exist on the same link. If however, more than 32 devices should be daisy chainedtogether, a REPEATER must be used. Note that a repeater is just another RS232 to RS485 converter device. Theshields of all 369 units should also be daisy chained together and grounded at the MASTER (PC/PLC) only. Thisis due to the fact that if shields are grounded at different points, a potential difference between grounds might existresulting in placing one or more of the transceiver chips (chip used for communications) in an unknown state, i.e.not receiving nor sending. The corresponding 369 communications might be erroneous, intermittent or unsuccess-ful.
c) Two sets of 120 Ω / 0.5 W resistor and 1 nF / 50 V capacitor in series must be used (value matches the character-istic impedance of the line). One set at the 369 end, connected between the positive and negative terminals (#46& #47 on 369) and the second at the other end of the communications link. This is to prevent reflections and ring-ing on the line. If a different value resistor is used, it runs the risk of over loading the line and communicationsmight be erroneous, intermittent or totally unsuccessful.
d) It is highly recommended that connection from the 369 communication terminals be made directly to the interfac-ing Master Device (PC/PLC/DCS), without the use of stub lengths and/or terminal blocks. This is also to minimizeringing and reflections on the line.
b) DON'Ts
Don’t apply direct voltage to the Digital Inputs.
There are 6 switch inputs (Spare Input; Differential Input; Speed Switch; Access; Emergency Restart; External Reset)that are designed for dry contact connections only. Applying direct voltage to the inputs, it may result in componentdamage to the digital input circuitry.
Grounding of the RTDs should not be done in two places.
When grounding at the 369, only one Return lead need be grounded as all are hard-wired together internally. No errorwill be introduced into the RTD reading by grounding in this manner.
Running more than one RTD Return lead back will cause significant errors as two or more parallel paths for returnhave been created.
Don’t reset an 86 Lockout switch before resetting the 369.
If an external 86 lockout device is used and connected to the 369, ensure that the 369 is reset prior to attempting toreset the lockout switch. If the 369 is still tripped, it will immediately re-trip the lockout switch. Also if the lockout switchis held reset, the high current draw of the lockout switch coil may cause damage to itself and/or the 369 output relay.
GE Power Management 369 Motor Management Relay 7-7
7 APPLICATIONS 7.4 CT SPECIFICATION AND SELECTION
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7.4 CT SPECIFICATION AND SELECTION 7.4.1 CT SPECIFICATION
a) 369 CT WITHSTAND
Withstand is important when the phase or ground CT has the capability of driving a large amount of current into the inter-posing CTs in the relay. This typically occurs on retrofit installations when the CTs are not sized to the burden of the relay.Electronic relays typically have low burdens (8 mΩ for 369), while the older electromechanical relays have typically highburdens (1 Ω).
For high current ground faults, the system will be either low resistance or solidly grounded. The limiting factor that deter-mines the ground fault current that can flow in these types of systems is the source capacity. Withstand is not important forground fault on high resistance grounded systems. On these systems, a resistor makes the connection from source toground at the source (generator, transformer). The resistor value is chosen so that in the event of a ground fault, the currentthat flows is limited to a low value, typically 5, 10, or 20 A.
Since the potential for very large faults exists (ground faults on high resistance grounded systems excluded), the fault mustbe cleared as quickly as possible. It is therefore recommended that the time delay for short circuit and high ground faults beset to instantaneous. Then the duration for which the 369 CTs subjected to high withstand will be less than 250 ms (369reaction time is less than 50ms + breaker clearing time).
Care must be taken to ensure that the interrupting device is capable of interrupting the potential fault. Ifnot, some other method of interrupting the fault should be used, and the feature in question should be dis-abled (e.g. a fused contactor relies on fuses to interrupt large faults).
The 369 CTs were subjected to high currents for 1 second bursts. The CTs were capable of handling 500 A (500 A relatesto a 100 times the CT primary rating). If the time duration required is less than 1 second, the withstand level will increase.
b) CT SIZE AND SATURATION
The rating (as per ANSI/IEEE C57.13.1) for relaying class CTs may be given in a format such as: 2.5C100, 10T200, T1OO,10C50, or C200. The number preceding the letter represents the maximum ratio correction; no number in this positionimplies that the CT accuracy remains within a 10% ratio correction from 0 to 20 times rating.
The letter is an indication of the CT type:
• A 'C' (formerly L) represents a CT with a low leakage flux in the core where there is no appreciable effect on the ratiowhen used within the limits dictated by the class and rating. The 'C' stands for calculated; the actual ratio correctionshould be different from the calculated ratio correction by no more than 1%. A 'C' type CT is typically a bushing, win-dow, or bar type CT with uniformly distributed windings.
• A 'T' (formerly H) represents a CT with a high leakage flux in the core where there is significant effect on CT perfor-mance. The 'T' stands for test; since the ratio correction is unpredictable, it is to be determined by test. A 'T' type CT istypically primary wound with unevenly distributed windings. The subsequent number specifies the secondary termi-nal voltage that may be delivered by the full winding at 20 times rated secondary current without exceeding the ratiocorrection specified by the first number of the rating. (Example: a 10C100 can develop 100 V at 20 × 5 A, therefore anappropriate external burden would be 1 Ω or less to allow 20 times rated secondary current with less than 10% ratiocorrection.) Note that the voltage rating is at the secondary terminals of the CT and the internal voltage drop across thesecondary resistance must be accounted for in the design of the CT. There are seven voltage ratings: 10, 20, 50, 100,200, 400, and 800. If a CT comes close to a higher rating, but does not meet or exceed it, then the CT must be rated tothe lower value.
In order to determine how much current CTs can output, the secondary resistance of the CT is required. This resistance willbe part of the equation as far as limiting the current flow. This is determined by the maximum voltage that may be devel-oped by the CT secondary divided by the entire secondary resistance, CT secondary resistance included.
7.4.2 CT SELECTION
The 369 phase CT should be chosen such that the FLA (FLC) of the motor falls within 50 to 100% of the CT primary rating.For example, if the FLA of the motor is 173 A, a primary CT rating of 200, 250, or 300 can be chosen (200 being the betterchoice). This provides maximum protection of the motor.
The CT selected must then be checked to ensure that it can drive the attached burden (relay and wiring and any auxiliarydevices) at maximum fault current levels without saturating. There are essentially two ways of determining if the CT is beingdriven into saturation:
∴ CT secondary voltage = 0.476 × (6000 / (300 / 5)) = 47.6 V
From the CT class (C20): The amount of secondary voltage the CT can deliver to the load burden at 20 × CT withoutexceeding the 10% ratio error is 20 V. This application calls for 6000/300 = 20 × CT (Fault current / CT primary). Thusthe 10% ratio error may be exceeded.
The number in the CT class code refers to the guaranteed secondary voltage of the CT. Therefore, the maximum cur-rent that the CT can deliver can be calculated as follows:
maximum secondary current = CT class / Burden = 20 / 0.476 = 42.02 A
GE Power Management 369 Motor Management Relay 7-9
7 APPLICATIONS 7.5 PROGRAMMING EXAMPLE
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7.5 PROGRAMMING EXAMPLE 7.5.1 PROGRAMMING EXAMPLE
Information provided by a motor manufacturer can vary from nameplate information to a vast amount of data related toevery parameter of the motor. The table below shows selected information from a typical motor data sheet and Figure 7–2:MOTOR THERMAL LIMITS shows the related motor thermal limit curves. This information is required to set the 369 for aproper protection scheme.
The following is a example of how to determine the 369 setpoints. It is only a example and the setpoints should bedetermined based on the application and specific design of the motor.
Figure 7–2: MOTOR THERMAL LIMITS
Table 7–2: SELECTED INFORMATION FROM A TYPICAL MOTOR DATA SHEET
Driven equipment Reciprocating Compressor
Ambient Temperature min. –20°C; max. 41°C
Type or Motor Synchronous
Voltage 6000 V
Nameplate power 2300 kW
Service Factor 1
Insulation class F
Temperature rise stator / rotor 79 / 79 K
Max. locked rotor current 550% FLC
Locked rotor current% FLC 500% at 100% Voltage / 425% at 85% Voltage
Starting time 4 seconds at 100% Voltage / 6.5 seconds at 85% Voltage
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7.5 PROGRAMMING EXAMPLE 7 APPLICATIONS
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Phase CT
The phase CT should be chosen such that the FLC is 50% to 100% of CT primary. Since the FLC is 229 A a 250:5, 300:5,or 400:5 CT may be chosen (a 250:5 is the better choice).
229 / 0.50 = 458 or 229 / 1.00 = 229
Motor FLC
Set the Motor Full Load Current to 229A, as per data sheets.
Ground CT
For high resistive grounded systems, sensitive ground detection is possible with the 50:0.025 CT. On solidly grounded orlow resistive grounded systems where the fault current is much higher, a 1A or 5A CT should be used. If residual groundfault connection is to be used, the ground fault CT ratio most equal the phase CT ratio. The zero sequence CT chosenneeds to be able to handle all potential fault levels without saturating.
