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GE 845, Instruction Manual

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CHAPTER 4: SETPOINTS

FLEXLOGIC

845 TRANSFORMER PROTECTION SYSTEM – INSTRUCTION MANUAL

4–335

Table 4-37: 845 FlexLogic Operands

ELEMENT

OPERANDS

EVENT DESCRIPTION

Aging Factor

Aging Factor PKP 

 

Aging Factor OP 

The Aging factor element has picked up 

 

The Aging factor element has operated 

Analog Input

Anlg lp Trip PKP 

 

Anlg lp Trip OP 

 

Anlg lp Alarm PKP 

 

Anlg lp Alarm OP 

 

Anlg lp 2 to 4 

Analog Input 1 trip has picked up 

 

Analog Input 1 trip has operated 

 

Analog Input 1 alarm has picked up 

 

Analog Input 1 alarm has operated 

 

Similar to Analog Input 1 operands above 

Arc Flash 1

AF 1 Light 1 PKP 

 

AF 1 Light 2 PKP 

 

AF 1 Light 3 PKP 

 

AF 1 Light 4 PKP 

 

AF 1 HS Ph IOC PKP A 

 

AF 1 HS Ph IOC PKP B 

 

AF 1 HS Ph IOC PKP C 

 

AF 1 HS GND IOC PKP 

 

Arc Flash 1 S1 OP 

 

 

Arc Flash 1 S2 OP 

 

 

Arc Flash 1 S3 OP 

 

 

Arc Flash 1 S4 OP 

 

 

Arc Flash 1 OP 

 

 

Light Sensor 1 Trouble 

 

Light Sensor 2 Trouble 

 

Light Sensor 3 Trouble 

 

Light Sensor 4 Trouble 

 

Light Sensor Trouble 

Light sensor 1 has detected light above threshold 

 

Light sensor 2 has detected light above threshold 

 

Light sensor 3 has detected light above threshold 

 

Light sensor 4 has detected light above threshold 

 

High speed IOC of phase A has picked up 

 

High speed IOC of phase B has picked up 

 

High speed IOC of phase C has picked up 

 

High speed IOC of Ground has picked up 

 

Arc Flash event is detected due to detection of light in sensor 1 above 

threshold AND HS Phs/Gnd IOC element picked up 

 

Arc Flash event is detected due to detection of light in sensor 2 above 

threshold AND HS Phs/Gnd IOC element picked up 

 

Arc Flash event is detected due to detection of light in sensor 3 above 

threshold AND HS Phs/Gnd IOC element picked up 

 

Arc Flash event is detected due to detection of light in sensor 4 above 

threshold AND HS Phs/Gnd IOC element picked up 

 

Arc Flash event is detected by at least one of the sensor elements AND HS 

Phs/Gnd IOC elements 

 

Detection of any trouble in light sensor 1 or corresponding fiber 

 

Detection of any trouble in light sensor 2 or corresponding fiber 

 

Detection of any trouble in light sensor 3 or corresponding fiber 

 

Detection of any trouble in light sensor 4 or corresponding fiber 

 

Detection of any trouble in any of the 4 light sensors or corresponding 

fibers 

Auxiliary OV

Aux OV PKP 

 

Aux OV OP 

Auxiliary overvoltage element has picked up 

 

Auxiliary overvoltage element has operated 

Auxiliary UV

Aux UV 1 PKP 

 

Aux UV 1 OP 

 

Aux UV 2 

Auxiliary undervoltage element 1 has picked up 

 

Auxiliary undervoltage element 1 has operated 

 

The same set of operands as per Aux UV 1 

Breaker

BKR[X] Opened 

 

BKR[X] Closed 

 

BKR[X] Unkwn State 

 

BKR[X] Connected 

 

BKR[X] Disconnected 

 

BKR[X] Configured 

Breaker state is detected opened 

 

Breaker state is detected closed 

 

Close or Open breaker state cannot be detected 

 

Breaker has been connected to the power system 

 

Breaker has been detached from the power system 

 

Breaker status contact is configured 

 

[X] - the element number. 

Breaker Arcing

BKR1 Arc OP 

 

BKR 2, BKR 3 

Breaking arcing 1 element operated 

 

Same set of operands as for BKR 1 

Breaker Control

BKR[X] Remote Open 

 

BKR[X] Remote Close 

 

BKR[X] Rem Blk Open 

 

BKR[X] Rem Blk Close 

 

BKR[X] Remote Blk Opn By 

 

BKR[X] Remote Blk Cls By 

Breaker Open command is initiated to Breaker 1 

 

Breaker Close command is initiated to Breaker 1 

 

The Open command to Breaker 1 is blocked 

 

The Close command to Breaker 1 is blocked 

 

The block open signal to Breaker 1 is bypassed 

 

The block close signal to Breaker 1 is bypassed 

 

[X] - the element number.

Breaker Failure

BF1 Retrip 

 

BF1 Highset OP 

 

 

BF1 Lowset OP 

 

 

BF1 52b Superv OP 

 

BF1 OP 

 

BF 2, BF 3 

Breaker failure 1 re-trip operated 

 

Breaker failure 1 operated with high level current supervision (includes 

breaker status supervision if set) 

 

Breaker failure 1 operated with low level current supervision (includes 

breaker status supervision if set) 

 

Breaker failure 1 operated with breaker status only 

 

Breaker failure 1 operated 

 

Same set of operands as for BF 1 

Summary of Contents for 845

Page 1: ...Instruction manual Product version GEK GE publication code 1601 0651 A5 GEK 119651D 1601 0450 A5 845 Transformer Protection System Transformer Protection Control and Management GE Grid Soutions ...

Page 2: ...istered trademarks of GE Multilin Inc The contents of this manual are the property of GE Multilin Inc This documentation is furnished on license and may not be reproduced in whole or in part without the permission of GE Multilin The content of this manual is for informational use only and is subject to change without notice Part number 1601 0651 A5 July 2017 Note May contain components with FCC ID...

Page 3: ... Warnings 1 30 Must read Information 1 33 Storage 1 34 For Further Assistance 1 34 Repairs 1 34 2 INSTALLATION Mechanical Installation 2 1 Product Identification 2 1 Dimensions 2 2 Mounting 2 3 Standard Panel Mount 2 4 Depth Reducing Collar 2 5 Draw out Unit Withdrawal and Insertion 2 7 Removable Power Supply 2 8 Removable Magnetic Module 2 9 Arc Flash Sensor 2 10 Sensor Fiber Handling Storage 2 1...

Page 4: ... with Setpoints Setpoints Files 3 24 Engaging a Device 3 25 Entering Setpoints 3 25 File Support 3 26 Using Setpoints Files 3 26 Downloading Saving Setpoints Files 3 27 Adding Setpoints Files to the Environment 3 27 Creating a New Setpoints File 3 28 Upgrading Setpoints Files to a New Revision 3 29 Printing Setpoints 3 30 Printing Values from a Connected Device 3 31 Loading Setpoints from a File 3...

Page 5: ...corder 4 48 Data Logger 4 50 Fault Reports 4 53 Event Data 4 54 Flex States 4 54 Front Panel 4 54 Programmable LEDs 4 55 Programmable Pushbuttons 4 56 Tab Pushbuttons 4 60 Annunciator 4 63 Display Properties 4 65 Default Screens 4 66 Home Screens 4 67 Resetting 4 68 Installation 4 68 System 4 70 Current Sensing 4 71 Voltage Sensing 4 71 Traditional VT 4 71 Power Sensing 4 73 Power System 4 73 Tran...

Page 6: ...rcurrent Protection 67G 4 184 Restricted Ground Earth Fault 87G 4 188 Negative Sequence Time Overcurrent Protection 51_2 4 193 Negative Sequence Instantaneous Overcurrent Protection 50_2 4 195 Voltage Elements 4 198 Undervoltage Curves 4 199 Phase Undervoltage Protection 27P 4 200 Auxiliary Undervoltage 27X 4 203 Phase Overvoltage Protection 59P 4 206 Auxiliary Overvoltage Protection 59X 4 209 Neu...

Page 7: ... 4 345 Viewing FlexLogic Graphics 4 347 FlexElements 4 348 Testing 4 354 Simulation 4 355 Setup 4 355 Pre Fault 4 356 Fault 4 357 Post Fault 4 357 Test LEDs 4 358 Contact Inputs 4 358 Output Relays 4 358 Ethernet Loopback Test 4 359 5 STATUS Summary 5 2 Configurable SLD 5 2 Annunciator 5 3 Tab Pushbuttons 5 3 Breakers 5 4 Switches 5 5 Last Trip Data 5 5 Arc Flash 5 5 Contact Inputs 5 6 Output Rela...

Page 8: ... 18 Current Demand K2 6 18 Directional Power 6 19 Arc Flash 6 19 RTDs 6 20 RTD Maximums 6 20 Analog Inputs 6 20 FlexElements 6 21 7 RECORDS Events 7 1 Transient Records 7 1 Fault Reports 7 2 Data Logger 7 2 Breakers 7 3 Breaker Arcing Current 7 3 Breaker Health 7 3 Digital Counters 7 3 Remote Modbus Device 7 4 Clear Records 7 6 8 TRANSFORMER M D DGA Monitoring 8 2 Device Data 8 3 Dissolved Gas Ana...

Page 9: ...NUAL VII 9 MAINTENANCE Environmental Health Report 9 1 General Maintenance 9 3 In service Maintenance 9 3 Out of service Maintenance 9 3 Unscheduled Maintenance System Interruption 9 3 A APPENDIX A Warranty A 1 Revision history A 1 Major Updates A 2 ...

Page 10: ...VIII 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL ...

Page 11: ...xibility will naturally make a piece of equipment difficult to learn To aid new users in getting basic protection operating quickly setpoints are set to typical default values and advanced features are disabled These settings can be reprogrammed at any time Programming can be accomplished with the front panel keys and display Due to the numerous settings this manual method can be somewhat laboriou...

Page 12: ...o the alternative reference source i e three phase currents signal or line voltage for the configuration of tie breaker if the frequency detected from the three phase voltage inputs is declared invalid The switching will not be performed if the frequency from the alternative reference signal is detected invalid Upon detecting valid frequency on the main source the tracking will be switched back to...

Page 13: ...nt Recorder Fault Report Data Logger Calculate 2nd and 5th Harmonics Harmonic Restraint 59N 24 Winding 1 Harmonics Amps Amps 51N 1 50N 1 51N 2 50N 2 Calculate 3I_0 Calculate 3I_0 Amps 50P 2 51P 2 50P 1 55 51P 1 50BF 1 50G 1 51G 1 87G 1 50G 2 51G 2 87G 2 81R 81U 81O RTD input 67P 67N 3V_0 Amps Harmonics 50BF 2 AFP 59P 27P 27X 845 Тransformer Protection System 67G 1 67G 2 59X Winding 2 3 3 3 T C Tap...

Page 14: ...ous Overcurrent 50_2 Negative Sequence Instantaneous Overcurrent 51G Ground Time Overcurrent 51N Neutral Time Overcurrent 51P Phase Time Overcurrent 51_2 Negative Sequence Time Overcurrent 55 Power Factor 59N Neutral Overvoltage 59P Phase Overvoltage 59X Auxiliary Overvoltage 59_2 Negative Sequence Overvoltage 67G Ground Directional Element 67N Neutral Directional Element 67P Phase Directional Ele...

Page 15: ... frequency harmonics THD Modbus User Map Non volatile Latches OPC UA Communications Output Relays Setpoint Groups 6 Transformer Dissolved Gas Analysis Transformer Energization Reports Transformer Integrated Fault Report Transformer Overload Transformer Loss of Life Trip Bus 6 Transient Recorder Oscillography Trip and Close Coil Monitoring User programmable LEDs User programmable Pushbuttons Virtua...

Page 16: ...rrents Voltages Frequency Harmonics Power Energy Current Demand Records Events Fault Reports Breakers Remote Modbus Device Targets Directional Power Data Logger Volts per Hertz Digital Counters RTDs RTD Maximums FlexElements Arc Flash Syncrocheck Testing Output Relays Virtual Inputs Information Device Status Clock Arc Flash Virtual Outputs Communications PTP Status Flex States Last Trip Data Break...

Page 17: ...ions based on specific roles and individual user accounts configured on the AAA server At present the defined roles are Administrator Operator and Observer Strong encryption of all access and configuration network messages between the EnerVista software and 845 devices using the Secure Shell SSH protocol the Advanced Encryption Standard AES and 128 bit keys in Galois Counter Mode GCM as specified ...

Page 18: ...ole has read only access to all 845 settings This role allows concurrent access The Observer is the default role if no authentication has been done to the device This role can download settings files and records from the device Factory This is an internal non user accessible role used for manufacturing diagnostics The ability to enable or disable this role is a security setting that the Administra...

Page 19: ... Form C 7 Digital Inputs Low High Voltage Int Ext Supply L 7 DcmA O P 4 DcmA I P 1 RTD Slot H HV I O N None High Voltage I O F 10 Digital Inputs 4 Arc Flash Inputs A 2 Form A Vmon 3 Form C 7 Digital Inputs Low High voltage Int Ext supply Faceplate M Basic Membrane Keypad G Standard Rugged Keypad Current Protection S Basic 87T 50 87 50P 50N 50G 51P 51N 51G Transformer Overload M Standard Basic 50_2...

Page 20: ...f 2x2 or 3x3 Data Storage Non volatile memory Mode Self reset latched acknowledgeable Display Text 3 lines of 15 characters maximum Visual Indication Flashing 2Hz 50 duty cycle CUSTOM CONFIGURATIONS Config Mode Simplified Regular Protection ARC FLASH HS PHASE GROUND INSTANTANEOUS OVERCURRENT HS 50P 50G Current Phasor Magnitude special high speed algorithm Pickup Level 0 050 to 30 000 x CT in steps...

Page 21: ...ickup at 60 Hz 30 ms at 3 x Pickup at 50 Hz Timer Accuracy 3 of delay setting or cycle whichever is greater from pickup to operate INSTANTANEOUS PHASE DIFFERENTIAL FUNCTION Pickup level 3 00 to 30 00 per unit in steps 0 01 Dropout level 97 to 98 of Pickup Operate time 12 ms at 3 x Pickup 60Hz 15 ms at 3 x Pickup 50Hz PHASE NEUTRAL GROUND TIME OVERCURRENT 51P N G Current Phasor or RMS Pickup Level ...

Page 22: ...damental Phasor Magnitude Pickup Level 0 050 to 30 000 x CT in steps of 0 001 x CT Dropout Level 97 to 98 of Pickup Level Accuracy For 0 1 to 2 0 x CT 0 5 of reading or 0 4 of rated whichever is greater For 2 0 x CT 1 5 of reading Operate Time 12 ms typical at 3 Pickup at 60 Hz Phase Ground IOC 16 ms typical at 3 Pickup at 60 Hz Neutral IOC 15 ms typical at 3 Pickup at 50 Hz Phase Ground IOC 20 ms...

Page 23: ...te Time no direction transition 16 ms at 3 x Pickup at 60 Hz 20 ms at 3 x Pickup at 50 Hz GROUND DIRECTIONAL OVERCURRENT 67G Directionality Co existing forward and reverse Polarizing Voltage Polarizing Voltage V_0 or VX Polarizing Current Isg Operating Current Ig Level Sensing Ig Isg Characteristic Angle 90º to 90º in steps of 1 Limit Angle 40º to 90º in steps of 1 independent for forward and reve...

Page 24: ...x pickup at 50 Hz Curve Timing Accuracy at 0 90 x pickup 3 5 of curve delay or cycle whichever is greater from pickup to operate PHASE OVERVOLTAGE 59P Voltage Fundamental Phasor Magnitude Pickup Level 0 02 to 3 00 x VT in steps of 0 01 x VT Dropout Level 97 to 98 of Pickup Level Accuracy 0 5 of reading from 10 to 208 V Phases Required for Operation Any one Any two All three Pickup Time Delay 0 000...

Page 25: ...teps of 0 001 s Operate Time 25 ms at 1 1 x pickup at 60 Hz 30 ms at 1 1 x pickup at 50 Hz Timer Accuracy 3 of delay setting or cycle whichever is greater from pickup to operate VOLTS PER HERTZ 24 Voltages Phasor only Pickup Level 0 80 to 4 00 in steps of 0 01 pu Dropout Level 97 to 98 of pickup Level Accuracy 0 02 pu Timing Curves Definite Time IEC Inverse A B C FlexCurves A B C and D TD Multipli...

Page 26: ...ng Voltage 0 000 to 1 250 x VT in steps of 0 001 x VT Level Accuracy 0 001 Hz Timer Accuracy 3 of delay setting or cycle whichever is greater from pickup to operate Operate Time typically 7 5 cycles at 0 1 Hz s change typically 7 cycles at 0 3 Hz s change typically 6 5 cycles at 0 5 Hz s change FASTPATH Typical times are average Operate Times including variables such as frequency change instance t...

Page 27: ...tion Opens closes blocks bypasses blocks to the feeder breaker BREAKER FAILURE Mode 3 pole Current Supervision phase and neutral current fundamental phasor magnitude Current Supervision Pickup 0 050 to 30 000 x CT in steps of 0 001 x CT Current Supervision Dropout 97 to 98 of pickup Current Supervision Accuracy For 0 1 to 2 0 x CT 0 5 of reading or 0 4 of rated whichever is greater For 2 0 x CT 1 ...

Page 28: ...up to operate TRIP CIRCUIT MONITOR TCM Applicable Voltage 20 to 250 VDC Trickle Current 1 to 2 5 mA Timing Accuracy 3 or 4 ms whichever is greater CLOSE CIRCUIT MONITOR CCM Applicable Voltage 20 to 250 VDC Trickle Current 1 to 2 5 mA Timing Accuracy 3 or 4 ms whichever is greater BREAKER ARCING CURRENT Mode 3 pole Principle accumulates breaker duty I2 t during fault Initiation any operand Alarm Th...

Page 29: ... 1 hour TAP CHANGER FAILURE Operating Parameter Tap Changer Position Time Delay 0 00 to 600 00 s Timer Accuracy 3 of delay setting or 2 cycles whichever is greater from pickup to operate HARMONIC DETECTION Operating Parameter Current 2nd 3rd 4th 5th harmonic or THD per phase Timer Accuracy Harmonics 3 of delay setting or 1 4 cycle whichever is greater from pickup to operate THD 3 of delay setting ...

Page 30: ...p 64 Configurable FlexAnalog values Commands Clear Last Trip Data User Programmable Elements FLEXLOGIC Lines of code 1024 Supported operations NOT XOR OR 2 to 16 inputs AND 2 to 16 inputs NOR 2 to 16 inputs NAND 2 to 16 inputs latch reset dominant edge detectors timers Inputs any logical variable contact or virtual input Number of timers 32 Pickup delay 0 to 60000 ms sec min in steps of 1 Dropout ...

Page 31: ...rom pickup to operate USER PROGRAMMABLE LEDS Number 17 14 3 PB LEDS for Membrane and Rugged Front Panels Programmability any logic variable contact or virtual input Reset mode self reset or latched USER PROGRAMMABLE PUSHBUTTONS Number of pushbuttons 3 Membrane and Rugged Front Panels Mode Self reset latched Display message 2 lines of 13 characters on each line Dropout timer 0 000 to 60 000 s in st...

Page 32: ...arh to 2147483 647 Mvarh Parameters 3 phase only Update Rate 50 ms Accuracy 2 0 of reading PHASORS Current Parameters Phase A B C Neutral and Ground Magnitude Accuracy 0 5 of reading or 0 2 of rated whichever is greater from 0 1 to 2 0 x CT 1 0 of reading 2 0 x CT Angle Accuracy 2 3 for 25 Hz Voltages Parameters Wye VTs A n B n C n A B B C C A Average Phase Neutral and Residual Delta VTs A B B C C...

Page 33: ...ted secondary Short Term CT Withstand 1 second at 100 x rated current 2 seconds at 40 x rated current continuous at 3 x rated current AC VOLTAGE VT Range 10 to 260 V Nominal Frequency 20 to 65 Hz Burden 0 25 VA at 120 V Conversion Range 1 to 275 V Voltage Withstand continuous at 260 V to neutral 1 min hr at 420 V to neutral ANALOG INPUTS Current Input mA DC 0 to 1mA 0 to 5mA 0 to 10mA 0 to 20mA 4 ...

Page 34: ...en 2 mA CLOCK Setup Date and Time Daylight Saving Time UTC Coordinated Universal Time Backup Retention 1 hour IRIG B INPUT Auto detect DC and AM Amplitude Modulation 1 V to 10 V pk to pk DC Shift TTL Input Impedance 40 kΩ Isolation 2 kV RTD INPUTS Types 3 wire 100 Ω Platinum 120 Ω Nickel 100 Ω Nickel 10 Ω Copper Sensing current 5 mA Range 40 to 250 C 40 to 482 F Accuracy 2 C 4 F Isolation 36 V pk ...

Page 35: ...pu in steps of 0 001 TRIP CLOSE OUTPUT RELAYS Relays 1 and 2 from Slot F Relays 9 and 10 from Slot G Type FORM A Configuration 2 two electromechanical Contact material silver alloy Operate time 8 ms Continuous current 10 A Make and carry for 0 2s 30 A per ANSI C37 90 Break DC inductive L R 40 ms 24 V 1 A 48 V 0 5 A 125 V 0 3 A 250 V 0 2 A Break DC resistive 24 V 10 A 48 V 6 A 125 V 0 5 A 250 V 0 3...

Page 36: ...requirements 1 second ON 10 seconds OFF per output relay at maximum rating FASTPATH For 2 IO_A module configuration the following ratings are applied to meet UL508 requirements 1 second on 10 seconds off per output relay at max rating PULSED OUTPUTS Mode 3 phase positive and negative active energy measurement 3 phase positive and negative reactive energy measurements Principle Pulsed output is ene...

Page 37: ...70 5 104 IEC 61850 IEC 61850 GOOSE IEEE 1588 SNTP IEC 62439 3 clause 4 PRP Wavelength 1310nm Typical link distance 4 km USB Standard specification Compliant with USB 2 0 Protocols Modbus TCP TFTP SERIAL RS485 port Isolated Baud rates Supports 9600 19200 38400 57600 and 115200 kbps Response time 10 ms typical Parity None Odd Even Protocol Modbus RTU DNP 3 0 IEC 60870 5 103 Maximum distance 1200 m 4...

Page 38: ...B Surge Immunity EN61000 4 5 Level 3 Conducted RF Immunity EN61000 4 6 Level 3 Power Frequency Immunity IEC60255 26 Class A B Voltage variation interruption and Ripple DC IEC60255 26 PQT levels based on IEC61000 4 29 IEC61000 4 11 and IEC61000 4 17 Radiated Conducted Emissions CISPR11 CISPR22 Class A Sinusoidal Vibration IEC60255 21 1 Class 1 Shock Bump IEC60255 21 2 Class 1 Seismic IEC60255 21 3 ...

Page 39: ...roduct Safety IEC60255 27 As per Normative sections Rated Burden IEC60255 1 Sec 6 10 Contact Performance IEC60255 1 Sec 6 11 Ambient temperatures Storage Shipping 40 C to 85 C Operating 40 C to 60 C Humidity Operating up to 95 non condensing 55 C As per IEC60068 2 30 Variant 2 6 days Altitude 2000m standard base reference evaluated altitude 5000m maximum achievable altitude Pollution Degree II Ove...

Page 40: ...er not specified by the manufacturer or functions abnormally proceed with caution Otherwise the protection provided by the equipment may be impaired and can result in impaired operation and injury CAUTION Hazardous voltages can cause shock burns or death CAUTION Installation service personnel must be familiar with general device test practices electrical awareness and safety precautions must be fo...

Page 41: ...sh option is ordered Ensure that the control power applied to the device the AC current and voltage input match the ratings specified on the relay nameplate Do not apply current or voltage in excess of the specified limits Only qualified personnel are to operate the device Such personnel must be thoroughly familiar with all safety cautions and warnings in this manual and with applicable country re...

Page 42: ... devices are considered safe to the unaided eye Do not view directly with optical instruments FASTPATH To ensure the settings file inside the relay is updated wait 30 seconds after a setpoint change before cycling power FASTPATH This product is rated to Class A emissions levels and is to be used in Utility Substation Industrial environments Not to be used near electronic devices rated for Class B ...

Page 43: ...nged A coordination time of at least 10 ms must therefore be added to all the instantaneous protection elements under the supervision of the Phase Directional element If current reversal is a concern a longer delay in the order of 20 ms is needed The same curves used for the time overcurrent elements are used for Neutral Displacement When using the curve to determine the operating time of the Neut...

Page 44: ...tory For issues not solved by troubleshooting the process to return the device to the factory for repair is as follows Contact a GE Grid Solutions Technical Support Center Contact information is found in the first chapter Obtain a Return Materials Authorization RMA number from the Technical Support Center Verify that the RMA and Commercial Invoice received have the correct information Tightly pack...

Page 45: ... indicates the product model serial number and date of manufacture Figure 2 1 Product Label LISTED C US L U E57838 IND CONT EQ 2D58 R MADE IN CANADA 7UDQVIRUPer Protection System Model 8 5 EP5NNG5HNNANNGSSBSNNNB SerialNumber MJ AXXXXXXX POWERSUPPLYRATINGS Nominal 100to240V 125to250V Range 88to265V 50 60Hz 88to300V PowerConsumption 20WTyp 34W 70VAMax Input OutputRatings RefertoManual InstructionMan...

Page 46: ...ION MANUAL MECHANICAL INSTALLATION CHAPTER 2 INSTALLATION Dimensions The dimensions in inches millimeters of the 845 are shown below Additional dimensions for mounting and panel cutouts are shown in the following sections Figure 2 2 845 Dimensions ...

Page 47: ...e rear of the panel screw the case into the panel at the 8 screw positions see figures in Standard panel mount section Optional tab mounting The V tabs are located on the sides of the case and appear as shown in the following figure Use needle nose pliers to bend the retaining V tabs outward to about 90 Use caution and do not bend and distort the wall of the enclosure adjacent to the tabs The rela...

Page 48: ...ndard Panel Mount The standard panel mount and cutout dimensions are illustrated below CAUTION To avoid the potential for personal injury due to fire hazards ensure the unit is mounted in a safe location and or within an appropriate enclosure Figure 2 4 Standard panel mount Figure 2 5 Panel cutout dimensions ...

Page 49: ... The drill hole locations are different when a depth reducing collar is used See Figure 2 7 Depth reducing collar panel cutout 18J0 0030 8 Series Depth Reducing Collar 1 3 8 18J0 0029 8 Series Depth Reducing Collar 3 Figure 2 6 Depth reducing collar dimensions Figure 2 7 Depth reducing collar panel cutout 10 40 A 9 00 7 25 GE PN A DEPTH 1009 0310 1 3 8 1009 0311 3 Dimensions in inches 8 73 892703A...

Page 50: ...own on the panel cutout drawing Figure 2 7 Depth reducing collar panel cutout 2 Mount the required collar depth 1 375 or 3 on the captive unit using eight screws as shown 3 Mount the combined unit and collar on the panel using eight screws as shown DEPTH REDUCING COLLAR GE PART 1009 0311 3IN 76 2MM DEPTH GE PART 1009 0310 1 375IN 34 9MM DEPTH 8 SERIES UNIT 8 32x3 8IN P HD PHIL BLK GE PART 1408 030...

Page 51: ...oved from the unit FASTPATH Turn off control power before drawing out or re inserting the relay to prevent mal operation Follow the steps outlined in the diagrams below to insert and withdraw the Draw out unit Figure 2 9 Unit withdrawal and insertion diagram 67 3 6 67 3 1 72 7 72 326 7 21 6 1 5 287 81 7 172 37 9 81 7 67 3 0 17 1 1 7 326 7 21 817 5 287 81 7 6 8 16 57 386 1 2 1 1 7 7 1 7 6 5 7 1 725...

Page 52: ...TION CHAPTER 2 INSTALLATION Removable Power Supply Follow the steps outlined in the Insert or Remove Power Supply diagram to insert 1 or remove 2 the power supply from the unit Figure 2 10 Insert or Remove the Power Supply Figure 2 11 Unlatch Module location is marked by arrow ...

Page 53: ...LLATION 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 2 9 Removable Magnetic Module Follow the steps outlined in the diagram below to insert or remove the magnetic module from the unit Figure 2 12 Insert or Remove the Magnetic Module ...

Page 54: ...or fiber which can be damaged if twisted bent or clamped tightly during installation Do not bend sensor fiber sharply or with a radius of less than 25 mm 1 inch Sharp bends can damage the fiber Do not pull or tug loops of sensor fiber as sharp bends may result Do not clamp sensor fiber tightly during installation Sensor fiber should be held in place loosely for the best long term performance Avoid...

Page 55: ...nsor clear of any obstructions that could shield the sensor from arc flash light 2 Mount the sensor securely using the mounting screw holes 3 Once the sensor is securely mounted carefully route the sensor fiber from the AFS sensor to the base unit minimizing loops and curves for the strongest possible signal 4 Secure all sensor fibers loosely but securely away from any moving parts FASTPATH Both t...

Page 56: ...R INPUT 4 C9 C8 C7 C6 C5 C4 C3 C2 C1 C12 C11 C10 C15 C14 C13 C18 C17 C16 SHIELD RETURN COMP HOT COMP HOT RETURN COMP HOT HOT RESERVED SHIELD COMP RETURN COMP HOT COMP HOT RTD 7 RTD 7 8 RTD 8 RTD 9 RTD 10 RTD 11 RTD 12 RTD 9 10 B9 B8 B7 B6 B5 B4 B3 B2 B1 B12 B11 B10 B15 B14 B13 B18 B17 B16 SHIELD RETURN COMP HOT COMP HOT RETURN COMP HOT HOT RESERVED SHIELD COMP RETURN COMP HOT COMP HOT RTD 1 RTD 1 ...

Page 57: ...C4 C3 C2 C1 C12 C11 C10 C15 C14 C13 C18 C17 C16 SHIELD RETURN COMP HOT COMP HOT RETURN COMP HOT HOT RESERVED SHIELD COMP RETURN COMP HOT COMP HOT RTD 7 RTD 7 8 RTD 8 RTD 9 RTD 10 RTD 11 RTD 12 RTD 9 10 B9 B8 B7 B6 B5 B4 B3 B2 B1 B12 B11 B10 B15 B14 B13 B18 B17 B16 SHIELD RETURN COMP HOT COMP HOT RETURN COMP HOT HOT RESERVED SHIELD COMP RETURN COMP HOT COMP HOT RTD 1 RTD 1 2 RTD 2 RTD 3 RTD 4 RTD 5...

Page 58: ...5 C4 C3 C2 C1 C12 C11 C10 C15 C14 C13 C18 C17 C16 SHIELD RETURN COMP HOT COMP HOT RETURN COMP HOT HOT RESERVED SHIELD COMP RETURN COMP HOT COMP HOT RTD 7 RTD 7 8 RTD 8 RTD 9 RTD 10 RTD 11 RTD 12 RTD 9 10 B9 B8 B7 B6 B5 B4 B3 B2 B1 B12 B11 B10 B15 B14 B13 B18 B17 B16 SHIELD RETURN COMP HOT COMP HOT RETURN COMP HOT HOT RESERVED SHIELD COMP RETURN COMP HOT COMP HOT RTD 1 RTD 1 2 RTD 2 RTD 3 RTD 4 RTD...

Page 59: ... C14 C13 C18 C17 C16 SHIELD RETURN COMP HOT COMP HOT RETURN COMP HOT HOT RESERVED SHIELD COMP RETURN COMP HOT COMP HOT RTD 7 RTD 7 8 RTD 8 RTD 9 RTD 10 RTD 11 RTD 12 RTD 9 10 B9 B8 B7 B6 B5 B4 B3 B2 B1 B12 B11 B10 B15 B14 B13 B18 B17 B16 SHIELD RETURN COMP HOT COMP HOT RETURN COMP HOT HOT RESERVED SHIELD COMP RETURN COMP HOT COMP HOT RTD 1 RTD 1 2 RTD 2 RTD 3 RTD 4 RTD 5 RTD 6 RTD 3 4 RTD 5 6 SLOT...

Page 60: ...ON Make sure that the first letter on the terminal strip corresponds to the slot location identified on the chassis silkscreen Terminal Connections NOTE NOTE When installing two lugs on one terminal both lugs must be right side up as shown in the picture below This is to ensure the adjacent lower terminal block does not interfere with the lug body Figure 2 18 Orient the Lugs Correctly Figure 2 19 ...

Page 61: ...f applications are available for the 845 relays As such it is not possible to present typical connections for all possible schemes The information in this section covers the important aspects of interconnections in the general areas of instrument transformer inputs other inputs outputs communications and grounding The figure below shows the rear terminal layout of the 845 Platform ...

Page 62: ... 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 1 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Tx4 Rx4...

Page 63: ...485_1 3 RS485_1 4 RS485_1 4 RS485_1 5 RS485_1 COM 5 RS485_1 COM 6 RESERVED 6 RESERVED 7 RESERVED 7 RESERVED 8 RESERVED 8 RESERVED 9 RESERVED 9 RESERVED 10 RESERVED 10 RESERVED RJ45 ETHERNET RJ45 NOT USED A HV I O 2 FA Vmon 3FC 7 Contact Inputs Terminal Description 1 FA_1 COM TRIP 2 FA_1 NO TRIP 3 FA_1 OPT V TRIP 4 FA_2 COM CLOSE AUX 5 FA_2 NO CLOSE AUX 6 FA_2 OPT V CLOSE AUX 7 FC_1 NC AUX 8 FC_1 C...

Page 64: ...ls 14 AWG to 22 AWG 2 1 mm2 to 0 3 mm2 Multiple wire termination with 9 53 mm 0 375 maximum diameter ring terminals Two ring terminals maximum per circuit Suggested wiring screw tightening torques are terminal strips A H tighten to 4 5 in lbs 0 5 N m and terminal blocks J K to 15 in lb 1 7 N m Figure 2 22 Fiber Connector Types S ST 22 FC_3 NC Critical Fail Relay 23 FC_3 COM Critical Fail Relay 24 ...