VT Settings
The motor is going to be connected in Wye, hence, the VT connection type will be programmed as Wye. Since the motorvoltage is 6000V, the VT being used will be 6000:120. The VT ratio to be programmed into the 369 will then be 50:1 (6000/120) and the Motor Rated Voltage will be programmed to 6000V, as per the motor data sheets.
Overload Pickup
The overload pickup is set to the same as the service factor of the motor. In this case, it would be set to the lowest settingof 1.01 x FLC for the service factor of 1.
Unbalance Bias Of Thermal Capacity
Enable the Unbalance Bias of Thermal Capacity so that the heating effect of unbalance currents is added to the ThermalCapacity Used.
Unbalance Bias K Factor
The K value is used to calculate the contribution of the negative sequence current flowing in the rotor due to unbalance. Itis defined as:
The 369 has the ability to learn the K value after five successful starts. After 5 starts, turn this setpoint off so that the 369uses the learned value
Hot/Cold Curve Ratio
The hot/cold curve ratio is calculated by simply dividing the hot safe stall time by the cold safe stall time. This informationcan be extracted from the Thermal Limit curves. From Figure 7–2: MOTOR THERMAL LIMITS, we can determine that thehot safe stall time is approximately 18 seconds and the cold safe stall time is approximately 24 seconds. Therefore, theHot/Cold curve ratio should be programmed as 0.75 (18 / 24) for this example.
Running and Stopped Cool Time Constant
The running cool time is the time required for the motor to cool while running. This information is usually supplied by themotor manufacturer but is not part of the given data. The motor manufacturer should be contacted to find out what the cooltimes are.
GE Power Management 369 Motor Management Relay 7-11
7 APPLICATIONS 7.5 PROGRAMMING EXAMPLE
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The Thermal Capacity Used quantity decays exponentially to simulate the cooling of the motor. The rate of cooling is basedupon the running cool time constant when the motor is running, or the stopped cool time constant when the motor isstopped. The entered cool time constant is one fifth the total cool time from 100% thermal capacity used down to 0% ther-mal capacity used.
The 369 has a unique capability of learning the cool time constant. This learned parameter is only functional if the StatorRTDs are connected to the 369. The learned cool time algorithm observes the temperature of the motor as it cools, thusdetermining the length of time required for cooling. If the cool times can not be retrieved from the motor manufacturer, thenthe Learned Cool Time must be enabled (if the stator RTDs are connected).
Motors have a fanning action when running due to the rotation of the rotor. For this reason, the running cool time is typicallyhalf of the stopped cool time.
Refer to the Selection of Cool Time application note for more details on how to determine the cool time constants when notprovided with the motor.
RTD Biasing
This will enable the temperature from the Stator RTD sensors to be included in the calculations of Thermal Capacity. Thismodel determines the Thermal Capacity Used based on the temperature of the Stators and is a separate calculation fromthe overload model for calculating Thermal Capacity Used. RTD biasing is a back up protection element which accounts forsuch things as loss of cooling or unusually high ambient temperature. There are three parameters to set: RTD Bias Min,RTD Bias Mid, RTD Bias Max.
RTD Bias Minimum
Set to 40°C which is the ambient temperature (obtained from data sheets).
RTD Bias Mid Point
The center point temperature is set to the motor’s hot running temperature and is calculated as follows:
Temperature Rise of Stator + Ambient Temperature.
The temperature rise of the stator is 79°K, obtained from the data sheets. Therefore, the RTD Center point temperature isset to 120°C (79 + 40).
RTD Bias Maximum
This setpoint is set to the rating of the insulation or slightly less. A class F insulation is used in this motor which is rated at155°C.
Overload Curve
If only one thermal limit curve is provided, the chosen overload curve should fit below it. When a hot and cold thermal limitcurve is provided, the chosen overload curve should fit between the two curves and the programmed Hot/Cold ratio is usedin the Thermal Capacity algorithm to take into account the thermal state of the motor. The best fitting 369 standard curve iscurve # 4, as seen in Figure 7–2: MOTOR THERMAL LIMITS on page 7–9.
Short Circuit Trip
The short circuit trip should be set above the maximum locked rotor current but below the short circuit current of the fuses.The data sheets indicate a maximum locked rotor current of 550% FLC or 5.5 × FLC. A setting of 6 × FLC with a instanta-neous time delay will be ideal but nuisance tripping may result due to unusually high demanding starts or starts while theload is coupled. If need be, set the S/C level higher to a maximum of 8 × FLC to override these conditions.
Mechanical Jam
If the process causes the motor to be prone to mechanical jams, set the Mechanical Jam Trip and Alarm accordingly. Inmost cases, the overload trip will become active before the Mechanical Trip, however, if a high overload curve is chosen,the Mechanical Jam level and time delay become more critical. The setting should then be set to below the overload curvebut above any normal overload conditions of the motor. The main purpose of the mechanical jam element is to protect thedriven equipment due to jammed, or broken equipment.
Undercurrent
If detection of loss of load is required for the specific application, set the undercurrent element according to the current thatwill indicate loss of load. For example, this could be programmed for a pump application to detect loss of fluid in the pipe.
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7.5 PROGRAMMING EXAMPLE 7 APPLICATIONS
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Unbalance Alarm and Trip
The unbalance settings are determined by examining the motor application and motor design. In this case, the motor beingprotected is a reciprocating compressor, in which unbalance will be a normal running condition, thus this setting should beset high. A setting of 20% for the Unbalance Alarm with a delay of 10 seconds would be appropriate and the trip may be setto 25% with a delay of 10 seconds
Ground Fault
Unfortunately, there is not enough information to determine a ground fault setting. These settings depend on the followinginformation:
1. The Ground Fault current available.
2. System Grounding - high resistive grounding, solidly grounded, etc.
3. Ground Fault CT used.
4. Ground Fault connection - zero sequence or Residual connection.
Acceleration Trip
This setpoint should be set higher than the maximum starting time to avoid nuisance tripping when the voltage is lower orfor varying loads during starting. If reduced voltage starting is used, a setting of 8 seconds would be appropriate, or if directacross the line starting is used, a setting of 5 seconds could be used.
Start Inhibit
This function should always be enabled after five successful starts to protect the motor during starting while it is alreadyhot. The 369 learns the amount of thermal capacity used at start. If the motor is hot, thus having some thermal capacity, the369 will not allow a start if the available thermal capacity is less than the required thermal capacity for a start. For moreinformation regarding start inhibit refer to application note in section 7.6.6.
Starts/Hour
Starts/Hour can be set to the # of cold starts as per the data sheet. For this example, the starts/hour would be set to 3.
Time Between Starts
In some cases, the motor manufacturer will specify the time between motor starts. In this example, this information is notgiven so this feature can be turned “Off”. However, if the information is given, the time provided on the motor data sheetsshould be programmed.
Stator RTDs
RTD trip level should be set at or below the maximum temperature rating of the insulation. This example has a class F insu-lation which has a temperature rating of 155°C, therefore the Stator RTD Trip level should be set to between 140°C to155°C. The RTD alarm level should be set to a level to provide a warning that the motor temperature is rising. For thisexample, 120°C or 130°C would be appropriate.
Bearing RTDs
The Bearing RTD alarm and trip settings will be determined by evaluating the temperature specification from the bearingmanufacturer.
GE Power Management 369 Motor Management Relay 7-13
7 APPLICATIONS 7.6 APPLICATIONS
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7.6 APPLICATIONS 7.6.1 MOTOR STATUS DETECTION
The 369 detects a stopped motor condition when the phase current falls below 5% of CT, and detects a starting motor con-dition when phase current is sensed after a stopped motor condition. If the motor idles at 5% of CT, several starts and stopscan be detected causing nuisance lockouts if Starts/Hour, Time Between Starts, Restart Block, Start Inhibit, or BackspinTimer are programmed. As well, the learned values, such as the Learned Starting Thermal Capacity, Learned Starting Cur-rent and Learned Acceleration time can be incorrectly calculated.
To overcome this potential problem, the Spare Digital Input can be configured to read the status of the breaker and deter-mine whether the motor is stopped or simply idling. With the spare input configured as Starter Status and the breaker aux-iliary contacts wired across the spare input terminals, the 369 senses a stopped motor condition only when the phasecurrent is below 5% of CT (or zero) AND the breaker is open. If both of these conditions are not met, the 369 will continueto operate as if the motor is running and the starting elements remain unchanged. Refer to the flowchart below for details ofhow the 369 detects motor status and how the starter status element further defines the condition of the motor.
When the Starter Status is programmed, the type of breaker contact being used for monitoring must be set. The followingare the states of the breaker auxiliary contacts in relation to the breaker:
• 52a, 52aa - open when the breaker contacts are open and closed when the breaker contacts are closed
• 52b, 52bb - closed when the breaker contacts are open and open when the breaker contacts are closed
Figure 7–3: FLOWCHART SHOWING HOW MOTOR STATUS IS DETERMINED
7-14 369 Motor Management Relay GE Power Management
7.6 APPLICATIONS 7 APPLICATIONS
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7.6.2 SELECTION OF COOL TIME CONSTANTS
Thermal limits are not a black and white science and there is some art to setting a protective relay thermal model. The def-inition of thermal limits mean different things to different manufacturers and quite often, information is not available. There-fore, it is important to remember what the goal of the motor protection thermal modeling is: to thermally protect the motor(rotor and stator) without impeding the normal and expected operating conditions that the motor will be subject to.