Page 65: ...5 relay There are no internal ground connections on the current inputs Current transformers with 1 to 12000 A primaries may be used CAUTION Verify that the relay s nominal input current of 1 A or 5 A matches the secondary rating of the connected CTs Unmatched CTs may result in equipment damage or inadequate protection CAUTION IMPORTANT The phase and ground current inputs correctly measure up to 46...

Page 66: ...olarizing voltage V0 are zero Also with the Delta VT connection the phase neutral voltage cannot be measured and is not displayed Restricted Earth Fault Inputs Restricted Earth Fault protection is often applied to transformers having grounded Wye windings to provide ground fault detection for faults near the transformer neutral Each current bank on the relay has 3 phase current inputs and one grou...

Page 67: ...acement of a Zero Sequence current CT so that ground fault current can be detected Twisted pair cabling on the Zero Sequence CT is recommended Figure 2 26 Zero Sequence Core Balance CT Installation Ground connection to neutral must be on the source side UNSHIELDED CABLE LOAD A B C N G Ground outside CT Source LOAD SHIELDED CABLE 996630A5 A B C Source To ground must be on load side Stress cone shie...

Page 68: ... Control Power Connection Contact Inputs Depending on the order code the 845 relay has a different number of contact inputs which can be used to operate a variety of logic functions for circuit switching device control external trips blocking of protection elements etc The relay has contact inputs and virtual inputs that are combined in a form of programmable logic to facilitate the implementation...

Page 69: ...lly excluded from the menus for output selection for the rest of the elements The critical failure output relay is reserved as Relay_8 and it is omitted and is not programmable Table 2 6 Slots F G H Terminal Master Identifier left and I O options A A N right INPUT SIGNAL SWITCH DRY INPUT SIGNAL SWITCH WET EXTERNAL DC POWER SUPPLY Slots F G H Terminal Master Identifier Slots F G H with I O options ...

Page 70: ...log Out_3 RELAY_9 4 RELAY_2 RELAY_10 RELAY_18 4 RELAY_2 Analog Out_4 RELAY_10 5 RELAY_2 RELAY_10 RELAY_18 5 RELAY_2 Analog Out_5 RELAY_10 6 RELAY_2 RELAY_10 RELAY_18 6 RELAY_2 Analog Out_6 RELAY_10 7 RELAY_3 RELAY_11 RELAY_19 7 RELAY_3 Analog Out_7 RELAY_11 8 RELAY_3 RELAY_11 RELAY_19 8 RELAY_3 Return RELAY_11 9 RELAY_3 RELAY_11 RELAY_19 9 RELAY_3 Shield RELAY_11 10 RELAY_4 RELAY_12 RELAY_20 10 RE...

Page 71: ...T F SLOT G SLOT H Terminal SLOT F SLOT H 1 RELAY_1 RELAY_9 Digital In_15 1 RELAY_1 Digital In_8 2 RELAY_1 RELAY_9 Digital In_16 2 RELAY_1 Digital In_9 3 RELAY_1 RELAY_9 Digital In_17 3 RELAY_1 Digital In_10 4 RELAY_2 RELAY_10 Digital In_18 4 RELAY_2 Digital In_11 5 RELAY_2 RELAY_10 Digital In_19 5 RELAY_2 Digital In_12 6 RELAY_2 RELAY_10 Digital In_20 6 RELAY_2 Digital In_13 7 RELAY_3 RELAY_11 Dig...

Page 72: ...r Each relay must be daisy chained to the next one Avoid star or stub connected configurations The last device at each end of the daisy chain should be terminated with a 120 ohm watt resistor in series with a 1 nF capacitor across the positive and negative terminals Some systems allow the shield drain wire to be used as a common wire and to connect directly to the COM terminal others function corr...

Page 73: ... or amplitude modulated AM form The type of form is auto detected by the 845 relay Third party equipment is available for generating the IRIG B signal this equipment may use a GPS satellite system to obtain the time reference so that devices at different geographic locations can also be synchronized Figure 2 30 IRIG B connection GE MULTILIN 8 SERIES IRIG B RECEIVER TO OTHER DEVICES SHIELDED CABLE ...

Page 74: ...2 30 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL ELECTRICAL INSTALLATION CHAPTER 2 INSTALLATION ...

Page 75: ... Security If the relay is in the commissioning phase and you want to bypass authentication switch the Setpoint access setting on or assign it to a contact input Once the setting is on you have complete administrator access from the front panel If a contact input is chosen the access is also conditional on the activation of the respective contact input For more information on setpoint access and ot...

Page 76: ...y are not being used system information is displayed after a user defined period of inactivity Pressing the Menu key during the display of the default message returns the display to the last message shown before the default message appeared Any Trip Alarm or Pickup is displayed immediately automatically overriding the default message ESCAPE ENTER HELP IN SERVICE TRIP ALARM PICK UP XFMR OVERLOAD LO...

Page 77: ...em Inputs Outputs Protection Monitoring Control FlexLogic Status Switches Contact Inputs Metering Summary Currents Voltages Frequency Harmonics Power Energy Current Demand Records Events Fault Reports Breakers Remote Modbus Device Targets Directional Power Data Logger Volts per Hertz Digital Counters RTDs RTD Maximums FlexElements Arc Flash Syncrocheck Testing Output Relays Virtual Inputs Informat...

Page 78: ...oft tabs from the screen or by selecting the item from the list of items on the screen using the Up and Down pushbuttons to move the yellow highlighted line and pressing the pushbutton Enter Figure 3 5 Tab Pushbuttons The tab pushbuttons are used to enter the menu corresponding to the label on the tabs If more than 5 tabs exist the first and the last tab are labelled with arrows to allow you to sc...

Page 79: ...he Enter pushbutton has a dual function It is used to display a sub menu when an item is highlighted It is also used to save the desired value for any selected setpoint The Up and Down pushbuttons are used to select highlight an item from a menu as well as select a value from the list of values for a chosen item The Up Down Left and Right pushbuttons on the membrane faceplate are used to move the ...

Page 80: ...n In all 8 Series devices the Breaker symbol color is configurable as per the color scheme setting in Setpoints Device Front Panel Display Properties Color Scheme Single Line Diagram for 845 and Breaker Transformer status color The 845 has a single line diagram SLD that represents the power system The single line diagram provided is pre configured to show Breaker status AC input connection Rated W...

Page 81: ...Power 1 Pwr1 Real Q Metering Power 1 Pwr1 Reactive PF Metering Power 1 Pwr1 PF Parameter Input for the value W1 Ia Metering CT Bank 2 K1 K1 Ia W1 Ib Metering CT Bank 2 K1 K1 Ib W1 Ic Metering CT Bank 2 K1 K1 Ic W2 Ia Metering CT Bank 3 K2 K2 Ia W2 Ib Metering CT Bank 3 K2 K2 Ib W2 Ic Metering CT Bank 3 K2 K2 Ic P Metering Power 1 Pwr1 Real Q Metering Power 1 Pwr1 Reactive PF Metering Power 1 Pwr1 ...

Page 82: ...The indicators TRIP LED 2 and ALARM LED 3 are also programmable and can be triggered by either a selection of FlexLogic operand assigned in their own menu or by the operation of any protection control or monitoring element with function selected as Trip Alarm or Latched Alarm The RESET key is used to reset any latched LED indicator or Target Message once the condition has been cleared latched cond...

Page 83: ...t is picked up This indicator is never latched TEST MODE This LED indicates that the relay has been set into Test Mode MESSAGE This LED indicates the presence of Target Messages detected by the relay LOCAL MODE This LED indicates that the relay is operating in local mode Breaker status indication is based on the breaker s 52a and 52b contacts With both contacts wired to the relay and configured cl...

Page 84: ...of LED operation is of maximum benefit in installations where languages other than English are used to communicate with operators FASTPATH For LED and Pushbutton programming details please refer to Front Panel Home Screen Icons The next figure shows the icons available on the front screen For descriptions of these screen icons see the following tables Figure 3 11 Home Screen Icons Table 3 1 Securi...

Page 85: ...ples include viewing metering or navigating to a screen with setting etc If no further navigation is performed no pushbutton is touched and or no target is initiated for the time specified in the message timeout setpoint the display goes back to the default screen the metering summary screen The target message interrupts the message timeout It overrides it The message timeout starts timing after e...

Page 86: ...he relay Major errors indicate a problem with the relay which takes it out of service CAUTION Self Test Warnings may indicate a serious problem with the relay hardware Upon detection of a minor problem the relay does the following Displays a detailed description of the error on the relay display as a target message Records the minor self test error in the Event Recorder Flashes the ALARM LED Upon ...

Page 87: ... valid data to match the order code Every 1 second CPanel S N Invalid Control Panel doesn t have valid data to match the order code Every 1 second PSU S N Invalid Power Supply Unit doesn t have valid data to match the order code Every 1 second RTC Error The CPU cannot read the time from the real time clock Every 1 second Product Serial Invalid The product serial number doesn t match the product ty...

Page 88: ...g enclosure for unexpected heat sources i e loose primary cables and remove accordingly Event Rate High Abnormally high amounts of events have been generated so the relay has stopped logging to prevent further issues Every 1 second Ensure settings are not set close to nominal ratings Ensure FlexLogic equations do not have impractical timing for status events IRIG B Failure A bad IRIG B input signa...

Page 89: ...e to pressing certain keys The factory default flash message time is 2 seconds Label Removal The following procedure describes how to use the label removal tool 1 Bend the tabs of the tool upwards as shown in the image 3 To disable Link Error Primary target when not in use with SE order code change IP address to 127 0 0 1 Self test Error Message Latched Target Message Description of Problem How Of...

Page 90: ...from the relay Move the tool inside until the tabs enter the pocket 3 Remove the tool with the LED label The following describes how to remove the user programmable pushbutton label from the 845 front panel 1 Slide the label tool under the user programmable pushbutton label as shown in the next image Make sure the bent tab is pointing away from the relay 2 Remove the tool and user programmable pus...

Page 91: ...menus in the familiar Windows environment This section provides the necessary information to install EnerVista 8 Series Setup software upgrade the relay firmware and write and edit setting files The EnerVista 8 Series Setup software can run without a 845 connected to the computer In this case settings may be saved to a file for future use If a 845 is connected to a PC and communications are enable...

Page 92: ...EnerVista software on the local PC 3 When installation is complete start the EnerVista Launchpad application 4 Click the IED Setup section of the LaunchPad toolbar 5 In the EnerVista Launchpad window click the Add Product button and select the 845 Protection System as shown below Select the Web option to ensure the most recent software release or select CD if you do not have a web connection then ...

Page 93: ... loaded into the computer and the installation program automatically creates icons and adds the EnerVista 8 Series Setup software to the Windows start menu 9 The 845 device is added to the list of installed IEDs in the EnerVista Launchpad window as shown below If you are going to communicate from your computer to the 845 Relay using the USB port 10 Plug the USB cable into the USB port on the 845 R...

Page 94: ...rface type 14 Select the Read Order Code button Upgrading the Software The latest EnerVista software and firmware can be downloaded from https www gegridsolutions com After upgrading check the version number under Help About If the new version does not display try uninstalling the software and reinstalling the new versions ...

Page 95: ...a fast connection through the front panel USB port of a relay or through the Ethernet port The following window appears when the QuickConnect button is pressed As indicated by the window the Quick Connect feature can quickly connect the software to a front port if the USB is selected in the interface drop down list Select USB and press the Connect button Ethernet or WiFi can also be used as the in...

Page 96: ...845 supports a maximum of 3 TCP IP sessions 1 Install and start the latest version of the EnerVista 8 Series Setup software available from the GE EnerVista CD or Website See the previous section for the installation procedure 2 Click on the Device Setup button to open the Device Setup window and click the Add Site button to define a new site 3 Enter the desired site name in the Site Name field If ...

Page 97: ...ck OK when the relay order code has been received The new device will be added to the Site List window or Online window located in the top left corner of the main EnerVista 8 Series Setup software window The 845 Site Device has now been configured for Ethernet communications Proceed to the following section to begin communications Connecting to the Relay Now that the communications parameters have...

Page 98: ...ed Other setpoint and command windows can be displayed and edited in a similar manner Actual Values windows are also available for display These windows can be arranged and resized if desired Working with Setpoints Setpoints Files FASTPATH When a settings file is being uploaded to a device the DEVICE IN SERVICE state Setpoints Device Installation switches to Not Ready for the duration of the uploa...

Page 99: ...ing setpoints In this example we are changing the voltage sensing setpoints 1 Establish communications with the relay 2 Select the Setpoint System Voltage Sensing menu item 3 Select the Aux VT Secondary setpoint by clicking anywhere in the parameter box This displays three arrows two to increment decrement the value and another to launch the numerical keypad 4 Clicking the arrow at the end of the ...

Page 100: ...n or provides focus to the already opened application New files are automatically added to the tree Using Setpoints Files The software interface supports three ways of handling changes to relay settings In off line mode relay disconnected to create or edit relay settings files for later download to communicating relays Directly modifying relay settings while connected to a communicating relay then...

Page 101: ...e and corresponding device s have been properly defined and configured as shown in Connecting to the Relay above 2 Select the desired device from the site list 3 Select the Read Device Settings from the online menu item or right click on the device and select Read Device Settings to obtain settings information from the device 4 After a few seconds of data retrieval the software requests the name a...

Page 102: ... a particular version are not downloaded into the relay 2 Select the Firmware Version and Order Code options for the new setpoint file 3 For future reference enter some useful information in the Description box to facilitate the identification of the device and the purpose of the file 4 To select a file name and path for the new file click the button beside the File Name box 5 Select the file name...

Page 103: ...e pane select the saved setpoint file 5 From the main window menu bar select the Offline Edit Settings File Properties menu item and note the File Version of the setpoint file If this version is different from the Firmware Revision noted in step 2 select a New File Version that matches the Firmware Revision from the pull down menu 6 For example if the firmware revision is J0J08AA150 SFD Firmware R...

Page 104: ...t Device Information menu item If printing from a previously saved setpoints file select the Offline Print Settings File menu item 3 The Print Export Options dialog box appears Select Setpoints in the upper section and select either Include All Features for a complete list or Include Only Enabled Features for a list of only those features which are currently used in the filtering section and click...

Page 105: ...pgraded since saving the setpoint file see Upgrading Setpoints Files to a New Revision for instructions on changing the revision number of a setpoint file The following procedure illustrates how to load setpoints from a file Before loading a setpoints file it must first be added to the 845 environment as described in the section Adding Setpoints Files to the Environment 1 Select the previously sav...

Page 106: ...settings file do the following 1 Create a default settings file 2 Write the default settings file to the relay 3 Delete all other files with the cid extension 4 Delete any other data files which can be in standard formats such as COMTRADE or csv You cannot directly erase the flash memory but all records and settings in that memory can be deleted Do this from the front panel or EnerVista software u...

Page 107: ...ters and settings for some simple overcurrent elements are easily set The Quick Setup screen is shown as follows Figure 3 16 Quick Setup window Settings names and units can be viewed at this screen To view the range of the settings hover the cursor over the setpoint value field The user can configure and save the settings as required The Save Restore and Default buttons function the same as in the...

Page 108: ...ed in this section Upon successful completion of this procedure the 845 will have new firmware installed with the factory default setpoints The latest firmware files are available from the GE Grid Solutions website at http www gegridsolutions com FASTPATH EnerVista 8 Series Setup software prevents incompatible firmware from being loaded into an 845 relay FASTPATH Note that uploading firmware on a ...

Page 109: ...en appears Select OK to proceed 3 The EnerVista 8 Series Setup software requests the new firmware file Locate the folder that contains the firmware file to load into the 845 The firmware filename has the following format The following screen appears Select YES to proceed 4 EnerVista 8 Series Setup software now prepares the 845 to receive the new firmware file The 845 front panel momentarily displa...

Page 110: ...3 36 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SOFTWARE INTERFACE CHAPTER 3 INTERFACES 5 The following screen appears click YES to proceed with the firmware loading process ...

Page 111: ...tifies the user when the 845 has finished loading and notifies the user to Cycle power to the relay to complete firmware update After successfully updating the 845 firmware the relay is not in service and requires setpoint programming To communicate with the relay the communication settings may have to be manually reprogrammed When communications is established the saved setpoints must be reloaded...

Page 112: ...pages Each page can have a combination of active and passive objects Status metering and control objects are active while the static images for bus generator motor transformer ground etc are passive objects Figure 3 17 SLD Page For optimum use the first SLD page can be used for the overall single line diagram and the subsequent pages can be used for breaker switch specific CT VT placement metering...

Page 113: ...mbols in the GE Standard style and IEC style If the switching element is tagged blocked or bypassed indicators with the letters T B and By appear on the lower right corner of the element Additionally the breaker switch name is displayed on top of the object NOTE NOTE The displayed breaker name is configured in the setpoint Setpoints System Breakers Breaker X Name This setpoint has a 13 character l...

Page 114: ...versed If the setting is used the breaker symbols automatically change to the Truck CB symbols The SLD assumes that if the Breaker Racked In Racked Out input is used any setting other than Off the appropriate Truck CB symbol will be used The following figure shows the orientation available for the control objects The default position for the control objects is 0 degrees Orientation in multiple dir...

Page 115: ...owing figure shows an example of Reclose Blocked signal in both On and Off state Figure 3 21 Reclose Blocked signal In addition Remote Breaker status objects are added for GE and IEC style Remote breaker status allows monitoring of three distant breakers These objects are not controllable and hence cannot be used for selection and operation Metering Objects The metering objects consist of metering...

Page 116: ...relay is in Local Mode Navigation The Single Line Diagram can be accessed in two ways from the front panel of the relay The original location for the SLD pages is under Status Summary Single Line Diagram SLD X However a more convenient way to access an SLD page is by setting it as a default home screen at Setpoints Device Front Panel Home Screens Home Screen1 Pressing home button more than once ro...

Page 117: ... element selection with flash message NOTE NOTE Browsing and selection is allowed only when the relay is in Local Mode and the user has at least an operator level of security access To check if the relay is in local mode look for an LM symbol on the task pane at the top of the screen Pressing navigation keys on SLD pages while in remote mode does nothing NOTE NOTE Control pushbuttons appearing on ...

Page 118: ... actions such as tag blocked bypass and open close are blocked The breaker may remain in the selected state but no action can be executed Once the selected breaker or switch is tagged a letter T appears below the associated element Similarly for blocking letter B appears and for bypassing letters By appear below the associated breaker or switch as shown in the last column of the following figure T...

Page 119: ...rence to customize the operating curve The Blue colored curve in the picture is a reference curve It can be Extremely Inverse Definite Time etc The Trip Reset and Operate Times in the tables and curves work interactively i e changing the table value affects the curve shape and vice versa The user can save Configured Trip Times The user can export Configured Trip Times to a CSV file The user can lo...

Page 120: ...e Transient Recorder Viewer window Click on Trigger Waveform to trigger a waveform capture To view the captured waveforms click on the Launch Viewer button A detailed Waveform Capture window appears as shown below Click on the Save button to save the selected waveform to the local PC A new window appears requesting the file name and path One file is saved as a COMTRADE file with the extension CFG ...

Page 121: ...enu bar press the Preference button to open the COMTRADE Setup page in order to change the graph attributes Display graph values at the corresponding cursor line Cursor lines are identified by their colors FILE NAME Indicates the file name and complete path if saved CURSOR LINES To move lines locate the mouse pointer over the cursor line then click and drag the cursor to the new position TRIGGER L...

Page 122: ...d and select other options as required by checking the appropriate boxes Click OK to store these graph attributes and to close the window The Waveform Capture window reappears based on the selected graph attributes To view a vector graph of the quantities contained in the waveform capture press the View Phasors button to display the following window Preference Button ...

Page 123: ...CHAPTER 3 INTERFACES SOFTWARE INTERFACE 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 3 49 ...

Page 124: ...ements The Protection Summary Screen allows the user to view the output relay R3 R4 assignments for the elements modify the output relay assignments for the elements view the Function status for the elements navigate to the respective element screen on a button click With the software running and communications established select the Setpoints Protection Summary menu item to open the Protection Su...

Page 125: ...a 8 Series Setup software reduces the manual effort required when moving from an older product to the 845 The feature takes an existing settings file provided by the user and generates a new settings file compatible with the 8 Series order code specified by the user After the import is complete the results are displayed in an interactive results window Convert SR 745 Files EnerVista 8 Series Setup...

Page 126: ...e name and path for the new file click the button beside the File Name box 5 To select the SR settings file used for initialization click the Initialize Settings from SR Settings File button 6 To locate and select the file to convert click the button beside the Initialize Settings from SR Settings File box CAUTION EnerVista 8 Series Setup version 1 4x and above supports conversion of 5 0 5 1 and 5...

Page 127: ... offline window but with status icons NOTE NOTE Settings in the results window are linked to setting screens This means the user can click in the results window to navigate to the corresponding 8 Series settings window Value the converted value for the 8 Series settings file Original Name setting name of the input file Original Value setting value of the input file CAUTION All other settings avail...

Page 128: ...3 54 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SOFTWARE INTERFACE CHAPTER 3 INTERFACES ...

Page 129: ...ailable from the paths shown below Each setpoints menu has sub sections that describe in detail the setpoints found on that menu NOTE NOTE Use the path provided to access the menus from the front panel and from the EnerVista 8 Series Setup software NOTE NOTE For certain named settings the user may configure custom names The user should not create 13 character long names using the largest width cha...

Page 130: ...ts some conditions apply All ouputs selected for BKR Trip Output Select under Breaker setup menu are available for selection in the menus of all elements except in the outputs selection for BKR Close Output Select For all elements the default value for the trip selected outputs under Breaker setup shows Do Not Operate The user can select these relays from the menu of the element All outputs select...

Page 131: ...2 3 Close Relay Select from the Setpoints System Breakers Breaker 1 2 3 menu as shown PATH SETPOINTS SYSTEM BREAKER 1 2 3 From these screens Relay 1 Relay 2 and Relay 9 are selected as default outputs for tripping Breaker 1 Breaker 2 and Breaker 3 respectively Output relays for closing the breakers are not selected The user can program any output relay from the list of output relays for breaker tr...

Page 132: ...plemented and will activate upon changing the function from Disabled to Alarm Latched Alarm or Configurable The output relays selected for tripping of the breakers will be de activated in the IOC1 element menu The rest of the outputs are fully programmable and operational The setting for these trip selected output relays can be changed i e from Do Not Operate to Operate but the physical relay will...

Page 133: ...for Operate Do Not Operate programming Figure 4 4 Function setpoint for Phase IOC 1 selected as Trip Example 2 Programming an IOC1 element as an Alarm Latched Alarm or Configurable function 1 Select Alarm Latched Alarm or Configurable as the setpoint Function When Alarm Latched Alarm or Configurable is selected as a Function the Output Relays 1 and 2 which have been assigned to trip Breaker 1 and ...

Page 134: ...re 4 5 Protection Summary screen NOTE NOTE Use the protection summary window for programming all of the elements and output relays needed for the application Please note that the output relays selected for breaker closing are excluded from the menus of all elements and they are made inactive cannot be selected in the Protection Summary menu The check boxes related to these outputs automatically be...

Page 135: ...d be changed from Not Ready the default to Ready Before putting the relay in Ready state each page of setpoint messages should be worked through entering values either by keypad or computer Common Setpoints To make the application of this device as simple as possible similar methods of operation and similar types of setpoints are incorporated in various features Rather than repeat operation descri...

Page 136: ...s Do Not Operate The available auxiliary relays vary depending on the order code DIRECTION The ELEMENT_NAME DIRECTION setpoint is available for overcurrent features which are subject to control from a directional element The range is Disabled Forward and Reverse If set to Disabled the element is allowed to operate for current flow in any direction There is no supervision from the directional eleme...

Page 137: ...corporated in the logic Comparator Blocks Shown as a block with an inset box labeled RUN with the associated pickup dropout setpoint shown directly above Element operation of the detector is controlled by the signal entering the RUN inset The measurement comparison can only be performed if a logic 1 is provided at the RUN input The relationship between a setpoint and input parameter is indicated b...

Page 138: ...eviations are used in the setpoints pages A amperes kA kiloamperes V volts kV kilovolts kW kilowatts kvar kilovars kVA kilo volt amperes AUX auxiliary COM Comms communications CT current transformer GND ground Hz Hertz MAX maximum MIN minimum SEC s seconds UV undervoltage OV overvoltage VT voltage transformer Ctrl control Hr hr hour O L overload ...

Page 139: ...by only displaying settings that are typically used or settings that are important to configure There are two configuration modes supported Simplified and Regular In Simplified configuration mode some of the advanced functions features or a few settings under a function are hidden or made read only greyed out In Regular configuration mode all function features and setpoints of the device are edita...

Page 140: ...n Simplified configuration mode the home icon color changes to green When in Regular mode the home icon color stays blue Example 1 More about the setting items view control The Phase TOC 1 function in Regular mode has 14 setpoints made available to edit read write In the case of Simplified mode this function has only 6 out of the 14 setpoints made available to edit read write 5 setpoints are hidde...

Page 141: ... are hidden or the values are read only to enhance User eXperience UX with minimum setpoint changes Real time Clock Path Setpoints Device Real Time Clock The 845 is capable of receiving a time reference from several time sources in addition to its own internal clock for the purpose of time stamping events transient recorders and other occurrences within the relay The accuracy of the time stamp is ...

Page 142: ...o 59 0 to 59 Default 00 00 00 LOCAL TIME OFFSET FROM UTC Range 24 0 to 24 0 hrs in steps of 0 5 hrs Default 0 0 hrs REAL TIME CLOCK EVENTS Range Disabled Enabled Default Enabled IRIG B Range Disabled Enabled Default Disabled DAYLIGHT SAVINGS TIME Range Disabled Enabled Default Disabled DST START MONTH Range January to December all months Default Not Set DST START DAY Range SUN to SAT all days of t...

Page 143: ... In networks containing one or more switches and or clocks that do not implement both of these mechanisms not all delays are compensated so the time of message arrival at the relay is later than the time indicated in the message The setting can be used to approximately compensate for the delay Since the relay is not aware of network switching that dynamically changes the amount of uncompensated de...

Page 144: ...single domain using the default domain number zero The setting applies to all of the relay s PTP capable ports PTP VLAN PRIORITY Range 0 to 7 Default 4 The setting selects the value of the priority field in the 802 1Q VLAN tag in request messages issued by the relay s peer delay mechanism In compliance with PP Power Profile the default VLAN priority is 4 but it is recommended that in accordance wi...

Page 145: ... protected All the roles except for the Observer role support only one session at one time The Observer role has read only access to all values in the relay except for one service command which is described in the Password Recovery Procedure section All the roles except for the Observer have access to a log out setting which has the effect of switching to Observer role A Setpoint access setting fo...

Page 146: ... has access However if an Operator is first connected before any other user only one Observer is allowed and not two so that an Administrator may always be able to connect This is because the maximum number of TCP connections from EnerVista when the Communications card is not present is only three With a Communications card the maximum number of TCP connections is five Basic Security The 8 Series ...

Page 147: ...lable to Administrator By default password complexity is disabled When password complexity is enabled it follows the rules defined in the Password Complexity section SETPOINT ACCESS This setting is only available to Administrator The setpoint access is used for the purpose of bypassing security It can be either switched on or assigned to a digital input If assigned to a digital input the digital i...

Page 148: ...ntication using RADIUS is added SECURE TUNNELING The following items are supported in the feature Under the CyberSentry option the 8 Series supports SSH secure tunneling of MODBUS communications between itself and EnerVista setup software SSH secure tunneling is supported on Ethernet only If bypass security is set through setpoint access the communications over Ethernet is not encrypted ROLE ACCES...

Page 149: ...ers the wrong password the Authentication Failed message is displayed If the maximum failed authentications occur the Account Blocked message is displayed The Observer user role is the default choice and it does not require a password Setpoints Data Capture Security Real Time Clock Level 1 Level 2 Level 3 Level 4 Device Communications Security Change Administrator Password Change Operator Password...

Page 150: ...e to switch on device authentication After switching on the device authentication the Administrator gains write access to all the other settings without the need to logout and login again LOAD FACTORY DEFAULTS Range Yes No Default No An Administrator role is able to change this setting This resets all the settings communication and security passwords and all records ACCESS LOCKOUT Range 0 99 Defau...

Page 151: ...ssigned to a digital input When the digital input is activated the user gets Administrator access to the front panel FACTORY SERVICE MODE Range Disabled Enabled Default Disabled When the feature is enabled the Factory role is accessible and the device may go into factory service mode The setting may be changed only by an Administrator The default value is Disabled NOTE NOTE The factory role passwo...

Page 152: ...es the user that this operation is allowed only for Administrators e g via a pop up window The EnerVista Login Screen has two radio buttons to choose between device and server authentication If server authentication is chosen the screen provides User Name and Password fields If device authentication is chosen the User Name field changes to a drop down menu If device authentication is enabled inter...

Page 153: ...s General Electric 2910 Administrat or Radius Authenticati on Method Authentication method used by Radius server Currently fixed to EAP TTLS EAP TTLS EAP TTLS EAP TTLS Administrat or Timeout Timeout in seconds in between re transmission requests 0 9999 10 sec Administrat or Retries Number of retries before giving up 0 9999 3 Administrat or Radius Authenticati on Shared Secret Shared Secret used in...

Page 154: ... parameters agree with the settings used on the computer or other equipment connected to this port A maximum of 32 relays can be daisy chained and connected to a DCS PLC or a PC using the RS485 port Path Setpoints Device Communications RS485 BAUD RATE Range 9600 19200 38400 57600 115200 Default 115200 PARITY Range None Odd Even Default None PORT PROTOCOL Range Modbus DNP 3 0 IEC 60870 5 103 Defaul...

Page 155: ...ors WPA and WEP Several forms of WPA2 security keys exist The 8 Series supports WPA2 PSK Pre Shared Key which utilizes 64 hexadecimal digits The key may actually be entered as a string of 64 hexadecimal digits or as a passphrase of 8 to 32 printable ASCII characters For user convenience the settings accept the key in the form of a passphrase Internally the ASCII passphrase is used for deriving a 2...

Page 156: ...ntable ASCII characters Internally a 256 bit key is calculated by applying the PBKDF2 key derivation function to this passphrase using the SSID as the salt and 4096 iterations of HMAC SHA1 The 8 Series devices are configured with a default passphrase which is provided by the vendor with the shipment of any new 8 Series device When choosing a new passphrase the password complexity rules of CyberSen...

Page 157: ...y connect to the configured Access Point 4 Start EnerVista on a PC and use the Discover function all relays within range appear and are populated in EnerVista for initial configuration and commissioning 5 Once the relay is configured change the 8 Series relay default WiFi SSID and Passphrase settings before the relay goes into service Figure 4 11 Example of WiFi Deployment IP address 192 168 0 1 S...

Page 158: ...n both enabled ports are on the communications card the Ethernet port located on the base CPU is disabled Protocols Modbus TCP DNP 3 0 IEC 60870 5 104 IEC 61850 GOOSE IEEE 1588 SNTP IEC 62439 3 clause 4 PRP Wavelength 1310 nm Typical link distance 4 km Network Settings Menu The following are the network settings menu of the 845 to accommodate the features of the 845 product If the communications c...

Page 159: ...Port 4 is active and the link loss problem is detected communications is switched to Port 5 immediately Port 5 is in effect acting as a redundant or backup link to the network for port 4 LLA Link Loss Alert is a proprietary feature supported by the 8 Series relay fiber optic ports When enabled on an 8 Series fiber optic port this feature is able to detect a failure of the fiber link If port 4 s OP...

Page 160: ...h modems at high bit rates Modbus protocol can be implemented at any standard communication speed The 845 supports operation at 9600 19200 38400 57600 and 115200 bps baud rate The USB interface supports ModBus TCP IP FUNCTION CODE SUPPORTED The following functions are supported by the 845 FUNCTION CODE 03H Read Setpoints FUNCTION CODE 04H Read Actual Values FUNCTION CODE 05H Execute Operation FUNC...

Page 161: ...s transmitted high order byte first As a result all 845 Setpoints are sent as two bytes The maximum number of registers that can be read in one transmission is 125 The slave response to this function code is the slave address function code a count of the number of data bytes to follow the data itself and the CRC Each data item is sent as a two byte number with the high order byte sent first For ex...

Page 162: ...RESPONSE BYTES EXAMPLE DESCRIPTION SLAVE ADDRESS 1 FE message from slave 254 FUNCTION CODE 1 03 read registers BYTE COUNT 1 08 4 registers 8 bytes total DATA 1 2 00 00 value in address 4A8A 16 bit DATA 2 2 04 B0 value in address 4A8B 16 bit DATA 3 2 00 00 value in address 4A8C 32 bit DATA 4 2 00 64 CRC low high 2 E7 75 CRC error code MASTER TRANSMISSION BYTES EXAMPLE DESCRIPTION Description Memory...

Page 163: ... 0 0000 Password Characters 15 and 16 62260 F334 0 0000 Password Characters 17 and 18 62261 F335 0 0000 Password Characters 19 and 20 62262 F336 0 0000 Password Characters 21 and 22 62263 F337 0 0000 Slave Function Data Starting Address Number of Setpoints Byte Count Data 1 Data 2 Data 3 Data 4 Data 5 Data 6 Data 7 Data 8 Data 9 FE 10 F322 0016 2C 4164 6D69 6E69 7374 7261 746F 7200 0 0 Data 10 Dat...

Page 164: ...ts the gateway of the default route to be used by IP traffic sent from the relay if no other route towards a given IP destination is found This setting is available only if the communications card is present Path Setpoints Device Communications Routing Static RT1 2 to 6 RT1 2 3 4 5 6 DESTINATION Range Standard IPV4 network address format 0 0 0 1 to 223 255 255 254 Default 127 0 0 1 This setting se...