The thermal model of the 369 provides integrated rotor and stator heating protection. If cooling time constants are suppliedwith the motor data they should be used. Since the rotor and stator heating and cooling is integrated into a single model,use the longer of the cooling time constants (rotor or stator).
If however, no cooling time constants are provided, settings will have to be determined. Before determining the cool timeconstant settings, the duty cycle of the motor should be considered. If the motor is typically started and run continuously forvery long periods of time with no overload duty requirements, the cooling time constants can be large. This would make thethermal model conservative. If the normal duty cycle of the motor involves frequent starts and stops with a periodic over-load duty requirement, the cooling time constants will need to be shorter and closer to the actual thermal limit of the motor.
Normally motors are rotor limited during starting. Thus RTDs in the stator do not provide the best method of determiningcool times. Determination of reasonable settings for the running and stopped cool time constants can be accomplished inone of the following manners listed in order of preference.
1. The motor running and stopped cool times or constants may be provided on the motor data sheets or by the manufac-turer if requested. Remember that the cooling is exponential and the time constants are one fifth the total time to gofrom 100% thermal capacity used to 0%.
2. Attempt to determine a conservative value from available data on the motor. See the following example for details.
3. If no data is available an educated guess must be made. Perhaps the motor data could be estimated from other motorsof a similar size or use. Note that conservative protection is better as a first choice until a better understanding of themotor requirements is developed. Remember that the goal is to protect the motor without impeding the operating dutythat is desired.
EXAMPLE:
Motor data sheets state that the starting sequence allowed is 2 cold or 1 hot after which you must wait 5 hours beforeattempting another start.
• This implies that under a normal start condition the motor is using between 34 and 50% thermal capacity. Hence, twoconsecutive starts are allowed, but not three (i.e. 34 × 3 > 100).
• If the hot and cold curves or a hot/cold safe stall ratio are not available program 0.5 (1 hot / 2 cold starts) in as the hot/cold ratio.
• Programming Start Inhibit ‘On’ makes a restart possible as soon as 62.5% (50 × 1.25) thermal capacity is available.
• After 2 cold or 1 hot start, close to 100% thermal capacity will be used. Thermal capacity used decays exponentially(see 369 manual section on motor cooling for calculation). There will be only 37% thermal capacity used after 1 timeconstant which means there is enough thermal capacity available for another start. Program 60 minutes (5 hours) asthe stopped cool time constant. Thus after 2 cold or 1 hot start, a stopped motor will be blocked from starting for 5hours.
Since the rotor cools faster when the motor is running, a reasonable setting for the running cool time constant might be halfthe stopped cool time constant or 150 minutes.
GE Power Management 369 Motor Management Relay 7-15
7 APPLICATIONS 7.6 APPLICATIONS
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7.6.3 THERMAL MODEL
Figure 7–4: THERMAL MODEL BLOCK DIAGRAM
LEGENDU/B..........................UnbalanceI/P ...........................InputIavg.........................Average Three Phase CurrentIeq...........................Equivalent Average Three Phase CurrentIp.............................Positive Sequence CurrentIn.............................Negative Sequence CurrentK .............................Constant Multiplier that Equates In to IpFLC.........................Full Load CurrentFLC TCR ................FLC Thermal Capacity Reduction SetpointTC...........................Thermal Capacity usedRTD BIAS TC .........TC Value looked up from RTD Bias Curve
If Unbalance input to thermal memory is enabled, the increase in heating is reflected in the thermal model.If RTD Input to Thermal Memory is enabled, the feed-back from the RTDs will correct the thermal model.
start
U/B I/P toThermal Memory
Enabled?
Ieq = Iavg
Ieq >FLC x O/LPickup ?
Ieq > FLC
TC <FLC TCR X(Iavg/FLC)
Decrement TC toFLC TCR x (Iavg/FLC) as per
the rate defined by User's CoolRate or Learned Cool Rate
RTD BIASENABLED?
end
Add to TC as per Ieqand O/L Curve
TC >FLC TCR x(Iavg/FLC)
Add 6% TC per Minute unt i lTC = FLC TCR x (Iavg/FLC)
7-16 369 Motor Management Relay GE Power Management
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7.6.4 RTD BIAS FEATURE
Figure 7–5: RTD BIAS FEATURE
LEGEND
Tmax.......................RTD Bias Maximum Temperature ValueTmin........................RTD Bias Minimum Temperature ValueHottest RTD ............Hottest Stator RTD measuredTC ...........................Thermal Capacity UsedTC RTD...................Thermal Capacity Looked up on RTD Bias Curve.TC Model ................Thermal Capacity based on the Thermal Model
GE Power Management 369 Motor Management Relay 7-17
7 APPLICATIONS 7.6 APPLICATIONS
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7.6.5 THERMAL CAPACITY USED CALCULATION
The overload element uses a Thermal Capacity algorithm to determine an overload trip condition. The extent of overloadcurrent determines how fast the Thermal Memory is filled, i.e. if the current is just over FLC × O/L Pickup, Thermal Capacityslowly increases; versus if the current far exceeds the FLC pickup level, the Thermal Capacity rapidly increases. An over-load trip occurs when the Thermal Capacity Used reaches 100%.
The overload current does not necessarily have to pass the overload curve for a trip to take place. If there is ThermalCapacity already built up, the overload trip will occur much faster. In other words, the overload trip will occur at the specifiedtime on the curve only when the Thermal Capacity is equal to zero and the current is applied at a stable rate. Otherwise, theThermal Capacity increases from the value prior to overload, until a 100% Thermal Capacity is reached and an overloadtrip occurs.
It is important to chose the overload curve correctly for proper protection. In some cases it is necessary to calculate theamount of Thermal Capacity developed after a start. This is done to ensure that the 369 does not trip the motor prior to thecompletion of a start. The actual filling of the Thermal Capacity is the area under the overload current curve. Therefore, tocalculate the amount of Thermal Capacity after a start, the integral of the overload current most be calculated. Below is anexample of how to calculate the Thermal Capacity during a start:
Thermal Capacity Calculation:
1. Draw lines intersecting the acceleration curve and the overload curve. This is illustrated in Figure 7–6: THERMALLIMIT CURVES on page 7–18.
2. Determine the time at which the drawn line intersect, the acceleration curve and the time at which the drawn line inter-sects the chosen overload curve.
3. Integrate the values that have been determined.
Therefore, after this motor has completed a successful start, the Thermal Capacity would have reached approximately40%.
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Figure 7–6: THERMAL LIMIT CURVES
Thermal limit curves illustrate thermal capacity used calculation during a start.
7.6.6 START INHIBIT
The Start Inhibit element of the 369 provides an accurate and reliable start protection without unnecessary prolonged lock-out times causing production down time. The lockout time is based on the actual performance and application of the motorand not on the worst case scenario, as other start protection elements.
The 369 Thermal Capacity algorithm is used to establish the lockout time of the Start Inhibit element. Thermal Capacity is apercentage value that gives an indication of how hot the motor is and is derived from the overload currents (as well asUnbalance currents and RTDs if the respective biasing functions are enabled). The easiest way to understand the ThermalModeling function of the 369 is to image a bucket that holds Thermal Capacity. Once this imaginary bucket is full, an over-load trip occurs. The bucket is filled by the amount of overload current integrated over time and is compared to the pro-grammed overload curve to obtain a percentage value. The thermal capacity bucket is emptied based on the programmedrunning cool time when the current has fallen below the Full Load Current (FLC) and is running normally.
GE Power Management 369 Motor Management Relay 7-19
7 APPLICATIONS 7.6 APPLICATIONS
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Upon a start, the inrush current is very high, causing the thermal capacity to rapidly increase. The Thermal Capacity Usedvariable is compared to the amount of the Thermal Capacity required to start the motor. If there is not enough thermalcapacity available to start the motor, the 369 blocks the operator from starting until the motor has cooled to a level of ther-mal capacity to successfully start.
Assume that a motor requires 40% Thermal Capacity to start. If the motor was running in overload prior to stopping, thethermal capacity would be some value; say 80%. Under such conditions the 369 (with Start Inhibit enabled) will lockout orprevent the operator from starting the motor until the thermal capacity has decreased to 60% so that a successful motorstart can be achieved. This example is illustrated in Figure 7–7: ILLUSTRATION OF THE START INHIBIT FUNCTIONAL-ITY on page 7–19.
The lockout time is calculated as follows:
where:
The INITIAL START CAPACITY setpoint provides a value to be used instead of the TC_learned value until the relay hasobserved the five successful starts and can determine a learned value. After the initial five starts, the INITIAL STARTCAPACITY setpoint is ignored and learned value is automatically used. The learned start capacity is then updated everyfour starts. A safe margin is built into the calculation of the LEARNED START CAPACITY REQUIRED to ensure successfulcompletion of the longest and most demanding starts. The Learned Start Capacity is calculated as follows:
where: Start_TC1 = the thermal capacity required for the first startStart_TC2 = the thermal capacity required for the second start, etc.