Page 165: ... for any of the entries 1 to 6 that entry becomes a static route and it must meet all the rules listed in the following section under Important Notes Rule 4 To configure the default route enter a default gateway address A default gateway address configured must be validated against Rule 5 the next rule Deleting a route Rule 5 Routes are deleted by replacing the route destination with the default a...

Page 166: ...is interface is 10 1 1 1 Port 5 IP address 10 1 2 2 connects to LAN 10 1 2 0 24 and to EnerVista setup program through Router 2 Router 2 has an interface on 10 1 2 0 24 and the IP address of this interface is 10 1 2 1 Configuration Network addresses PRT54IP ADDRESS 10 1 1 2PRT4 SUBNET IP MASK 255 255 255 0PRT5 IP ADDRESS 10 1 2 2PRT5 SUBNET IP MASK 255 255 255 0 Routing Settings IPV4 DEFAULT ROUTE...

Page 167: ...annel 1 Port will take the DNP TCP UDP Port 1 and DNP Client Address 1 to allow reject connections The same relation is used by channel 2 DNP Unsol Resp Function Range Enabled Disabled Default Disabled This setting will take effect for Ethernet communication only if the main card is present or a comms card is available in the device This setting enables disables the unsolicited response functional...

Page 168: ...fault 240 This setting determines the size in bytes at which message fragmentation occurs Large fragment sizes allow for more efficient throughput smaller fragment sizes cause more application layer confirmations to be necessary which can provide for more robust data transfer over noisy communication channels DNP OBJECT 1 Default Variation to DNP Object 32 Default Variation These settings allow th...

Page 169: ...for the analog input point For example if the DNP PHASE A VOLTAGE SCALE FACTOR setting is set to 1000 and the Phase A voltage is 72000 V the Phase A voltage is sent on to the 845 as 72 The settings are useful when analog input values must be adjusted to fit within certain ranges in DNP masters FASTPATH Note that a scale factor of 0 1 is equivalent to a multiplier of 10 DNP ANALOG INPUT POINT 0 31 ...

Page 170: ...Buffer Size 1024 Default Class for All Points 1 POINT NAME DESCRIPTION COUNTERS The following details lists both Binary Counters Object 20 and Frozen Counters Object 21 When a freeze function is performed on a Binary Counter point the frozen value is available in the corresponding Frozen Counter point 845 Digital Counter values are represented as 16 or 32 bit integers The DNP 3 0 protocol defines ...

Page 171: ... for individual Analog Input Points can be set using DNP Object 34 FASTPATH 1 A default variation refers to the variation response when variation 0 is requested and or in class 0 1 2 or 3 scans The default variations for object types 1 2 20 21 22 23 30 and 32 are selected via relay settings This optimizes the class 0 poll data size 2 For static non change event objects qualifiers 17 or 28 are only...

Page 172: ...t of the General Group and Group 2 so when a general interrogation or group 2 interrogation takes place all the measurands are included in the response Also there is a cyclic data period setting where it is configured in the scan period to send the measurands to the Master And the last way is by sending spontaneously when a deadband overflow takes place The IEC104 Channels sub menu information is ...

Page 173: ...nt points because they must be unique There is no mechanism in the EnerVista 8 Series Setup software or the front panel HMI to detect duplication of the information index FASTPATH The IEC 60870 5 103 point lists always begin with point 0 and end at the first Off value Since IEC 60870 5 103 point lists must be in one continuous block any points assigned after the first Off point are ignored IEC 618...

Page 174: ...he next examples Example of Additional Options Generate ICD file The menu option generates a default ICD file with the respective order code option and saves the file to the path the user has selected previously Read Device Settings The menu option reads all the settings from the relay by TFTP and creates an 845 file with extension CID The created CID file consists of two sections A private sectio...

Page 175: ...a software The IEC 61850 configurator consists of five sections ICD CID Settings Reports GOOSE Reception GOOSE Transmission Remote Modbus Device The Remote Modbus Device describes a device within the same network as the 8 Series device and the poll mode of operation for retrieving the data The 8 Series device acts as a Modbus Master and initiates Modbus requests to the Modbus slave at a defined po...

Page 176: ...ast one of the assigned triggers Trigger Source Trigger on Pickup Trigger on Operate Trigger on Alarm or Trigger on Trip The number of cycles captured in a single transient record varies based on the number of records sample rate and the number of selected channels There is a fixed amount of data storage for the Transient Recorder the more data captured the less the number of cycles captured per r...

Page 177: ...20 This setting indicates the location of the trigger with respect to the selected length of record For example at 20 selected trigger position the length of each record will be split on 20 pre trigger data and 80 post trigger data TRIGGER SOURCE Range Off Any FlexLogic operand Default Off The trigger source can be any digital input an operand from the list of FlexLogic operands a contact input a ...

Page 178: ...NOTE NOTE If data is not available for the entire duration of pre trigger the trigger position will be based on available pre trigger Path Setpoints Device Data Logger FUNCTION Range Disabled Continuous Triggered Default Continuous This setting configures the mode in which the data logger operates When set to Continuous the data logger actively records any configured channels at the rate defined i...

Page 179: ...ay automatically prepares the parameter list CHANNEL 1 16 MODE Default Sample Range Sample Min Max Mean This setpoint defines the type of sample to be logged in the data logger record with respect to the selected rate i e the time interval selected under the setpoint Rate While enabled the Data Logger executes every protection pass and each of the four modes Sample Max Min or Mean The flexanalog v...

Page 180: ...4 52 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL DEVICE CHAPTER 4 SETPOINTS Figure 4 13 Data Logger Storage Capacity ...

Page 181: ...rVista 8 Series Setup software The file names are numbered sequentially to show which file is older than the other The trigger can be any FlexLogic operand but in most applications it is expected to be the same operand usually a virtual output that is used to drive an output relay to trip a breaker A FAULT RPT TRIG event is automatically created when the report is triggered If a number of protecti...

Page 182: ...hannels can be configured Event Data The Event Data feature stores 64 FlexAnalog quantities each time an event occurs The relay is able to capture a maximum of 1024 records The Event Data behaviour matches that of the Event Recorder This is a Platform feature and a Basic option so it has no dependencies There is no Enabling Disabling of the feature It is always ON When changes are made to the Even...

Page 183: ... LED 5 The setpoint is used to select the LED name by choosing up to 13 alphanumeric characters LED 5 17 COLOR Range Off Red Green Orange Default Orange The setpoint selects the color of the LED Three colors are available for selection depending on the user s preference Red Green and Orange LED 5 17 TRIGGER Range Off Any FlexLogic operands Default Testing On This setpoint requires the assigning of...

Page 184: ...ttings enable the auto reset timer and specify the associated time delay The auto reset timer can be used in select before operate SBO switching device control applications where the command type CLOSE OPEN must be selected prior to command execution The selection must Reset automatically if control is not executed within a specified time period SELF RESET MODE In Self reset mode a pushbutton rema...

Page 185: ...set PB9 PB Block PB10 This setting specifies the 13 character line of the user programmable message and is intended to provide the ID information of the pushbutton ON TEXT Range Up to 13 alphanumeric characters Default PB1 On or PB X On This setting specifies the 13 character line of the user programmable message and is displayed when the pushbutton is in the ON position Refer to the Working with ...

Page 186: ...utton is in Latched mode AUTORESET DELAY Range 0 2 to 600 0 s in steps of 0 1 s Default 1 0 s This setting specifies the time delay for automatic Reset of the pushbutton when in the Latched mode LOCK Range Off Any FlexLogic operand Default Off This setting assigns a FlexLogic operand serving to inhibit pushbutton operation from the front panel pushbuttons This locking functionality is not applicab...

Page 187: ...set Function Disabled Enabled AND FLEXLOGIC OPERAND Pushbutton 1 ON t PKP 0 OR 60 ms 0 TIMER AND AND 200 ms 0 TIMER OR OR SETPOINT Drop Out Timer t RST 0 SETPOINT Auto Reset Delay SETPOINT AND OR Latched Self Reset Latched AND FLEXLOGIC OPERAND Pushbutton 1 OFF FLEXLOGIC OPERAND Pushbutton 1 ON SETPOINT Flash Message Time t RST 0 SETPOINT PB 1 ID Text LCD MESSAGE PB 1 OFF Text XXXXXXXXXX XXXXXXXXX...

Page 188: ... in the Dropout Time setting expires The pulse duration of the pushbutton must be at least 100ms to operate the pushbutton LATCHED MODE In Latched Mode a pushbutton can be set activated by directly pressing the associated tab pushbutton The pushbutton maintains the set state until deactivated by another press of the same button The state of each pushbutton is stored in non volatile memory and main...

Page 189: ...in the summary view BUTTON COLOR Range Black Red Yellow Blue Green Teal Purple White Default Black This setting specifies the background color of the Tab Pushbutton If the button is disabled the button color by default is shown as grey TEXT COLOR Range Black Red Yellow Blue Green Teal Purple White Default White This setting specifies the text color of the Tab Pushbutton INDICATOR COLOR Range Black...

Page 190: ...LOCK Range Any FlexLogic operand Default Off This setting assigns a FlexLogic operand to inhibit pushbutton operation from the front panel pushbuttons This locking functionality is not applicable to pushbutton autoreset DROPOUT TIME Range 0 0 s to 600 0 s in steps of 0 1 s Default 0 0 s This setting applies only to Self reset mode and specifies the duration of the pushbutton active status after th...

Page 191: ...nunciator panel is programmed as one of the homescreens This means that when on the home page pressing the home button multiple times lets the user rotate through all the homescreens Alternatively the annunciator can be accessed by navigating to Status Summary Annunciator Page1 Individual annunciator pages can also be assigned as a homepage If the auto navigation setting is enabled in the setup th...

Page 192: ...e alarm is then acknowledged or reset the background stops flashing If the operand becomes inactive the indicator returns to its default colors The behavior of these modes conforms to ISA 18 1 1979 R2004 standard A 4 5 6 self reset and M 6 latched Figure 4 16 Self Reset Mode Figure 4 17 Latched Mode When any annunciator page is displayed with an alarm condition the navigation keys can be used to s...

Page 193: ...es setting Path Setpoints Device Front Panel Display Properties COLOR SCHEME Range Green open Red open Default Green open This setting defines the color scheme for the breaker status If it is programmed Green open the breaker open status is shown in the color green on the single line diagram and on the device status FLASH MESSAGE TIME Range 1 to 10 s in steps of 1 s Default 5 s Flash messages are ...

Page 194: ...arts after the time of inactivity programmed in the Message Timeout setpoint no PB has been pressed no target message is present Pressing a pushbutton or the presence of a target message inhibits the sequential display of default screens The screen displays resume only after the target messages are cleared and no PB pressing is recorded for 30 seconds When configured the home screen is changed to ...

Page 195: ...default screen is shown after 30 seconds plus the inactivity period defined in Setpoints Device Front Panel Display Properties Message Timeout If the default screens feature and screen saver are disabled the screen defaults to the Values screen after the inactivity period When the home screens are programmed and the default screens feature is enabled but the screens are set to Off the last accesse...

Page 196: ...nd from the list of FlexLogic operands The targets LEDs and latched output relays reset upon assertion from any of the operands selected as Reset Inputs Installation Path Setpoints Device Installation DEVICE NAME Range Up to 13 alphanumeric characters An alphanumeric name may be assigned to the device DEVICE IN SERVICE Default Not Ready Range Not Ready Ready The relay is defaulted to the Not Ready...

Page 197: ...g GGGG CURRENT CUTOFF Range 0 000 to 1 000 p u in steps of 0 001 p u Default 0 020 p u VOLTAGE CUTOFF Range 0 0 to 300 0 in steps of 0 1 V Default 1 0 V FASTPATH Lower the Voltage Cutoff and Current Cutoff levels with care as the relay accepts lower signals as valid measurements Unless dictated otherwise by a specific application the default settings of 0 020 pu for current and 1 0 V for voltage a...

Page 198: ...condary voltage and VT ratios Power Sensing information related to voltage and current banks polarity residing on the same card Power System information related to system frequency tracking frequency phase rotation Transformer information related to transformer losses temperature rise over ambient winding resistance type of transformer capacity winding voltage phase shifting grounding etc Breakers...

Page 199: ...ault 500 A Enter the rated Ground CT primary current for the ground current input for the selected Current 1 bank Path Setpoints System Current Sensing Current Bank 2 K1 Path Setpoints System Current Sensing Current Bank 3 K2 The names and the configuration of the current banks below applies only to 845 orders for two winding transformers without voltage Path Setpoints System Current Sensing CT Ba...

Page 200: ...e one applied to the Aux VT relay terminals from bank J2 Select Vn neutral voltage if the neutral voltage is applied to the relay auxiliary VT AUX VT SECONDARY Range 10 0 to 240 0 V in steps of 0 1 V Default 120 0 V Select the output secondary voltage of the aux VT connected to the aux VT input from bank J2 AUX VT RATIO Range 1 00 to 5000 00 in steps of 0 01 Default 1 00 Select the aux VT ratio to...

Page 201: ...requency tracking are not present or a valid frequency is not detected Before reverting to the nominal frequency the frequency tracking algorithm holds the last valid frequency measurement for a safe period of time while waiting for the signals to reappear or for the distortions to decay PHASE ROTATION Range ABC ACB Default ABC The selection of the PHASE ROTATION setting must match the power syste...

Page 202: ...1 The transformer voltage ratio defines different winding nominal currents 2 The winding CTs are not rated to the exact match of the winding nominal currents 3 Physically the transformer windings are connected in Delta Wye or Zig Zag configuration and they introduce a phase shift For the correct performance of the overall percent differential protection it is necessary to correct the magnitude and...

Page 203: ...lection In this mode the relay expects to measure already phase compensated currents on its terminals In this mode the relay only performs magnitude compensation LOAD LOSS AT RATED LOAD Range 0 001 to 20000 000 kW in steps of 0 001 kW Default 100 000 kW This setting is taken from the transformer nameplate If it is not available from the nameplate the setting value can be computed as PR In W 2 R wh...

Page 204: ...etting defines the type of transformer cooling and is used to calculate the aging acceleration factor The values and their description for this setting are as follows OA oil air FA forced air Non directed FOA FOW non directed forced oil air forced oil water Directed FOA FOW directed forced oil air forced oil water Sealed Self Cooled Vented Self Cooled Forced Cooled as named TOP OIL RISE OVER AMBIE...

Page 205: ... x weight of copper winding or C 0 015 x weight of core and copper windings from the nameplate or C 0 12 x weight of aluminum windings or C 0 02 x weight of core and aluminum coils from the nameplate WNDG THERMAL TIME CONSTANT Range 0 25 to 15 00 min in steps of 0 01 Default 2 00 min This setting is required for the insulation aging calculation If this value is not available from the transformer d...

Page 206: ...from the current transformers CTs connected to the relay by correcting the magnitude and phase relationships of the currents for each winding so as to obtain zero or near zero differential currents under normal operating conditions Traditionally these corrections were accomplished by interposing CTs and tapped relay windings with some combination of CT connections The 845 simplifies these configur...

Page 207: ...Ph Range 0 0001 to 100 0000 ohms in steps of 0 0001 Default 10 0000 ohms Enter the three phase winding resistance from the transformer nameplate PHASE RELATIONSHIPS OF THREE PHASE TRANSFORMERS Power transformers that are built in accordance with ANSI and IEC standards are required to identify winding terminals and phase relationships among the windings of the transformer ANSI standard C 37 12 70 r...

Page 208: ...ses the turns of that winding i e changes its phase phase voltage which in return leads to a different transformation ratio When the transformation ratio is changed the nominal currents of the windings change as well meaning that the computation for CT mismatch based on the initially entered CT and ph ph voltage per winding will be different than the actual CT mismatch This mismatch will appear as...

Page 209: ...to perform phase shift compensation If the transformer has only Wye connected windings the phase currents from the first Wye winding in the setup are used as a reference The power system phase sequence must be set when describing the winding phase relationships since these relationships change when the phase sequence changes The example below shows why this happens using a transformer described in...

Page 210: ...ng have not changed The transformer nameplate phase relationship information is only correct for a stated phase sequence It is suggested that for the ACB sequence the phase relationship can be returned to that shown on the transformer nameplate by connecting source phases A B and C to transformer terminals A C and B respectively This will restore the nameplate phase shifts but will cause incorrect...

Page 211: ...setpoint Angle With Respect to W1 from the menu System Transformer Transformer Setup see Winding 2 and the same setpoint from the menu System Transformer Transformer Setup see Winding 3 for three winding transformer protection NOTE NOTE The angle of Winding 1 is always 0 and this setpoint is omitted from the Winding 1 setup menu The 845 supports all standard two and three winding transformer types...

Page 212: ...es The phase reference winding wf is the winding which will have a phase shift of 0 applied to it The phase reference winding is chosen to be the delta or zigzag non wye winding with the lowest winding index if one exists For a transformer that has no delta or zigzag windings the first wye winding is chosen The phase compensation angle φcomp is the angle by which a winding current is shifted with ...

Page 213: ... w IC p w IC w IB w IA p w IA w IC w IB p w IB w IA w IC p w IC w IB w IA p w IC w IB p w IA w IC p w IB w IA p w IC w IA w IB w IB p w IA w IB w IC w IC p w IB w IA w IC w IA p w IB w IC w IB p w IC w IA w IC p w IA w IB w IA p w IB w IC w IB p w IC w IA w IC p w IA w IB w IA p w IB w IB p w IC w IC p w IA w IA p w IB w IA w IC w IB p w IC w IA w IB w IC p w IA w IB w IC w IA p w IB w IA w IB p w...

Page 214: ... factor for winding 3 see previous sections IA P w IB P w and IC P w phase and zero sequence compensated winding phase currents see earlier The magnitude compensation factor for the reference winding is 1 210 lag 240 lag 270 lag 300 lag 330 lag IA p w 1 3 IC w 1 3 IA w IB p w 1 3 IA w 1 3 IB w IC p w 1 3 IB w 1 3 IC w IA p w 1 3 IC w 1 3 IA w IB p w 1 3 IA w 1 3 IB w IC p w 1 3 IB w 1 3 IC w IA p ...

Page 215: ... w3 IdC IC C w1 IC C w2 IC C w3 Restraint currents are calculated as follows IrA max IA C w1 IA C w2 IA C w3 IrB max IB C w1 IB C w2 IB C w3 IrC max IC C w1 IC C w2 IC C w3 EXAMPLE Consider a typical Wye Delta power transformer with the following data Winding 1 CT Bank 1 J1 500 5 CT ratio Winding 2 CT Bank 2 K1 1500 5 CT ratio Transformer is 50 loaded Magnitude Compensation Based on 50 loading the...

Page 216: ...ch winding is then calculated as follows Rotation ABC φcomp 1 30 0 30 30 lag φcomp 2 30 30 0 The non reference Wye winding will be rotated by 30 degrees to be in phase and match the currents from the Delta winding Per figure Two winding transformer connections for phase compensation angle of 30 lag the relay will use the following phase and zero sequence compensation equations Winding 1 Wye ground...

Page 217: ...STEM INSTRUCTION MANUAL 4 89 Transformer Types and Phase Shift compensation angles The figures below show standard two winding and three winding transformer types and the phase compensation angles which reference the phase reference winding used by the relay ...

Page 218: ...4 90 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SYSTEM CHAPTER 4 SETPOINTS Figure 4 26 Two winding transformer connections ...

Page 219: ...CHAPTER 4 SETPOINTS SYSTEM 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 91 ...

Page 220: ...4 92 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SYSTEM CHAPTER 4 SETPOINTS Figure 4 27 Three winding transformer connections ...

Page 221: ...CHAPTER 4 SETPOINTS SYSTEM 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 93 ...

Page 222: ...4 94 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SYSTEM CHAPTER 4 SETPOINTS ...

Page 223: ...CHAPTER 4 SETPOINTS SYSTEM 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 95 ...

Page 224: ...4 96 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SYSTEM CHAPTER 4 SETPOINTS ...

Page 225: ...CHAPTER 4 SETPOINTS SYSTEM 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 97 ...

Page 226: ...4 98 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SYSTEM CHAPTER 4 SETPOINTS ...

Page 227: ...CHAPTER 4 SETPOINTS SYSTEM 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 99 ...

Page 228: ...the ALL BREAKERS OPEN setpoints closed contacts indicate de energization When Current Supervision is enabled any current exceeding the minimum energization current indicates energization Detection by voltage When energization sensing by voltage is enabled any voltage drops below the minimum energization voltage indicates de energization However if Current Supervision is enabled any of the winding ...

Page 229: ...W2 Ic Minimum W2 Ib Minimum W3 Ia Minimum W3 Ic Minimum W3 Ib Minimum METERING PHASE VOLTAGE J2 Vab Vca Vbc SETPOINT MINIMUM VOLTAGE V Minimum V Minimum V Minimum AND OR SENSING BY BREAKERS OPEN FlexLogic Operand XFMR De Energized FlexLogic Operand XFMR Energized AND AND ALL BREAKERS OPEN AND Disabled 0 Enabled 1 SETPOINT SENSING BY VOLTAGE Disabled 0 Enabled 1 RUN SETPOINT CURRENT SUPERVISION RUN...

Page 230: ... the voltage input must be connected to the appropriate phase voltage terminals on the relay Since the other two voltages per the logic diagram will be zero the transformer de energized status will be detected when the magnitude of the connected single voltage input is below the minimum voltage setting MINIMUM VOLTAGE Range 0 50 to 0 99 x VT in steps of 0 01 x VT Default 0 85 x VT Select the minim...

Page 231: ... Transformer Thermal Inputs WINDING CURRENTS Range CT Bank1 J1 CT Bank 2 K1 CT Bank 3 K2 Default CT Bank 1 J1 Select the bank representing the currents loading of the winding to which the thermal elements are applied AMBIENT TEMPERATURE Range Monthly Average RTD 1 RTD 2 RTD x Default Monthly Average Select RTD input if the ambient temperature is to be measured directly Select the Monthly Average s...

Page 232: ... label in the figure Figure 4 29 Tap position input In this method of detection the resistive output from the tap changer is connected to the Ohms input on the relay The maximum resistance supported by the Ohms input is 5 1kΩ The user defines the minimum and maximum tap voltage increment per tap and the Ohms per tap Tap detection using dcmA analog input In this method the user selects Analog Input...

Page 233: ...k currents Otherwise if the setpoint TC Winding Currents is set to None the mismatch magnitude computation is not automatically updated to include the new transformation ratio In such cases the relay may display differential current where this current will be higher for taps far away from the tap representing the nominal winding voltage and it will be lower for taps closer to the nominal voltage t...

Page 234: ...ge 0 01 to 20 00 kV in steps of 0 01 kV Default 0 50 kV Enter the voltage increment per tap change Ohms at MIN TAP Range 0 to 5100 Ohms in steps of 1 Ohm Default 33 Ohms Enter the resistance in Ohms corresponding to the minimum tap This setting is used only when Ohms input is selected as Tap Detection Input Ohms at MAX TAP Range 0 to 5100 Ohms in steps of 1 Ohm Default 1089 Ohms Enter the resistan...

Page 235: ...isabled When Disabled increasing the tap position increases turns and hence the winding voltage used also for automatic compensation of the currents mismatch which otherwise could be seen as differential current upon changing tap This usually is the case when the OLTC On Load Tap Changer is installed on the winding connected to the load When Enabled increasing the tap position will decrease the am...

Page 236: ... 0 Tap 0 0 0 0 0 1 1 Tap 0 0 0 0 1 0 2 Tap 0 0 0 0 1 1 3 Tap 0 0 0 1 0 0 4 Tap 0 0 0 1 0 1 5 Tap 0 0 0 1 1 0 6 Tap 0 0 0 1 1 1 7 Tap 0 0 1 0 0 0 8 Tap 0 0 1 0 0 1 9 Tap 0 0 1 0 1 0 invalid Tap 0 0 1 0 1 1 invalid Tap 0 0 1 1 0 0 invalid Tap 0 0 1 1 0 1 invalid Tap 0 0 1 1 1 0 invalid Tap 0 0 1 1 1 1 invalid MIN TAP BCD bit 6 Input BCD bit 5 Input BCD bit 4 Input BCD bit 3 Input BCD bit 2 Input BCD...

Page 237: ... 0 1 0 0 0 28 Tap 1 0 1 0 0 1 29 Tap 1 0 1 0 1 0 invalid Tap 1 0 1 0 1 1 invalid Tap 1 0 1 1 0 0 invalid Tap 1 0 1 1 0 1 invalid Tap 1 0 1 1 1 0 invalid Tap 1 0 1 1 1 1 invalid MIN TAP BCD bit 6 Input BCD bit 5 Input BCD bit 4 Input BCD bit 3 Input BCD bit 2 Input BCD bit 1 Input TAP Position Tap 1 1 0 0 0 0 30 Tap 1 1 0 0 0 1 31 Tap 1 1 0 0 1 0 32 Tap 1 1 0 0 1 1 33 Tap 1 1 0 1 0 0 34 Tap 1 1 0 1...

Page 238: ...connected to the Breaker auxiliary contact 52a CONTACT INPUT 52b Range Off Any FlexLogic operand Default Off Selects the Contact Input connected to the Breaker auxiliary contact 52b CONNECTED Range Off Any FlexLogic operand Default Off Select a contact input to show whether the breaker is connected Racked in or disconnect switches switched on or disconnected racked out or disconnect switches switc...

Page 239: ...ntact Status 52b Contact Status Breaker Status Off On BKR Opened On Off BKR Closed On On BKR Unknown State Off Off BKR Unknown State SETPOINT BKR 1 CONNECTED FlexLogic operand 1 Off 0 FlexLogic operand status AND OR FLEXLOGIC OPERANDS BKR 1 Disconnected FLEXLOGIC OPERANDS BKR 1 Connected 894207A1 cdr SETPOINT 52a CONTACT FlexLogic operand 1 Off 0 SETPOINT 52b CONTACT FlexLogic operand 1 Off 0 Flex...

Page 240: ...puts 89a and 89b show normal states on the relay Path Setpoints System Switches Switch 1 9 NAME Range 13 alphanumeric characters Default SW 1 Assign a user defined name to the disconnect switch This name is used in the SLD flash messages related to disconnect switch 1 and the event recorder CONTACT INPUT 89a Range Off Any FlexLogic operand Default Off Select an operand usually NO aux contact wired...

Page 241: ... on output relay selection availability EVENTS Range Disabled Enabled Default Enabled This setting disables or enables the disconnect switch operation events TARGETS Range Disabled Self Reset Latched Default Enabled This setting disables or enables the disconnect switch operation Targets The logic for Switch configuration and the Open and Close status is shown in the following tables Table 4 21 Sw...

Page 242: ...xLogic operand SW1 89a state FlexLogic operand SW1 89b state AND AND XOR PKP S R LED ALARM LATCH OR AND OR OR AND AND FLEXLOGIC OPERANDS SW1 CLOSED FLEXLOGIC OPERANDS SW1 OPENED FLEXLOGIC OPERANDS SW1 DISCREPANCY OR FLEXLOGIC OPERANDS SW1 NOT CONFIGURED SETPOINT ALARM DELAY t Positive Edge SETPOINT RESET ALARM FlexLogic operand Off 0 FLEXLOGIC OPERANDS SW1 INTERMITTENT FLEXLOGIC OPERAND 89a CONTAC...

Page 243: ...r entering times to reset and operate 40 points for reset from 0 to 0 98 times the Pickup value and 80 for operate from 1 03 to 20 times the Pickup This data is converted into two continuous curves by linear interpolation between data points Path Setpoints System FlexCurves NOTE NOTE Please use the EnerVista 8 Series Setup software program to select design or modify any of the four FlexCurves The ...

Page 244: ...NFIGURATION WITH ENERVISTA 8 SERIES SETUP SOFTWARE The EnerVista 8 Series Setup software allows for easy configuration and management of FlexCurves and their associated data points Prospective FlexCurves can be configured from a selection of standard curves to provide the best approximate fit then specific data points can be edited afterwards Alternately curve data can be imported from a specified...

Page 245: ...ting voltage supply is 100 mA When the internal 24 V supply is used the current limitations of the 24V supply must be considered The Contact Inputs are either open or closed with a programmable debounce time to prevent false operation from induced voltage The debounce time is adjustable by the user per manufacturer specifications A raw status is scanned for all Contact Inputs synchronously at the ...

Page 246: ...t Inputs The FlexLogic operand response time to the Contact Input change is related to the debounce time setting plus up to one protection pass variable and depending on system frequency if frequency tracking enabled For example 8 protection passes per cycle on a 60 Hz system correspond to a protection pass every 2 1 ms With a contact debounce time setting of 3 0 ms the FlexLogic operand assert ti...

Page 247: ...ps of five contact inputs and therefore requires two Voltage Threshold settings While Contact input card type C allocated at Slot B has three groups of five contact inputs and therefore requires three Voltage Threshold settings Each Voltage Threshold setting is distinct by the slot or terminal numbers For example Voltage Threshold Slot F specifies the threshold setting of all the contact inputs in...

Page 248: ...abled Disabled Default Enabled For example to use Contact Input F1 as a status input from the breaker 52b contact to seal in the trip relay and record it in the Event Records menu make the following settings changes CONTACT INPUT 1 NAME 52b CONTACT INPUT 1 EVENTS Enabled FASTPATH The 52b contact is closed when the breaker is open and open when the breaker is closed Virtual Inputs The 845 relay is ...

Page 249: ... Self Reset when the input signal transits from OFF to ON the output operand will be set to ON for only one evaluation of the FlexLogic equations then return to OFF If set to Latched the virtual input sets the state of the output operand to the same state as the most recent received input FASTPATH The self reset operating mode generates the output operand for a single evaluation of the FlexLogic e...

Page 250: ...ransducers limit this isolation to 36 V with respect to the 8 Series safety ground Depending upon the order code the 8 Series relay supports one optional DC analog card The analog card has 4 analog inputs and 7 analog outputs For each element when the measured analog input quantity exceeds the Pickup level for longer than the associated time delay the relay can be configured to cause an alarm or t...

Page 251: ...ximum are scaled linearly TRIP FUNCTION Range Disabled Trip Configurable Default Disabled Selecting the Trip or Configurable setting enables the Trip function of the analog input If Disabled is selected the main function still remains enabled and reads the meter value TRIP TYPE Range Over Under Default Over This setting determines if pickup occurs when the analog input is over or under the program...

Page 252: ...s of 1 Default 5 This setting represents the variation of pickup value in percentage of pickup at which the alarm element will effectively drop out The drop out ratio is defined as follows Drop Out pickup pickup dropout ratio 100 when ALARM TYPE is Over Drop Out pickup pickup dropout ratio 100 when ALARM TYPE is Under For example if the pickup level is 5000 µA ALARM TYPE is set to Over and DROPOUT...

Page 253: ...4 125 EVENTS Range Disabled Enabled Default Enabled This setting enables or disables the events of the Analog Input function TARGETS Range Disabled Self Reset Latched Default Latched The selection of the Self Reset or Latched setting enables the targets of the Analog Input function ...

Page 254: ...te Operate Anlg Ip 1 ALARM OP AND AND OR LATCH S R RESET Command LED Alarm FLEXLOGIC OPERANDS Anlg Ip 1 TRIP PKP SETPOINT Output Relay Do Not Operate Operate Anlg Ip 1TRIP OP Operate Output Relay 1 TRIP LED TRIP OR AND ANALOG INPUT Measured Signal SETPOINT Enabled 1 FUNCTION Disabled 0 SETPOINT MIN VALUE NAME UNITS RANGE MAX VALUE SETPOINT TRIP TYPE OVER UNDER Dropout Ratio VALUE PKP VALUE PKP RUN...

Page 255: ...nder the Breaker menu for breaker tripping the operation of the output follows the Trip logic diagram below 2 If the auxiliary output relay is programmed under the Breaker menu for breaker closing the operation of the output follows the Close logic diagram 3 If the auxiliary output is not programmed for tripping or closing a breaker the operation of the output follows the Auxiliary Relay Generic l...

Page 256: ...t relays can be used for many different purposes such as opening and closing breakers contactors switches control of primary equipment such as motor transformer generator for blocking or supervision purposes for interlocking ect To avoid using the same output relay for two totally different actions the 8series relays checks the assignments of these output relays and prevents their usage for some o...

Page 257: ...Place selected Assigned Non assigned Output Relays Available Hidden Output Relays in Setpoints Protection Control Monitoring Elements BKR 1 3 Trip Relay Select BKR 1 3 Close Relay Select SW 1 9 Open Relay Select SW 1 9 Close Relay Select Other Auxiliary Relays Available Hidden Hidden Hidden Available Output Relays in Control Elements with Restoration Ability BKR 1 3 Trip Relay Select BKR 1 3 Close...

Page 258: ...ent BLOCK Range Disabled Any FlexLogic operand Default Disabled This setting defines a Block to the Trip output relay When the selected input is asserted the Trip output relay is blocked TYPE Range Self Reset Latched Pulsed Default Latched This setting defines the sequence type of the Trip output relay The functionality is described in the Outputs Output Relays Trip and Close Relays section OPERAT...

Page 259: ...ime expiry Upon dropout of the trip signal and no breaker open status detected this timer will start on the raising edge of a pulse issued from either of the two timers and will produce positive pulse upon time expiry When breaker open status is detected and no trip is present the output relay will stay reset AND TYPE SETPOINT Pulsed Self Reset RESET command For 850 only Latched Relay Ready 1 OPER...

Page 260: ...r breaker Close Path Setpoints Outputs Output Relays Path Setpoints Outputs Output Relays Aux Relay 2 Close NOTE NOTE The output relays selected under the Breaker menu for breaker closing are excluded from the list of outputs for selection under the menus of all elements providing such output relay selection ...

Page 261: ...mer will start on the raising edge of a pulse issued from either of the two timers and will produce positive pulse upon time expiry This timer starts on the falling edge of a pulse and issues a positive pulse upon time expiry This timer starts on the falling edge of a pulse and issues a positive pulse upon time expiry For 850 only For 850 only Relay Ready 1 OPERATE SETTING FL Operand Off 0 OR AND ...