Figure 7–7: ILLUSTRATION OF THE START INHIBIT FUNCTIONALITY
TC_used = Thermal Capacity Used
TC_learned = Learned Thermal Capacity required to start
stopped_cool_time = one of two variables will be used:1. Learned cool time is enabled, or2. Programmed stopped cool time
lockout time stopped_cool_time_constant TCused100 TClearned–--------------------------------------------
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7.6.7 2φ CT CONFIGURATION
This section illustrates how to use two CTs to sense three phase currents.
The proper configuration for using two CTs rather than three to detect phase current is shown below. Each of the two CTsacts as a current source. The current from the CT on phase ‘A’ flows into the interposing CT on the relay marked ‘A’. Fromthere, the it sums with the current flowing from the CT on phase ‘C’ which has just passed through the interposing CT onthe relay marked ‘C’. This ‘summed’ current flows through the interposing CT marked ‘B’ and splits from there to return toits respective source (CT). Polarity is very important since the value of phase ‘B’ must be the negative equivalent of'A' + 'C' for the sum of all the vectors to equate to zero. Note that there is only one ground connection. Making twoground connections creates a parallel path for the current
Figure 7–8: TWO PHASE WIRING
In the two CT configuration, the currents sum vectorially at the common point of the two CTs. The following diagram illus-trates the two possible configurations. If one phase is reading high by a factor of 1.73 on a system that is known to be bal-anced, simply reverse the polarity of the leads at one of the two phase CTs (taking care that the CTs are still tied to groundat some point). Polarity is important.
Figure 7–9: VECTORS SHOWING REVERSE POLARITY
To illustrate the point further, the diagram here shows how the current in phases 'A' and 'C' sum up to create phase 'B'.
Figure 7–10: RESULTANT PHASE CURRENT - CORRECTLY WIRED 2 φ CT SYSTEM
GE Power Management 369 Motor Management Relay 7-21
7 APPLICATIONS 7.6 APPLICATIONS
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Once again, if the polarity of one of the phases is out by 180°, the magnitude of the resulting vector on a balanced systemwill be out by a factor of 1.73.
Figure 7–11: RESULTANT PHASE CURRENT - INCORRECTLY WIRED 2 φ CT SYSTEM
On a three wire supply, this configuration will always work and unbalance will be detected properly. In the event of a singlephase, there will always be a large unbalance present at the interposing CTs of the relay. If for example phase ‘A’ was lost,phase ‘A’ would read zero while phases ‘B’ and ‘C’ would both read the magnitude of phase ‘C’. If on the other hand, phase‘B’ was lost, at the supply, ‘A’ would be 180× out of phase with phase ‘C’ and the vector addition would be zero at phase ‘B’.
7.6.8 GROUND FAULT DETECTION ON UNGROUNDED SYSTEMS
The 50:0.025 ground fault input is designed for sensitive detection of faults on a high resistance grounded system. Detec-tion of ground currents from 1 to 10 A primary translates to an input of 0.5 mA to 5 mA into the 50:0.025 tap. Understandingthis allows the use of this input in a simple manner for the detection of ground faults on ungrounded systems.
The following diagram illustrates how to use a wye-open delta voltage transformer configuration to detect phase grounding.Under normal conditions, the net voltage of the three phases that appears across the 50:0.025 input and the resistor isclose to zero. Under a fault condition, assuming the secondaries of the VTs to be 69 V, the net voltage seen by the relayand the resistor is 3Vo or 3 × 69 V = 207 V.
Figure 7–12: GROUND FAULT DETECTION ON UNGROUNDED SYSTEMS
Since the wire resistance should be relatively small in comparison to the resistor chosen, the current flow will be a functionof the fault voltage seen on the open delta transformer divided by the chosen resistor value plus the burden of the 50:0.025input (1200 Ω).
EXAMPLE:
If a pickup range of 10 to 100 V is desired, the resistor should be chosen as follows:
7-22 369 Motor Management Relay GE Power Management
7.6 APPLICATIONS 7 APPLICATIONS
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1. 1 to 10 A pickup on the 2000:1 tap = 0.5 mA – 5 mA.
2. 10 V / 0.5 mA = 20 kΩ.
3. If the resistor chosen is 20 kΩ – 1.2 kΩ = 18.8 kΩ, the wattage should be greater than E2/R, approximately (207 V)2 /18.8 kΩ = 2.28 W. Therefore, a 5 W resistor will suffice.
The VTs must have a primary rating equal or greater than the line to line voltage, as this is the voltagethat will be seen by the unfaulted inputs in the event of a fault.
7.6.9 RTD CIRCUITRY
This section illustrates the functionality of the RTD circuitry in the 369 Motor Protection Relay.
Figure 7–13: RTD CIRCUITRY
A constant current source sends 3 mA DC down legs A and C. A 6 mA DC current returns down leg B. It may be seen that:
or
The above holds true providing that all three leads are the same length, gauge, and material, hence the same resistance.
or
Electronically, subtracting VAB from VBC leaves only the voltage across the RTD. In this manner lead length is effectivelynegated:
NOTE
RTD
COMPENSATION3 mA
RETURN6 mA
HOT840733A1.CDRC
B
A
3 mA
VAB VLeadA VLeadB+=( ) and VCB VLeadC VRTD VLeadB+ +=
VAB Vcomp Vreturn+=( ) and VCB Vhot VRTD Vreturn+ +=
GE Power Management 369 Motor Management Relay 7-23
7 APPLICATIONS 7.6 APPLICATIONS
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7.6.10 REDUCED RTD LEAD NUMBER APPLICATION
The 369 requires three leads to be brought back from each RTD: Hot, Return, and Compensation. In certain situations thiscan be quite expensive. However, it is possible to reduce the number of leads so that three are required for the first RTDand only one for each successive RTD. Refer to the following diagram for wiring configuration.
Figure 7–14: REDUCED WIRING RTDs
The Hot line for each RTD is run as usual for each RTD. However, the Compensation and Return leads need only be run forthe first RTD. At the motor RTD terminal box, connect the RTD Return leads together with as short as possible jumpers. Atthe 369 relay, the Compensation leads must be jumpered together.
Note that an error is produced on each RTD equal to the voltage drop across the RTD return jumper. This error increasesfor each successive RTD added as:
VRTD1 = VRTD1
VRTD2 = VRTD2 + VJ3
VRTD3 = VRTD3 + VJ3 + VJ4
VRTD4 = VRTD4 + VJ3+ VJ4 + VJ5, etc....
This error is directly dependent on the length and gauge of the jumper wires and any error introduced by a poor connection.For RTD types other than 10C, the error introduced by the jumpers is negligible.
Although this RTD wiring technique reduces the cost of wiring, the following disadvantages must be noted:
1. There is an error in temperature readings due to lead and connection resistances. Not recommended for 10C RTDs.
2. If the RTD Return lead to the 369 or one of the jumpers breaks, all RTDs from the point of the break onwards will readopen.
3. If the Compensation lead breaks or one of the jumpers breaks, all RTDs from the point of the break onwards will func-tion without any lead compensation.
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7.6.11 TWO WIRE RTD LEAD COMPENSATION
An example of how to add lead compensation to a two wire RTD is shown below.
Figure 7–15: 2 WIRE RTD LEAD COMPENSATION
The compensation lead would be added and it would compensate for the Hot and the Return assuming they are all of equallength and gauge. To compensate for resistance of the Hot and Compensation leads, a resistor equal to the resistance ofthe Hot lead could be added to the compensation lead, though in many cases this is unnecessary.
7.6.12 AUTO TRANSFORMER STARTER WIRING
Figure 7–16: AUTO TRANSFORMER, REDUCED VOLTAGE STARTING CIRCUIT
GE Power Management 369 Motor Management Relay 8-1
8 TESTING 8.1 TEST SETUP
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8 TESTING 8.1 TEST SETUP 8.1.1 INTRODUCTION
This chapter demonstrates the procedures necessary to perform a complete functional test of all the 369 hardware whilealso testing firmware/hardware interaction in the process. Testing of the relay during commissioning using a primary injec-tion test set will ensure that CTs and wiring are correct and complete.
8-2 369 Motor Management Relay GE Power Management
8.2 HARDWARE FUNCTIONAL TESTING 8 TESTING
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8.2 HARDWARE FUNCTIONAL TESTING 8.2.1 PHASE CURRENT ACCURACY TEST
The 369 specification for phase current accuracy is ±0.5% of 2 × CT when the injected current is less than 2 × CT. Performthe steps below to verify accuracy.
2. Measured values should be within ±10A of expected. Inject the values shown in the table below and verify accuracy ofthe measured values. View the measured values in:
ACTUAL VALUES A2:\METERING DATA\CURRENT METERING
8.2.2 VOLTAGE INPUT ACCURACY TEST
The 369 specification for voltage input accuracy is ±1.0% of full scale (240 V). Perform the steps below to verify accuracy.
2. Measured values should be within ±24 V (±1 × 240 × 10) of expected. Apply the voltage values shown in the table andverify accuracy of the measured values. View the measured values in:
GE Power Management 369 Motor Management Relay 8-3
8 TESTING 8.2 HARDWARE FUNCTIONAL TESTING
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8.2.3 GROUND (1A/5A) ACCURACY TEST
The 369 specification for the 1 A/5 A ground current input accuracy is ±0.5% of 1 × CT for the 5 A input and ±0.5% of 5 × CTfor the 1 A input. Perform the steps below to verify accuracy.
2. Measured values should be ±5 A. Inject the values shown in the table below into one phase only and verify accuracy ofthe measured values. View the measured values in A2: METERING DATA\CURRENT METERING
2. Measured values should be ±25 A. Inject the values shown in the table below into one phase only and verify accuracyof the measured values. View the measured values in A2:\METERING DATA\CURRENT METERING
8.2.4 50:0.025 GROUND ACCURACY TEST
The 369 specification for GE Power Management 50:0.025 ground current input accuracy is ±0.5% of CT rated primary(25 A). Perform the steps below to verify accuracy.
2. Measured values should be within ±0.125 A of expected. Inject the values shown below either as primary values into aGE Power Management 50:0.025 Core Balance CT or as secondary values that simulate the core balance CT. Verifyaccuracy of the measured values. View the measured values in A2:\METERING DATA\CURRENT METERING
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8.2 HARDWARE FUNCTIONAL TESTING 8 TESTING
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8.2.5 RTD ACCURACY TEST
1. The 369 specification for RTD input accuracy is ±2°. Alter the following setpoints:
SETPOINT S6:RTD TEMPERATURE \ RTD TYPE \ STATOR RTD TYPE: 100 ohm Platinum (select desired type)
2. Measured values should be ±2°C or ±4°F. Alter the resistances applied to the RTD inputs as per the table below tosimulate RTDs and verify accuracy of the measured values. View the measured values in:
ACTUAL VALUES A2:\METERING DATA\ LOCAL RTD (and/or REMOTE RTD if using the RRTD Module)
3. Select the preferred temperature units for the display. Alter the following setpoint:
SETPOINT S1: 369 SETUP \ DISPLAY PREFERENCES \ TEMPERATURE DISPLAY: Celsius (or Fahrenheit if preferred)
4. Repeat the above measurements for the other RTD types (120 Ω Nickel, 100 Ω Nickel and 10 Ω Copper)
GE Power Management 369 Motor Management Relay 8-5
8 TESTING 8.2 HARDWARE FUNCTIONAL TESTING
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8.2.6 DIGITAL INPUTS AND TRIP COIL SUPERVISION
The digital inputs and trip coil supervision can be verified easily with a simple switch or pushbutton. Perform the stepsbelow to verify functionality of the digital inputs.
1. Open switches of all of the digital inputs and the trip coil supervision circuit.
2. View the status of the digital inputs and trip coil supervision in A1: \ STATUS \ DIGITAL INPUT STATUS
3. Close switches of all of the digital inputs and the trip coil supervision circuit.
4. View the status of the digital inputs and trip coil supervision in A1: \ STATUS \ DIGITAL INPUT STATUS
8.2.7 ANALOG INPUTS AND OUTPUTS
The 369 specification for analog input and analog output accuracy is ±1% of full scale. Perform the steps below to verifyaccuracy.
4 to 20mA ANALOG INPUT:
1. Alter the following setpoints:
SETPOINT S10:ANALOG OUTPUTS \ ANALOG OUTPUT 1 \ ANALOG RANGE: 4-20 mA (repeat for analog inputs 2 to 4)
2. Analog output values should be ±0.2 mA on the ammeter. Force the analog outputs using the following setpoints:
SETPOINT S11:TESTING\TEST ANALOG OUTPUTS \ FORCE ANALOG OUTPUT 1: 0% (enter desired percent, repeat for analog outputs 2 to 4)
3. Verify the ammeter readings for all the analog outputs
4. Repeat 1 to 3 for the other forced output settings
0 to 1mA ANALOG INPUT:
1. Alter the following setpoints:
SETPOINT S10:ANALOG OUTPUTS \ ANALOG OUTPUT 1 \ ANALOG RANGE: 0-1 mA (repeat for analog inputs 2 to 4)
2. Analog output values should be ±0.01 mA on the ammeter. Force the analog outputs using the following setpoints:
SETPOINT S11:TESTING\TEST ANALOG OUTPUTS \ FORCE ANALOG OUTPUT 1: 0%(enter desired percent, repeat for analog outputs 2 to 4)
3. Verify the ammeter readings for all the analog outputs
4. Repeat 1 to 3 for the other forced output settings.
GE Power Management 369 Motor Management Relay 8-7
8 TESTING 8.3 ADDITIONAL FUNCTIONAL TESTING
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8.3 ADDITIONAL FUNCTIONAL TESTING 8.3.1 OVERLOAD CURVE TEST
The 369 specification for overload curve timing accuracy is ±100 ms or ±2% of time to trip. Pickup accuracy is as per cur-rent inputs (±0.5% of 2 × CT when the injected current is < 2 × CT; ±1% of 20 × CT when the injected current is ≥ 2 × CT).
1. Perform the steps below to verify accuracy. Alter the following setpoints:
SETPOINT S2:SYSTEM SETUP \ CT / VT SETUP \ PHASE CT PRIMARY: 1000SETPOINT S2:SYSTEM SETUP \ CT / VT SETUP \ MOTOR FULL LOAD AMPS FLA: 1000SETPOINT S3:OVERLOAD PROTECTION \ OVERLOAD CURVES \ SELECT CURVE STYLE: StandardSETPOINT S3: OVERLOAD PROTECTION \ OVERLOAD CURVES \ STANDARD OVELOAD CURVE NUMBER: 4SETPOINT S3: OVERLOAD PROTECTION \ THERMAL MODEL \ OVERLOAD PICKUP LEVEL: 1.10SETPOINT S3: OVERLOAD PROTECTION \ THERMAL MODEL \ UNBALANCE BIAS K FACTOR: 0SETPOINT S3: OVERLOAD PROTECTION \ THERMAL MODEL \ HOT / COLD SAFE STALL RATIO: 1.00SETPOINT S3: OVERLOAD PROTECTION \ THERMAL MODEL \ ENABLE RTD BIASING: No
2. Any trip must be reset prior to each test. Short the emergency restart terminals momentarily immediately prior to eachoverload curve test to ensure that the thermal capacity used is zero. Failure to do so will result in shorter trip times.Inject the current of the proper amplitude to obtain the values as shown and verify the trip times. Motor load may beviewed in A2:\METERING DATA\CURRENT METERING
Thermal capacity used and estimated time to trip may be viewed in A1:\STATUS\MOTOR STATUS
8.3.2 POWER MEASUREMENT TEST
The 369 specification for reactive and apparent power is ±1.5% of 2 × CT × VT full scale @ Iavg < 2 × CT. Perform the stepsbelow to verify accuracy.
2. Inject current and apply voltage as per the table below. Verify accuracy of the measured values. View the measuredvalues in A2:\METERING DATA\POWER METERING
AVERAGE PHASE CURRENT
DISPLAYED
INJECTED CURRENT1 A UNIT
PICKUP LEVEL
EXPECTED TIME TO TRIP
TOLERANCE RANGE MEASURED TIME TO TRIP
1050 A 1.05 A 1.05 never N/A
1200 A 1.20 A 1.20 795.44 s 779.53 to 811.35 s
1750 A 1.75 A 1.75 169.66 s 166.27 to 173.05 s
3000 A 3.0 A 3.00 43.73 s 42.86 to 44.60 s
6000 A 6.0 A 6.00 9.99 s 9.79 to 10.19 s
10000 A 10.0 A 10.00 5.55 s 5.44 to 5.66 s
INJECTED CURRENT / APPLIED VOLTAGE (Ia is reference vector)
8-8 369 Motor Management Relay GE Power Management
8.3 ADDITIONAL FUNCTIONAL TESTING 8 TESTING
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8.3.3 VOLTAGE PHASE REVERSAL TEST
The 369 can detect voltage phase rotation and protect against phase reversal. To test the phase reversal element, performthe following steps:
1. Alter the following setpoints:
SETPOINT S2:SYSTEM SETUP \ CT / VT SETUP \ VT CONNECTION TYPE: Wye or Open DeltaSETPOINT S7:VOLTAGE ELEMENTS \ PHASE REVERSAL \ PHASE REVERSAL TRIP: OnSETPOINT S7:VOLTAGE ELEMENTS \ PHASE REVERSAL \ ASSIGN TRIP RELAYS: TripSETPOINT S2: SYSTEM SETUP \ CT / VT SETUP \ SYSTEM PHASE SEQUENCE: ABC
2. Apply voltages as per the table below. Verify the 369 operation on voltage phase reversal.
8.3.4 SHORT CIRCUIT TEST
The 369 specification for short circuit timing is +40 ms or ±0.5% of total time. The pickup accuracy is as per the phase cur-rent inputs. Perform the steps below to verify the performance of the short circuit element.