Page 262: ... will be reapplied to the last pulse resulting in prolonged time for which the output will stay energized before going to de energized mode BLOCK Range Disabled Any FlexLogic operand Default Disabled This setting defines a block to the Auxiliary output relay When the selected input is asserted the Aux relay is blocked OPERATE Range Off Any FlexLogic operand Default Off This setpoint provides a sel...

Page 263: ... below Figure 4 43 Critical Failure Relay 8 Scheme 892828A3 cdr AND SETPOINT TYPE Latched Self Reset AND AND OR AND OR RESET Command Operate Aux Output Relay Pulsed AND SETPOINT OPERATE Off 0 SEAL IN TIME SETPOINT t This setpoint is displayed only upon Pulsed output type selection OR Operation from Protection Control or Monitoring Elements Relay Ready 1 Relay Ready 1 OR BLOCK SETTING Off 0 Relay R...

Page 264: ...acters Default VO 1 An alphanumeric name may be assigned to a virtual output for diagnostic setting and event recording purposes EVENTS Range Disabled Enabled Default Disabled Analog Outputs Description Depending on the order code the 8 Series relay supports one optional DC analog card The Analog card has 4 analog inputs and 7 analog outputs There are three Analog Output channel scenarios for anal...

Page 265: ...UM VALUE Range Populates per selection of the analog parameter Default 0 This setting defines the minimum value of the analog output quantity It populates based on the selection of the analog parameter MAXIMUM VALUE Range Populates per selection of the analog parameter Default 0 This setting defines the maximum value of the analog output quantity It populates based on the selection of the analog p...

Page 266: ...tional Overcurrent Protection 67P Neutral Time Overcurrent Protection 51N Neutral Instantaneous Overcurrent Protection 50N Neutral Directional Overcurrent Protection 67N Ground Time Overcurrent Protection 51G Ground Instantaneous Overcurrent Protection 50G Ground Directional Overcurrent Protection 67G Restricted Ground Earth Fault 87G Negative Sequence Time Overcurrent Protection 51_2 Negative Seq...

Page 267: ...27P Auxiliary Undervoltage 27X Phase Overvoltage Protection 59P Auxiliary Overvoltage Protection 59X Neutral Overvoltage Protection 59N Negative Sequence Overvoltage Protection 59_2 Volts per Hertz 24 Power Elements Directional Power 32 Frequency Elements Underfrequency 81U Overfrequency 81O Frequency Rate of Change 81R ...

Page 268: ...ank is connected at the neutral side of the generator and must be configured as Winding 2 K1 Figure 4 46 Filtering and Calculation of differential and restraint currents The 845 continuously calculates per phase differential and restraint currents and compares the ratio between the two values with a user pre defined differential restraint characteristic The purpose of the characteristic is to defi...

Page 269: ...ed in the menu While at the same time the differential restraint ratio is below a slope average calculated based on Slope 1 and Slope 2 settings The directional flag is not checked unless the SAT flag is initiated Normally during internal faults the trajectory of the differential restraint ratio does not cross the average calculated breakpoint threshold in which case the directional flag is not ch...

Page 270: ...seen during transformer tap changer operation providing the tap changer automatic differential current compensation is disabled i e the setpoint TC Winding Currents from Tap Changer setup set to None If this setpoint is set to a current bank J1 K1 K2 representing any of the transformer winding currents the Minimum Pickup can be set to be more sensitive but not below the differential current caused...

Page 271: ...ferential current Slope 2 must be set high enough to cope with the worst case when the CTs from one winding saturate but the CTs from the other winding do not saturate during external fault In such case the ratio of the differential to restraint current can be as high as 95 to 98 Break 1 Break 1 must be set to reflect the through current restraint current expressed in times winding 1 CT w1 below w...

Page 272: ...ms Burden resistance of 2 19 Ohms and Burden reactance of 0 01 Ohms Logging this data into the CT sat tool produces the following CT saturation waveform The waveform shows that during this external bolted fault with maximum fault current of 25 kA the CT 3000 5 will saturate severely and produce only a of a cycle saturation free time Break 2 must be set to a through fault current so that the CT 300...

Page 273: ... 3000 5 times winding 2 CT Bringing this to the same scale with respect to winding 1 CT reference i e multiplying by a magnitude of 0 4521 the Break 2 setting would be Break 2 5 0 4521 2 21 xCT w1 Figure 4 48 Examples of differential restraint trajectory during internal fault Figure 4 49 Examples of differential restraint trajectory during external fault ...

Page 274: ...ure sensitivity on internal faults at normal transformer loading The value of slope 1 must be above the maximum differential currents which may be seen for through currents with magnitudes less than break 1 setting The differential currents can be caused by winding CT inaccuracies the constant transformer magnetizing current and the leakage current from in zone grounding transformers Usually a mar...

Page 275: ... the inrush inhibit function None of the settings for inrush inhibit are active when the function is set to Disabled INRUSH INHIBIT LEVEL Range 1 0 to 40 0 in steps of 0 1 Default 20 0 This setting specifies the ratio of the 2nd harmonic differential current to the fundamental frequency differential current for the selected mode of the 2nd harmonic inhibit The percent differential protection will ...

Page 276: ...otection is not desirable The relay uses a traditional 5th harmonic ratio for inhibiting the differential function during overexcitation conditions OVEREXCITATION LEVEL Range 1 0 to 40 0 in steps of 0 1 Default 10 0 This setting specifies the level of 5th harmonic during overexcitation overfluxing transformer conditions When the 5th harmonic level exceeds the specified OVEREXCITATION LEVEL setting...

Page 277: ...LAYS Range Do Not Operate Operate Default Do Not Operate The menu includes a list of available output relays to be set for operation or no operation upon protection operation FASTPATH The output relays selected under the Breaker menu for breaker trip need to be reselected if the Percent Differential function is set to Trip These output relays will not be operational even if selected to operate if ...

Page 278: ...ND AND AND LED PICKUP OR RUN 2nd Harm Diff A 2nd Harm Diff B 2nd Harm Diff C 5th Harm Diff A 5th Harm Diff B 5th Harm Diff C SETPOINTS FUNCTION Disabled 0 Trip OR OR AND AND LED ALARM AND S R LATCH Configurable LED TRIP RESET Command Set Dominant Do Not Operate Operate r d Ia Diff Ia Restr r d Ib Diff Ib Restr Ic Diff Ic Restr r d Iad 0 5 x PKP Ibd 0 5 x PKP Icd 0 5 x PKP OR Percent Diff Warn 10s ...

Page 279: ... 208 This setting identifies the level of transformer overload where the pickup delay starts timing For a two winding transformer the setting is expressed as a percentage of the transformer base MVA rating and is normally set at or above the maximum rated MVA from the transformer nameplate For a three winding transformer the setting is expressed as a percentage of the winding base MVA rating PICKU...

Page 280: ...INT BLOCK Off 0 W2 load PICKUP W1 load PICKUP W3 load PICKUP SETPOINT t PKP OR LED ALARM RESET Command AND S R LATCH Configurable SETPOINTS OUTPUT RELAYS Do Not Operate Operate 0 PICKUP DELAY LED TRIP Set Dominant Overload PKP FlexLogic Operands Overload OP FlexLogic Operands ACTUAL VALUES SETPOINT Overtemp Input Operand X 1 Off 0 FlexLogic operand status AND OR W1 Overload PKP FlexLogic Operands ...

Page 281: ...devices If none of these curve shapes is adequate FlexCurves may be used to customize the inverse time curve characteristics The definite time curve is also an option that may be appropriate if only simple protection is required Table 4 23 OVERCURRENT CURVE TYPES Setpoints Device System Inputs Outputs Protection Monitoring Control FlexLogic Data Capture Group 1 Phase IOC Phase TOC Neutral TOC Phas...

Page 282: ...current falls below the reset threshold The Timed selection can be used where the relay must coordinate with electromechanical relays IEEE CURVES The IEEE Time Overcurrent curve shapes conform to industry standards and the IEEE C37 112 1996 curve classifications for extremely very and moderately inverse The IEEE curves are derived from the formula Where T operate time in seconds TDM Multiplier set...

Page 283: ... 538 14 387 10 465 8 410 7 196 6 418 5 889 5 513 10 0 161 790 70 277 29 423 17 983 13 081 10 513 8 995 8 023 7 361 6 891 IEEE MODERATELY INVERSE 0 5 3 220 1 902 1 216 0 973 0 844 0 763 0 706 0 663 0 630 0 603 1 0 6 439 3 803 2 432 1 946 1 688 1 526 1 412 1 327 1 260 1 207 2 0 12 878 7 606 4 864 3 892 3 377 3 051 2 823 2 653 2 521 2 414 4 0 25 756 15 213 9 729 7 783 6 753 6 102 5 647 5 307 5 041 4 ...

Page 284: ... 5 301 2 148 1 365 1 040 0 864 0 755 0 680 0 625 0 583 6 0 18 805 7 951 3 221 2 047 1 559 1 297 1 133 1 020 0 937 0 874 8 0 25 073 10 602 4 295 2 730 2 079 1 729 1 510 1 360 1 250 1 165 10 0 31 341 13 252 5 369 3 412 2 599 2 161 1 888 1 700 1 562 1 457 ANSI NORMALLY INVERSE 0 5 2 142 0 883 0 377 0 256 0 203 0 172 0 151 0 135 0 123 0 113 1 0 4 284 1 766 0 754 0 513 0 407 0 344 0 302 0 270 0 246 0 2...

Page 285: ... 0 900 0 675 0 540 0 450 0 386 0 338 0 300 0 40 10 800 5 400 2 700 1 800 1 350 1 080 0 900 0 771 0 675 0 600 0 60 16 200 8 100 4 050 2 700 2 025 1 620 1 350 1 157 1 013 0 900 0 80 21 600 10 800 5 400 3 600 2 700 2 160 1 800 1 543 1 350 1 200 1 00 27 000 13 500 6 750 4 500 3 375 2 700 2 250 1 929 1 688 1 500 IEC CURVE C 0 05 3 200 1 333 0 500 0 267 0 167 0 114 0 083 0 063 0 050 0 040 0 10 6 400 2 6...

Page 286: ... 2 0 6 796 2 997 1 212 0 711 0 491 0 372 0 298 0 248 0 212 0 185 4 0 13 591 5 993 2 423 1 422 0 983 0 744 0 595 0 495 0 424 0 370 6 0 20 387 8 990 3 635 2 133 1 474 1 115 0 893 0 743 0 636 0 556 8 0 27 183 11 987 4 846 2 844 1 966 1 487 1 191 0 991 0 848 0 741 10 0 33 979 14 983 6 058 3 555 2 457 1 859 1 488 1 239 1 060 0 926 IAC VERY INVERSE 0 5 1 451 0 656 0 269 0 172 0 133 0 113 0 101 0 093 0 0...

Page 287: ...0 070 0 061 0 057 0 054 0 052 0 051 0 050 0 049 2 0 0 286 0 190 0 140 0 123 0 114 0 108 0 105 0 102 0 100 0 099 4 0 0 573 0 379 0 279 0 245 0 228 0 217 0 210 0 204 0 200 0 197 6 0 0 859 0 569 0 419 0 368 0 341 0 325 0 314 0 307 0 301 0 296 8 0 1 145 0 759 0 559 0 490 0 455 0 434 0 419 0 409 0 401 0 394 10 0 1 431 0 948 0 699 0 613 0 569 0 542 0 524 0 511 0 501 0 493 MULTIPLIER TDM CURRENT I Ipicku...

Page 288: ...rom 50 to 600000 milliseconds Where T operate time in seconds TDM Multiplier setting I input current Ipickup Pickup Current setting TRESET reset time in seconds assuming energy capacity is 100 and RESET is Timed Percent of Load To Trip The Percent of Load to Trip is calculated from the phase with the highest current reading It is the ratio of this current to the lowest pickup setting among the pha...

Page 289: ...etting The selection of TDM when in Definite Time mode sets the time to operate in seconds Path Setpoints Protection Group 1 6 Current Phase TOC 1 X FUNCTION Range Disabled Trip Alarm Latched Alarm Configurable Default Disabled INPUT Range Phasor RMS Default Phasor PICKUP Range 0 050 to 30 000 x CT in steps of 0 001 x CT Default 1 000 x CT CURVE Range IEEE Extremely Very Moderately Inverse ANSI Ex...

Page 290: ...t to 1 000 XCT in case of system faults cause generator terminal voltage drops to 0 4 pu ratio of Phase Phase Voltage VT Nominal Phase phase voltage the new pickup with voltage restraint would be 1 000 0 4 0 400 xCT During the fault condition when the voltage drops the overcurrent relay pickup also drops linearly and it should be verified that for the limiting case the new voltage restraint relay ...

Page 291: ...TOC 1 OP B Phase TOC 1 OP A FlexLogic Operands Phase TOC 1 PKP Phase TOC 1 PKP C Phase TOC 1 PKP B Phase TOC 1 PKP A SETPOINTS INPUT Phasor RMS RESET From Cold Load Pickup TOC Pickup Raise From Autoreclose TOC Pickup Raise SETPOINTS OUTPUT RELAYS Do Not Operate Operate LED TRIP Set Dominant From Manual Close Blocking TOC Pickup Raise RUN Calculate Voltage Restraint Multiplier SETPOINT VOTAGE RESTR...

Page 292: ...red current drops below 97 98 of the Pickup value before the time for operation is reached Path Setpoints Protection Group1 6 Current Phase IOC 1 X FUNCTION Range Disabled Trip Alarm Latched Alarm Configurable Default Disabled SIGNAL INPUT Range Dependant upon the order code Default CT Bank 1 J1 This setting provides the selection for the current input bank The three bank names listed above are th...

Page 293: ...OR LED ALARM RESET Command AND S R LATCH Configurable Phase IOC 1 OP Phase IOC 1 OP A Phase IOC 1 OP B Phase IOC 1 OP C FlexLogic Operands Phase IOC 1 PKP Phase IOC 1 PKP A Phase IOC 1 PKP B Phase IOC 1 PKP C FlexLogic Operands SETPOINTS OUTPUT RELAYS Do Not Operate Operate t RST t RST t RST PICKUP DELAY LED TRIP Set Dominant Ph A Reverse from Phase Directional OC element From Manual Close Blockin...

Page 294: ...crease security for three phase faults very close to the VTs used to measure the polarizing voltage a voltage memory feature is incorporated This feature remembers the measurement of the polarizing voltage 3 cycles back from the moment the voltage collapsed below the polarizing voltage threshold and uses it to determine direction The voltage memory remains valid for one second after the voltage ha...

Page 295: ...ration upon expiration of voltage memory When set to Yes the directional element output value is forced to Reverse when voltage memory expires when set to No the directional element is Forward when voltage memory expires BLOCK Range Off Any FlexLogic operand Default Off EVENTS Range Enabled Disabled Default Enabled TARGETS Range Self reset Latched Disabled Default Self reset FASTPATH The Phase Dir...

Page 296: ... VALUES Ia Seq ABC Seq ACB Vbc Vcb SETPOINT REV WHEN V MEM EXP No Yes SETPOINT POLARIZING V TRESHOLD Vact if V V minimum Vmem if V Vminimum V V minimum MEMORY TIMER 1 cycle 1 sec AND AND PHASE B LOGIC SIMILAR TO PHASE A PHASE C LOGIC SIMILAR TO PHASE A Ph Dir OC REV A FLEXLOGIC OPERANDS Ph Dir OC REV B FLEXLOGIC OPERANDS Ph Dir OC REV C FLEXLOGIC OPERANDS To phase TOC IOC elements To phase TOC IOC...

Page 297: ...in steps of 0 001 x CT Default 1 000 x CT CURVE Range IEEE Extremely Very Moderately Inverse ANSI Extremely Very Normally Moderately Inverse Definite time IEC A B C and Short Inverse IAC Extremely Very Inverse Short Inverse FlexCurve A B C D I2t I4t Default IEEE Moderately Inverse This setting sets the shape of the selected over current inverse curve If none of the standard curve shapes is appropr...

Page 298: ...CTION MANUAL PROTECTION CHAPTER 4 SETPOINTS BLOCK Range Off Any FlexLogic operand Default Off OUTPUT RELAY X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Range Self reset Latched Disabled Default Self reset ...

Page 299: ...arm AND RESET Neutral current In Calculated as a sum of phase currents SETPOINTS BLOCK Off 0 From Autoreclose per shot settings From Cold Load Pickup LED ALARM RESET Command AND S R LATCH SETPOINTS Do Not Operate Operate OUTPUT RELAYS SETPOINTS INPUT Phasor RMS Configurable Ntrl TOC 1 PKP FLEXLOGIC OPERANDS Ntrl TOC 1 OP FLEXLOGIC OPERANDS DIRECTION Direction from Neutral Directional OC element Se...