1. Alter the following setpoints:
SETPOINT S2:SYSTEM SETUP \ CT / VT SETUP \ PHASE CT PRIMARY: 1000SETPOINT S4:CURRENT ELEMENTS \ SHORT CIRCUIT \ SHORT CIRCUIT TRIP: OnSETPOINT S4:CURRENT ELEMENTS \ SHORT CIRCUIT \ ASSIGN TRIP RELAYS: TripSETPOINT S4:CURRENT ELEMENTS \ SHORT CIRCUIT \ SHORT CIRCUIT PICKUP LEVEL: 5.0 x CTSETPOINT S4:CURRENT ELEMENTS \ SHORT CIRCUIT \ ADD S/C DELAY: 0
2. Inject current as per the table below, resetting the unit after each trip by pressing the [RESET] key, and verify timingaccuracy. Pre-trip values may be viewed in
ACTUAL VALUES A1: STATUS \ LAST TRIP DATA
APPLIED VOLTAGE EXPECTED RESULT88 NO TRIP99 PHASE REVERSAL TRIP
The hardware or electrical interface is one of the following:
• one of three 2-wire RS485 ports from the rear terminal connector,
• the RS232 from the front panel connector
• a fibre optic connection.
In a 2-wire RS485 link, data flow is bidirectional. Data flow is half duplex for both the RS485 and the RS232 ports. That is,data is never transmitted and received at the same time. RS485 lines should be connected in a daisy chain configuration(avoid star connections) with a terminating network installed at each end of the link, i.e. at the master end and at the slavefarthest from the master. The terminating network should consist of a 120 Ω resistor in series with a 1 nF ceramic capacitorwhen used with Belden 9841 RS485 wire. The value of the terminating resistors should be equal to the characteristicimpedance of the line. This is approximately 120 Ω for standard #22 AWG twisted pair wire. Shielded wire should always beused to minimize noise. Polarity is important in RS485 communications. Each '+' terminal of every 369 must be connectedtogether for the system to operate. See Section 3.3.14: RS485 COMMUNICATIONS on page 3–13 for details on correctserial port wiring.
When using a fibre optic link the Tx from the 369 should be connected to the Rx of the Master device and the Rx from the369 should be connected to the Tx of the Master device.
10.1.2 PROFIBUS COMMUNICATIONS
The 369 Motor Management Relay supports Profibus-DP protocol as slave that can be read and written to, from a Profibus-DP master which can read DMD file in the form of 369_xxxx.gs* files.
The relay supports the following configurations and indications:
• Fieldbus type: PROFIBUS-DP EN 50170 (DIN 19245) Part 3.
• Extended functions supported: Diagnostics Data via mailbox telegram.
• Auto baud rate detection 9.6Kbit - 12Mbit.
• Address range: 1-126, setting via 369PC Program or front keypad.
• Input data: 220 bytes - cyclical.
• Diagnostic data: 26 bytes - non-cyclical.
See Section 10.2: PROFIBUS PROTOCOL on page 10–2 for complete details.
10.1.3 MODBUS COMMUNICATIONS
The 369 implements a subset of the AEG Modicon Modbus RTU serial communication standard. Many popular program-mable controllers support this protocol directly with a suitable interface card allowing direct connection of relays. Althoughthe Modbus protocol is hardware independent, the 369 interfaces include three 2-wire RS485 ports and one RS232 port.Modbus is a single master, multiple slave protocol suitable for a multi-drop configuration as provided by RS485 hardware.In this configuration up to 32 slaves can be daisy-chained together on a single communication channel.
The 369 is always a slave. It cannot be programmed as a master. Computers or PLCs are commonly programmed as mas-ters. The Modbus protocol exists in two versions: Remote Terminal Unit (RTU, binary) and ASCII. Only the RTU version issupported by the 369. Monitoring, programming and control functions are possible using read and write register com-mands.
See Section 10.3: MODBUS RTU PROTOCOL on page 10–8 for complete details.
The 369 Motor Management Relay supports mandatory parametrization. The relay keeps its user parameter data / set-points in a non-volatile memory and does not need device related parametrization during startup of the DP master. The369PC software is the best tool for user parametrization of the 369 device.
10.2.2 369MMR-DP CONFIGURATION
The Profibus-DP basic configuration has one DP master and one DP slave. In a typical bus segment up to 32 stations canbe connected (a repeater has to be used if more then 32 stations operate on a bus). The end nodes on a Profibus-DP net-work must be terminated to avoid reflections on the bus line. If the 369 Motor Management Relay is used as the first or lastmodule in a network the on-board termination switch has be in the ON position (default is OFF), or an external terminationconnector has to be used.
The bus address for the relay as Profibus-DP node can be set using the S1: 369 COMMUNICATIONS \ PROFIBUS ADDRESSsetpoint or via the 369PC software, which extends address range from 1 to 126. Address 126 is used only for commission-ing purposes and should not be used to exchange user data.
The media for the fieldbus is a twisted pair copper cable along with 9-pin SUB-D connector, which connects the bus to the369 socket on the back of the relay. The 369 Motor Management Relay has autobaud support. The baud rates and otherslave specific information needed for configuration are contained in 369_xxxx.gs* which is used by a network configura-tion program.
The 369 Motor Management Relay as a DP slave transfers fast process data to the DP master according to master-slaveprinciple.
The 369 Motor Management Relay is a modular device, supporting up to 8 input modules.
During the configuration session, all modules have to be selected in order to get the entire area of 110 words of input data.There are no output data for processing. The following diagram shows the possible DP Master Class2 configuration menu:
GE Power Management 369 Motor Management Relay 10-5
10 COMMUNICATIONS 10.2 PROFIBUS PROTOCOL
10
10.2.3 369MMR-DP DIAGNOSTICS
The 369 Motor Management Relay supports both slave mandatory (6 bytes system-wide standardized) and slave specificdiagnostic data. If the diagnostics are considered hi-priority, the PLC/host program will be informed of the fault (alarm ortrip) and can call a special error routine. When the 369 is in Simulation mode, the DP master will get a static diagnosticmessage, which means the 369MMR-DP produced non-process (simulated values), and the DP master should stop dataexchange with the 369MMR-DP. The extended diagnosis for the relay is composed of 26 bytes (bytes 7 to 32) and containsdiagnostic information according to the following table.
10-8 369 Motor Management Relay GE Power Management
10.3 MODBUS RTU PROTOCOL 10 COMMUNICATIONS
10
10.3 MODBUS RTU PROTOCOL 10.3.1 DATA FRAME FORMAT AND DATA RATE
One data frame of an asynchronous transmission to or from an 369 is default to 1 start bit, 8 data bits, and 1 stop bit. Thisproduces a 10 bit data frame. This is important for transmission through modems at high bit rates (11 bit data frames arenot supported by Hayes modems at bit rates of greater than 300 bps). The parity bit is optional as odd or even. If it is pro-grammed as odd or even, the data frame consists of 1 start bit, 8 data bits, 1 parity bit, and 1 stop bit.
Modbus protocol can be implemented at any standard communication speed. The 369 RS485, fiber optic and RS232 portssupport operation at 1200, 2400, 4800, 9600, and 19200 baud.
10.3.2 DATA PACKET FORMAT
A complete request/response sequence consists of the following bytes (transmitted as separate data frames):
Master Request Transmission:
SLAVE ADDRESS - 1 byteFUNCTION CODE - 1 byteDATA - variable number of bytes depending on FUNCTION CODECRC - 2 bytes
Slave Response Transmission:
SLAVE ADDRESS - 1 byteFUNCTION CODE - 1 byteDATA - variable number of bytes depending on FUNCTION CODECRC - 2 bytes
SLAVE ADDRESS: This is the first byte of every transmission. It represents the user-assigned address of the slave devicethat is to receive the message sent by the master. Each slave device must be assigned a unique address and only theaddressed slave will respond to a transmission that starts with its address. In a master request transmission the SLAVEADDRESS represents the address of the slave to which the request is being sent. In a slave response transmission theSLAVE ADDRESS represents the address of the slave that is sending the response. Note: A master transmission with aSLAVE ADDRESS of 0 indicates a broadcast command. Broadcast commands can be used for specific functions.
FUNCTION CODE: This is the second byte of every transmission. The modbus protocol defines function codes of 1 to 127.The 369 implements some of these functions. In a master request transmission the FUNCTION CODE tells the slave whataction to perform. In a slave response transmission if the FUNCTION CODE sent from the slave is the same as the FUNC-TION CODE sent from the master indicating the slave performed the function as requested. If the high order bit of theFUNCTION CODE sent from the slave is a 1 (i.e. if the FUNCTION CODE is > 127) then the slave did not perform the func-tion as requested and is sending an error or exception response.
DATA: This will be a variable number of bytes depending on the FUNCTION CODE. This may be actual values, setpoints,or addresses sent by the master to the slave or by the slave to the master. Data is sent MSByte first followed by theLSByte.
CRC: This is a two byte error checking code. CRC is sent LSByte first followed by the MSByte.
10.3.3 ERROR CHECKING
The RTU version of Modbus includes a two byte CRC-16 (16 bit cyclic redundancy check) with every transmission. TheCRC-16 algorithm essentially treats the entire data stream (data bits only; start, stop and parity ignored) as one continuousbinary number. This number is first shifted left 16 bits and then divided by a characteristic polynomial(11000000000000101B). The 16 bit remainder of the division is appended to the end of the transmission, LSByte first. Theresulting message including CRC, when divided by the same polynomial at the receiver will give a zero remainder if notransmission errors have occurred.
If an 369 Modbus slave device receives a transmission in which an error is indicated by the CRC-16 calculation, the slavedevice will not respond to the transmission. A CRC-16 error indicates than one or more bytes of the transmission werereceived incorrectly and thus the entire transmission should be ignored in order to avoid the 369 performing any incorrectoperation.
The CRC-16 calculation is an industry standard method used for error detection. An algorithm is included here to assistprogrammers in situations where no standard CRC-16 calculation routines are available.
GE Power Management 369 Motor Management Relay 10-9
10 COMMUNICATIONS 10.3 MODBUS RTU PROTOCOL
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10.3.4 CRC-16 ALGORITHM
Once the following algorithm is complete, the working register "A" will contain the CRC value to be transmitted. Note thatthis algorithm requires the characteristic polynomial to be reverse bit ordered. The MSbit of the characteristic polynomial isdropped since it does not affect the value of the remainder. The following symbols are used in the algorithm:
--> data transferA 16 bit working registerAL low order byte of AAH high order byte of ACRC 16 bit CRC-16 valuei, j loop counters(+) logical exclusive or operatorDi i-th data byte (i = 0 to N-1)G 16 bit characteristic polynomial = 1010000000000001 with MSbit dropped and bit order
reversedshr(x) shift right (the LSbit of the low order byte of x shifts into a carry flag, a '0' is shifted into the
MSbit of the high order byte of x, all other bits shift right one location
The algorithm is as follows:
1. FFFF hex --> A
2. 0 --> i
3. 0 --> j
4. Di (+) AL --> AL
5. j+1 --> j
6. shr(A)
7. is there a carry? No: go to 8.Yes: G (+) A --> A
8. is j = 8? No: go to 5.Yes: go to 9.
9. i+1 --> i
10. is i = N? No: go to 3.Yes: go to 11.
11. A --> CRC
10.3.5 TIMING
Data packet synchronization is maintained by timing constraints. The receiving device must measure the time between thereception of characters. If three and one half character times elapse without a new character or completion of the packet,then the communication link must be reset (i.e. all slaves start listening for a new transmission from the master). Thus at9600 baud a delay of greater than 3.5 × 1 / 9600 × 10 = 3.65 ms will cause the communication link to be reset.
10.3.6 SUPPORTED MODBUS FUNCTIONS
The following Modbus functions are supported by the 369:
• 03 - Read Setpoints and Actual Values• 04 - Read Setpoints and Actual Values• 05 - Execute Operation• 06 - Store Single Setpoint• 07 - Read Device Status• 08 - Loopback Test• 16 - Store Multiple Setpoints
For detailed Modbus function code descriptions, refer to the Modicon Modbus Protocol Reference guide.
10-10 369 Motor Management Relay GE Power Management
10.3 MODBUS RTU PROTOCOL 10 COMMUNICATIONS
10
10.3.7 ERROR RESPONSES
When an 369 detects an error other than a CRC error, a response will be sent to the master. The MSbit of the FUNCTIONCODE 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 masterplus 128). The following byte will be an exception code indicating the type of error that occurred.
Transmissions received from the master with CRC errors will be ignored by the 369.
The slave response to an error (other than CRC error) will be:
GE Power Management 369 Motor Management Relay 10-11
10 COMMUNICATIONS 10.4 MEMORY MAP
10
10.4 MEMORY MAP 10.4.1 MEMORY MAP INFORMATION
The data stored in the 369 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 registeraddress is the address of a two-byte value. Addresses are listed in hexadecimal. Data values (setpoint ranges, increments,factory values) are in decimal.
Many Modbus communications drivers add 40001d to the actual address of the register addresses. Forexample: if address 0h was to be read, 40001d would be the address required by the Modbus communi-cations driver; if address 320h (800d) was to be read, 40801d would be the address required by the Mod-bus communications driver.
10.4.2 USER DEFINABLE MEMORY MAP AREA
The 369 has a powerful feature, called the User Definable Memory Map, which allows a computer to read up to 124 non-consecutive data registers (setpoints or actual values) by using one Modbus packet. It is often necessary for a master com-puter to continuously poll various values in each of the connected slave relays. If these values are scattered throughout thememory map, reading them would require numerous transmissions and would burden the communication link. The UserDefinable Memory Map can be programmed to join any memory map address to one in the block of consecutive User Maplocations, so that they can be accessed by reading these consecutive locations.
The User Definable area has two sections:
1. A Register Index area (memory map addresses 0180h-01FCh) that contains 125 Actual Values or Setpoints registeraddresses.
2. A Register area (memory map addresses 0100h-017Ch) that contains the data at the addresses in the Register Index.
Register data that is separated in the rest of the memory map may be remapped to adjacent register addresses in the UserDefinable Registers area. This is accomplished by writing to register addresses in the User Definable Register Index area.This allows for improved through-put of data and can eliminate the need for multiple read command sequences.
For example, if the values of Average Phase Current (register address 0306h) and Hottest Stator RTD Temperature (regis-ter address 0320h) are required to be read from an 369, their addresses may be remapped as follows:
1. Write 0306h to address 0180h (User Definable Register Index 0000) using function code 06 or 16.
2. Write 0320h to address 0181h (User Definable Register Index 0001) using function code 06 or 16.
A read (function code 03 or 04) of registers 0100h (User Definable Register 0000) will return the Phase A Current and reg-ister 0101h (User Definable Register 0001) will return Hottest Stator RTD Temperature.
10.4.3 EVENT RECORDER
The 369 event recorder data starts at address 3000h. Address 3003h is a pointer to the event of interest (1 representing theoldest event and 40 representing the latest event. To retrieve event 1, write ‘1’ to the Event Record Selector (3003h) andread the data from 3004h to 3022h. To retrieve event 2, write ‘2’ to the Event Record Selector (3003h) and read the datafrom 3004h to 3022h. All 40 events may be retrieved in this manner. The time and date stamp of each event may be usedto ensure that all events have been retrieved in order without new events corrupting the sequence of events (event 1should be more recent than event 2, event 2 should be more recent than event 3, etc.).
10.4.4 WAVEFORM CAPTURE
The 369 stores 16 cycles of A/D samples each time a trip occurs in a trace buffer. The Trace Memory Trigger is set up in S1Preferences and determines how many pre-trip and post-trip cycles are stored. The trace buffer is time and date stampedand may be correlated to a trip in the event record. 7 waveforms are captured this way when a trip occurs. These are the 3phase currents, ground current and 3 voltage waveforms. The last three captured records are retained by the 369. Thisinformation is stored in volatile memory and will be lost if power is cycled to the relay.
To access the captured waveforms, select the captured record by writing to the Trace Memory Buffer Selector (address30F5h), then select waveform of interest by writing its trace memory channel (see following table) to the Trace MemoryChannel Selector (address 30F6h). Then read the trace memory data from address 3100h to 31FFh. The values read arein actual amperes or volts.
F4 16 bits 2’s COMPLEMENT SIGNED VALUEExample: -1234 stored as -1234 (i.e. 64302)
F5 16 bits 2’s COMPLEMENT SIGNED VALUE, 1 DECIMAL PLACESExample: -123.4 stored as -1234 (i.e. 64302)
F6 16 bits 2’s COMPLEMENT SIGNED VALUE, 2 DECIMAL PLACESExample: -12.34 stored as -1234 (i.e. 64302)
F7 16 bits 2’s COMPLEMENT SIGNED VALUE, 3 DECIMAL PLACESExample: -1.234 stored as -1234 (i.e. 64302)
F8 16 bits 2’s COMPLEMENT SIGNED VALUE, 4 DECIMAL PLACESExample: -0.1234 stored as -1234 (i.e. 64302)
F15 16 bits HARDWARE REVISION
0000 0000 0000 0001 1 = A
0000 0000 0000 0010 2 = B
↓ ↓
0000 0000 0001 1010 26 = Z
F16 16 bits SOFTWARE REVISION
1111 1111 xxxx xxxx Major Revision Number, 0 to 9 in steps of 1
xxxx xxxx 1111 1111 Minor Revision Number (two BCD digits), 00 to 99 in steps of 1Example: Revision 2.30 stored as 0230 hex
F18 32 bits DATE (MM/DD/YYYY)Example: Feb. 20, 1995 stored as 34867142 (i.e. 1st word: 0214, 2nd word 07C6)
1st byte Month (1 to 12)
2nd byte Day (1 to 31)
3rd and 4th byte Year (1998 to 2094)
F19 32 bits TIME (HH:MM:SS:hh)Example: 2:05pm stored as 235208704 (i.e. 1st word: 0E05, 2nd word 0000)
1st byte Hours (0 to 23)
2nd byte Minutes (0 to 59)
3rd byte Seconds (0 to 59)
4th byte Hundreds of seconds (0 to 99) - Not used by 369
F20 16 bits 2’s COMPLEMENT SIGNED LONG VALUEExample: 1234 stored as 1234. Note: -1 means “Never”
F21 16 bits 2’s COMPLEMENT SIGNED VALUE, 2 DECIMAL PLACES (Power Factor)Example: Power Factor of 0.87 lag is used as 87 (i.e. 0057)
< 0 Leading Power Factor - Negative
> 0 Lagging Power Factor - Positive
F22 16 bits TWO 8-BIT CHARACTERS PACKED INTO 16-BIT UNSIGNEDExample: String "AB" stored as 4142 hex.
MSB First Character
LSB Second Character
F23 16 Bits UNSIGNED VALUE (For 1A/5 A CT, 1Decimal Place) (For 50: 0.025 A CT, 2 Decimal Places)Example: For 1A/5A CT, G/F current = 1000.0 AExample: For 50: 0.025 A CT, G/F current = 25.00
A-2 369 Motor Management Relay GE Power Management
A.1 CHANGE NOTES APPENDIX A
AA.1.5 MAJOR UPDATES FOR 369-B9
A.1.6 MAJOR UPDATES FOR 369-B8
Firmware version 53CMB145.000 contains only minor software changes that do not affect the functional-ity of the 369 or the 1601-0777-B8 manual contents.
A.1.7 MAJOR UPDATES FOR 369-B7
CHANGES
Updated Figure 3-4: TYPICAL WIRING
Updated Figure 3-15: REMOTE RTD MODULE
Added menu item PROFIBUS ADDRESS to the 369 Setup Communications menu
Added menu item CLEAR ENERGY DATA to the 369 Setup Clear/Preset Data menu
Added Section 10.2: PROFIBUS PROTOCOL to Communications chapter
CHANGES
Revision change to match firmware and PC program
Added/changed setpoints of Backspin start inhibit
Updated memory map for the changes listed above
Changed FC to F for each of the format codes
Updated Phase 2 feature release document
Removed 32 bit format codes from the memory map
Added 369PC instruction section describing the converting of 269 setpoint files to 369
Added note in uploading setpoint section that versions 1.10 and 1.12 are not compatible with newer versions
Added a separate section for Backspin Metering
Made corrections to the application notes section
Added refresh RRTD setpoints to the PC program
Added some self-testing algorithms and programmable self-test relay assignment
GE Power Management 369 Motor Management Relay A-3
APPENDIX A A.2 WARRANTY
AA.2 WARRANTY A.2.1 WARRANTY INFORMATION
GE POWER MANAGEMENT RELAY WARRANTY
General Electric Power Management (GE Power Management) warrantseach relay it manufactures to be free from defects in material and work-manship under normal use and service for a period of 24 months fromdate of shipment from factory.
In the event of a failure covered by warranty, GE Power Management willundertake to repair or replace the relay providing the warrantor deter-mined that it is defective and it is returned with all transportation chargesprepaid to an authorized service centre or the factory. Repairs or replace-ment under warranty will be made without charge.
Warranty shall not apply to any relay which has been subject to misuse,negligence, accident, incorrect installation or use not in accordance withinstructions nor any unit that has been altered outside a GE Power Man-agement authorized factory outlet.
GE Power Management is not liable for special, indirect or consequentialdamages or for loss of profit or for expenses sustained as a result of arelay malfunction, incorrect application or adjustment.
For complete text of Warranty (including limitations and disclaimers), referto GE Power Management Standard Conditions of Sale.
AA1 STATUS .................................................................. 6-3A2 METERING DATA ..................................................... 6-7A3 LEARNED DATA..................................................... 6-13A4 STATISTICAL DATA ............................................... 6-16A5 EVENT RECORD .................................................... 6-18A6 RELAY INFORMATION ............................................ 6-19ACCELERATION TRIP ......................................... 5-38, 7-12ACCESS SECURITY ...................................................... 5-4ACCESSORIES ............................................................. 1-2ACTUAL VALUES .......................................................... 6-1
main menu ................................................................. 6-1overview .................................................................... 6-1page 1 menu .............................................................. 6-3page 2 menu .............................................................. 6-7page 3 menu ............................................................ 6-13page 4 menu ............................................................ 6-16page 5 menu ............................................................ 6-18page 6 menu ............................................................ 6-19
ADDITIONAL FEATURES ............................................... 2-3ADDITIONAL FUNCTIONAL TING ................................... 8-7ALARM RELAY
setpoints .................................................................. 5-16ALARM STATUS ........................................................... 6-4AMBIENT TEMPERATURE ............................................. 2-8ANALOG
inputs and outputs ....................................................... 8-5outputs ................................................... 3-10, 3-11, 5-59outputs (Option M) ...................................................... 2-5
CURRENT DEMAND ............................................ 5-13, 5-15CURRENT TRANSFORMER
see CTCUSTOM OVERLOAD CURVE .......................................5-27
DDATA
frame format and data rate ..........................................10-8packet format ............................................................10-8
DATE ........................................................................... 5-8DEFAULT MESSAGES
cycle time .................................................................. 5-5setpoints ...................................................................5-10timeout ...................................................................... 5-5
interface .................................................................... 4-1FACTORY DATA ..........................................................5-10FAQ ............................................................................ 7-2FAST TRANSIENTS ...................................................... 2-8FAULT SETUP .............................................................5-63FIBER OPTIC PORT (OPTION F) .................................... 2-5FIRMWARE
history ....................................................................... 1-2version .....................................................................6-19
information .............................................................. 10-11MESSAGE SCRATCHPAD ..............................................5-9METERED QUANTITIES .................................................2-1METERING ...................................................................2-5MODBUS
serial communications control ......................................5-17setpoints ..............................................................5-6, 5-7
MODBUS COMMUNICATIONS .......................................10-1MODBUS/TCP COMMUNICATIONS..................................5-6MODEL INFORMATION ................................................6-19MONITORING SETUP ..................................................5-12MOTOR
CT and VT.................................................................. 7-5POSITIVE REACTIVE POWER ...................................... 5-52POWER
measurement test ....................................................... 8-7metering .................................................................... 6-8metering (option m) ..................................................... 2-5
SS10 ANALOG OUTPUTS ...............................................5-59S11 369 TESTING ........................................................5-61S2 SYSTEM SETUP .....................................................5-11S3 OVERLOAD PROTECTION .......................................5-21S4 CURRENT ELEMENTS .............................................5-32S5 MOTOR START / INHIBITS .......................................5-38S6 RTD TEMPERATURE ...............................................5-41S7 VOLTAGE ELEMENTS .............................................5-46S8 POWER ELEMENTS ................................................5-50S9 DIGITAL INPUTS .....................................................5-55SECONDARY INJECTION TEST SETUP .......................... 8-1SECURITY ................................................................... 5-4SELF-TEST MODE .......................................................5-15SELF-TEST RELAY ......................................................5-15SERIAL COMMUNICATION CONTROL ...........................5-17SETPOINTS ................................................................. 5-1
access ....................................................................... 5-4entry ......................................................................... 4-2main menu ................................................................. 5-1page 1 menu .............................................................. 5-4page 10 menu............................................................5-59
page 11 menu ...........................................................5-61page 2 menu .............................................................5-11page 3 menu .............................................................5-21page 4 menu .............................................................5-32page 5 menu .............................................................5-38page 6 menu .............................................................5-41page 7 menu .............................................................5-46page 8 menu .............................................................5-50page 9 menu .............................................................5-55
SHORT CIRCUIT..........................................................5-32test ........................................................................... 8-8trip ...........................................................................7-11
TIME ............................................................................5-8TIME BETWEEN STARTS .............................................7-12TIMING .......................................................................10-9TRENDING ....................................................................4-9TRIP COUNTER.................................5-12, 5-13, 5-15, 6-16TRIP RELAY................................................................3-12
setpoints ...................................................................5-16TROUBLESHOOTING ...................................................4-12TWO PHASE WIRING ...................................................7-20TWO WIRE RTD LEAD COMPENSATION ........................7-24TYPE TEST STANDARDS ...............................................2-8
UUNBALANCE
alarm and trip ............................................................7-12bias ..........................................................................5-28bias k factor ..............................................................7-10bias of thermal capacity ..............................................7-10setpoints ...................................................................5-22test ............................................................................8-8
relay firmware .............................................................4-4setpoint file to new revision ...........................................4-7
USER DEFINABLE MEMORY MAP AREA...................... 10-11
input accuracy test .......................................................8-2metering .....................................................................6-8phase reversal test .......................................................8-8
VOLTAGE TRANSFORMERsee VT
VTconnection type .........................................................5-12ratio .........................................................................5-12
VT RATIO .......................................................... 5-11, 5-12VT SETTINGS .............................................................7-10