Page 300: ...currents are injected into the relay single phase injection Iop 0 9375 I_injected three phase pure zero sequence injection Iop 3 I_injected The settings of this function are applied to the neutral current to produce Pickup and Trip flags The Neutral IOC Pickup flag is asserted when the neutral current is above the PKP value The Neutral IOC Operate flag is asserted if the element stays picked up fo...

Page 301: ... PROTECTION SYSTEM INSTRUCTION MANUAL 4 173 BLOCK Range Off Any FlexLogic operand Default Off OUTPUT RELAY X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Range Self reset Latched Disabled Default Self reset ...

Page 302: ...IOC source AND AND SETPOINT FUNCTION Disabled 0 Trip Alarm Latched Alarm PICKUP DELAY SETPOINTS t PKP From Autoreclose per shot settings LED ALARM RESET Command AND S R LATCH LED PICKUP SETPOINTS Do Not Operate Operate OUTPUT RELAYS DIRECTION Phasor DROPOUT DELAY t RST Configurable Ntrl IOC 1 PKP FLEXLOGIC OPERANDS Ntrl IOC 1 OP FLEXLOGIC OPERANDS Set Dominant Direction from Neutral Directional OC...

Page 303: ...lts The positive sequence restraint must be considered when testing for Pickup accuracy and response time multiple of Pickup The operating quantity depends on the way the test currents are injected into the relay single phase injection Iop 1 K Iinjected three phase pure zero sequence injection Iop 3 Iinjected The positive sequence restraint is removed for low currents If the positive sequence curr...

Page 304: ... used for the tripping direction The reverse looking function is designed to be faster as compared to the forward looking function and should be used for the blocking direction This allows better protection coordination The above bias should be taken into account when using the Neutral Directional Overcurrent element to directionalize other protection elements NOTE NOTE For 845 relays ordered with...

Page 305: ... signal If the polarizing signal is not valid neither forward nor reverse indication is given For a choice of current polarizing it is recommended that the polarizing signal be analyzed to ensure that a known direction is maintained irrespective of the fault location For example if using an autotransformer neutral current as a polarizing source it should be ensured that a reversal of the ground cu...

Page 306: ...he overcurrent unit of the element in the forward direction When selecting this setting it must be kept in mind that the design uses a positive sequence restraint technique for the Calculated 3I0 mode of operation REVERSE LIMIT ANGLE Range 40 to 90 in steps of 1 Default 90 This setting defines a symmetrical in both directions from the ECA limit angle for the reverse direction REVERSE PICKUP Range ...

Page 307: ...r OC FWD Ntrl Dir OC REV Disabled 0 Measured VX Voltage Calculated V _0 Current Ground Crt Ig Zero Seq Crt I_0 Dual NOTE 1 CURRENT POLARIZING IS POSSIBLE ONLY IN RELAYS WITH THE GROUND CURRENT INPUTS CONNECTED TO AN ADEQUATE CURRENT POLARIZING SOURCE 2 POSITIVE SEQUENCE RESTRAINT IS NOT APPLIED WHEN I_ 1 IS BELOW 0 8 x CT Off 0 Enabled 1 AND AND AND AND AND AND AND OR OR OR OR Ig 0 05xCT 3 I_0 K I...

Page 308: ... Definite Time is selected the time for Ground TOC operation is defined only by the TDM setting FUNCTION Range Disabled Trip Alarm Latched Alarm Configurable Default Disabled INPUT Range Phasor RMS Default Phasor PICKUP Range 0 050 to 30 000 x CT in steps of 0 001 x CT Default 1 000 x CT CURVE Range IEEE Extremely Very Moderately Inverse ANSI Extremely Very Normally Moderately Inverse Definite tim...

Page 309: ... Latched Alarm AND RESET Ground current Ig From Ground CT SETPOINTS BLOCK Off 0 From Autoreclose per shot settings From Cold Load Pickup LED ALARM RESET Command AND S R LATCH SETPOINTS Do Not Operate Operate OUTPUT RELAYS SETPOINTS INPUT Phasor RMS Configurable Ground TOC1 PKP FLEXLOGIC OPERANDS Ground TOC1 OP FLEXLOGIC OPERANDS DIRECTION Direction from Ground Directional OC element Set Dominant F...

Page 310: ...he Pickup and Operate flags will be asserted at the same time The element drops from Pickup without operation if the Ground current drops below 97 to 98 of the Pickup value Path Setpoints Protection Group 1 6 Current Ground IOC 1 X FUNCTION Range Disabled Trip Alarm Latched Alarm Configurable Default Disabled PICKUP Range 0 050 to 30 000 x CT in steps of 0 001 x CT Default 1 00 x CT DIRECTION Rang...

Page 311: ...Cold Load Pickup From Ground CT AND AND SETPOINT FUNCTION Disabled 0 Trip Alarm Latched Alarm PICKUP DELAY SETPOINTS t PKP From Autoreclose per shot settings LED ALARM RESET Command AND S R LATCH LED PICKUP SETPOINTS Do Not Operate Operate RELAYS DIRECTION DROPOUT DELAY t RST Configurable Ground IOC 1 PKP FLEXLOGIC OPERANDS Ground IOC 1 OP FLEXLOGIC OPERANDS Set Dominant Direction from Ground Dire...

Page 312: ...s the usage of the voltage polarized directional unit of the element by showing the voltage polarized phase angle comparator characteristics for a phase A to ground fault with ECA 90 element characteristic angle centerline of operating characteristic FWD LA 80 forward limit angle the angular limit with the ECA for operation REV LA 80 reverse limit angle the angular limit with the ECA for operation...

Page 313: ...sured VX Default Calculated V0 Selects the polarizing voltage used by the directional unit when Voltage or Dual polarizing mode is set The polarizing voltage can be programmed to be either the zero sequence voltage calculated from the phase voltages Calculated V_0 or supplied externally as an auxiliary voltage Measured VX 827805X1 CDR VAG reference VBG VCG Ig line Ig line ECA line ECA line LA LA L...

Page 314: ...ngle for the forward direction FORWARD PICKUP Range 0 050 to 30 000 x CT in steps of 0 001 x CT Default 0 050 x CT This setting defines the Pickup level for the overcurrent unit of the element in the forward direction REVERSE LIMIT ANGLE Range 40 to 90 in steps of 1 Default 90 This setting defines a symmetrical in both directions from the ECA limit angle for the reverse direction REVERSE PICKUP Ra...

Page 315: ...T GROUND FUNCTION DIR OC BLOCK GROUND LIMIT ANGLE DIR OC FWD GROUND ECA DIR OC FWD GROUND LIMIT ANGLE DIR OC REV GROUND DIR OC FWD PICKUP GROUND PICKUP DIR OC REV Gnd Dir OC FWD Gnd Dir OC REV Disabled 0 Measured VX Calculated V _ 0 Ground Current Ig Off 0 Enabled 1 AND AND AND AND AND Ig PICKUP Ig PICKUP Voltage Polarization 3V_ 0 Ig FWD FWD REV REV RUN RUN RUN 1 25 cy 1 5 cy TO GROUND TOC AND IO...

Page 316: ...nding on the position of the fault with respect to the winding neutral point The diagram below shows the dependence of the fault current on the fault distance from the neutral point Figure 4 65 Fault current with respect to distance from neutral The resultant primary current can be negligible for ground winding faults within 35 of the distance from the neutral point since the fault voltage is not ...

Page 317: ...on that may result into spurious neutral current and may jeopardize the security of the RGF 1 protection When the GROUND CURRENT SUPERVISION setting is selected as Enabled the algorithm checks if the ground current measured by the relay satisfies the selected GROUND CURRENT SUPERV LEVEL before making operation decision The ground current supervision is not active if the GROUND CURRENT SUPERVISION ...

Page 318: ...or during transformer energization Since RGF 1 protection is intended to detect small ground fault currents delayed clearance of such a fault is not a high concern On the other hand delayed RGF 1 operation due to a spurious ground differential current caused by an out of zone fault can be used as a backup for downstream protections should they fail to clear the fault GND CURR SUPERV Range Disabled...

Page 319: ... close to the winding neutral so that the winding rated load can be used as a reference in defining the RGF 1 slope setting The rated load for 4 16kV Wye winding is Irated 5MVA 4 16kV v3 693 A Slope setting 36 A 693A 100 5 1 Select 5 if the transformer is expected to run most of the time at full load If most of the time the transformer runs at lower than the nominal loads the slope setting can be ...

Page 320: ...OP SETPOINTS Do Not Operate Operate OUTPUT RELAY 3 X Source IB Source IC AND SETPOINTS RGF 1 BLOCK Off 0 Source IA Disabled OR RESET Igd Imax Igd I pickup RUN SETPOINTS RGF 1 PICKUP DELAY t PKP 0 Select highest value Imax max Ia Ib Ic Trip Operate Output Relay 1 TRIP LED TRIP AND Igd 3Io Ig Calculate 3Io SETPOINTS RGF 1 PICKUP RGF 1 SLOPE Source Ig AND SETPOINTS RGF 1 GND CURR SUPERV Disabled 0 En...

Page 321: ...element drops from Pickup without operation if the measured current drops below 97 to 98 of the pickup value before the time for operation is reached When Definite Time is selected the time for Negative Sequence TOC operation is defined only by the TDM setting Path Setpoints Protection Group 1 6 Current Negative Sequence TOC 1 X FUNCTION Range Disabled Trip Alarm Latched Alarm Configurable Default...

Page 322: ... TRIP Alarm OR OR Adjust PKP AND Latched Alarm AND RESET Negative sequence current In_2 Calculated value SETPOINTS BLOCK Off 0 From Autoreclose per shot settings From Cold Load Pickup LED ALARM RESET Command AND S R LATCH SETPOINTS Do Not Operate Operate OUTPUT RELAY 3 X Phasor Configurable Neg Seq TOC 1 PKP FLEXLOGIC OPERANDS Neg Seq TOC 1 OP FLEXLOGIC OPERANDS DIRECTION Direction from Neg Seq Di...

Page 323: ...g three phase faults The positive sequence restraint must be considered when testing for Pickup accuracy and response time multiple of Pickup The operating quantity depends on the way the test currents are injected into the relay single phase injection Iop 0 2917 I_injected three phase injection opposite rotation Iop I_injected The settings of this function are applied to the calculated negative s...

Page 324: ...4 196 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL PROTECTION CHAPTER 4 SETPOINTS EVENTS Range Enabled Disabled Default Enabled TARGETS Range Self reset Latched Disabled Default Self reset ...

Page 325: ...IOC source AND AND SETPOINT FUNCTION Disabled 0 Trip Alarm Latched Alarm PICKUP DELAY SETPOINTS t PKP From Autoreclose per shot settings LED ALARM RESET Command AND S R LATCH LED PICKUP SETPOINTS Do Not Operate Operate OUTPUT RELAYS DIRECTION Phasor DROPOUT DELAY t DP O Configurable Neg Seq IOC 1 PKP FLEXLOGIC OPERANDS Neg Seq IOC 1 OP FLEXLOGIC OPERANDS Set Dominant Direction from Neg Seq Directi...

Page 326: ...1 Level 2 Level 3 Level 4 Level 5 Setpoints Device System Inputs Outputs Protection Monitoring Control FlexLogic Data Capture Power Voltage Current Volts per Hertz Neutral OV Phase OV Neg Seq OV Auxiliary OV Data Capture Group 1 Group 2 Group 3 Group 4 Group 5 Group 6 Frequency Phase UV Transformer Percent Differential Auxiliary UV Undervoltage Curves Testing ...

Page 327: ...e The delay setting selects the minimum operating time of the phase undervoltage NOTE NOTE At 0 of Pickup the operating time equals the Undervoltage Pickup Time Delay setpoint Figure 4 72 Inverse Time Undervoltage Curves If FlexCurves are selected the operating time determined based on following equation T Flexcurve Vpkp V NOTE NOTE FlexCurve reverses the ratio of voltages The ratio of set pickup ...

Page 328: ...t drops from Pickup without operation if the measured voltage rise above 102 to 103 of the Pickup value before the time for operation is reached The minimum voltage setting selects the operating voltage below which the element is blocked a setting of 0 allows a dead source to be considered a fault condition This element may be used to give a desired time delay operating characteristic versus the a...

Page 329: ...s required for operation of the Phase UV protection function UNDERVOLTAGE CURVES Range Definite Time Inverse Time FlexCurves A B C D Default Definite Time This setting provides the selection of definite time delay or time delay inverse undervoltage curves or FlexCurves In the case of FlexCurves the voltage ratio used is reversed Refer to the equation and note regarding FlexCurves in the previous s...

Page 330: ...o Phase Delta VTs RUN RUN PICK UP DELAY UNDERVOLTAGE CURVES VA VAB PICKUP VB VBC PICKUP VC VCA PICKUP OR SETPOINTS OPERATE ANY ONE ANY TWO ALL THREE PHASES FOR OPERATION PICK UP ANY ONE ANY TWO ALL THREE SETPOINTS MINIMUM VOLTAGE VA VAB MINIMUM AND AND VB VBC MINIMUM VC VCA MINIMUM AND Phase UV1 OP C Phase UV1 OP B Phase UV1 OP A MODE Phase A voltage VA Phase B voltage VB Phase C voltage VC Phase ...

Page 331: ...nimum voltage setting selects the operating voltage below which the element is blocked a setting of 0 will allow a dead source to be considered a fault condition This element may be used to give a desired time delay operating characteristic versus the applied voltage or as a definite time element For the inverse time setpoint the undervoltage delay setpoint defines a family of curves as described ...

Page 332: ...CTION MANUAL PROTECTION CHAPTER 4 SETPOINTS BLOCK Range Off Any FlexLogic operand Default Off OUTPUT RELAY X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Range Disabled Self reset Latched Default Self reset ...

Page 333: ...Trip PICKUP AND Operate Output Relay 1 TRIP LED PICKUP LED TRIP Alarm OR OR AND Latched Alarm AND RUN SETPOINTS BLOCK Off 0 LED ALARM LATCHED ALARM RESET Command AND S R LATCH Configurable FlexLogic Operands Aux UV 1 2 OP Aux UV 1 2 PKP PICKUP DELAY UNDERVOLTAGE CURVES Vx PICKUP SETPOINTS MINIMUM VOLTAGE Vx MINIMUM AND SETPOINTS Do Not Operate Operate OUTPUT RELAYS 3 to 7 SETPOINTS SIGNAL INPUT NA...

Page 334: ...ow 97 to 98 of the Pickup value before the time for operation is reached Path Setpoints Protection Group 1 6 Voltage Phase OV 1 X FUNCTION Range Disabled Trip Alarm Latched Alarm Configurable Default Disabled MODE Range Phase to Ground Phase to Phase Default Phase to Ground This setting provides the selection of phase to ground and phase to phase voltages for a Wye VT connection phase to phase for...

Page 335: ...ROTECTION 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 207 OUTPUT RELAY X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Range Disabled Self reset Latched Default Self reset ...

Page 336: ...OV 1 OP B Phase OV 1 OP A Phase OV 1 PKP Phase OV 1 OP C Phase OV 1 OP B Phase OV 1 OP A SETPOINTS MODE Phase to Ground Phase to Phase for wye connection Phase to Phase Delta connection Ph Ph AB voltage VAB Ph Ph BC voltage VBC Ph Ph CA voltage VCA Phase to Phase Voltages Delta connection VB VBC PICKUP RUN VC VCA PICKUP RUN SETPOINTS PICKUP DELAY DROPOUT DELAY t PKP t RST t PKP t RST t PKP t RST S...

Page 337: ...flags The Auxiliary OV pickup flag is asserted when the voltage on auxiliary input is above the PKP value The Auxiliary OV trip flag is asserted if the element stays picked up for the time defined by pickup time delay Inverse Time or FlexCurves The element drops from pickup without operation if the measured voltage drops below 97 98 of the pickup value before the time for operation is reached This...

Page 338: ...xample a Pickup setting of 1 10 x VT with 13800 115 VT translates into 15 08kV or 126 5V secondary PICKUP DELAY Range 0 000 6000 000s in steps of 0 001s Default 1 000s DROPOUT DELAY Range 0 000 to 6000 000 s in steps of 0 001 s Default 1 000 s BLOCK Range Off Any FlexLogic operand Default Off OUTPUT RELAY X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Rang...

Page 339: ...ed Trip PICKUP AND Operate Output Relay 1 TRIP LED TRIP Alarm OR OR Auxiliary voltage AND Latched Alarm AND Vx PICKUP RUN SETPOINTS BLOCK Off 0 LED ALARM LATCHED ALARM RESET Command AND S R LATCH Configurable FlexLogic Operands Aux OV OP Aux OV PKP PICK UP DELAY DROP OUT DELAY LED PICKUP SETPOINTS Do Not Operate Operate OUTPUT RELAYS 3 to 7 SETPOINTS SIGNAL INPUT NAME Ax VT Bnk1 J2 889 Overvoltage...

Page 340: ...tion It would normally be applied to give line to ground fault coverage on high impedance grounded or ungrounded systems which are isolated This constraint stems from the fact that a measurement of 3V_0 cannot discriminate between a faulted circuit and an adjacent healthy circuit Use of a time delayed back up or alarm mode allows other protections an opportunity to isolate the faulted element firs...

Page 341: ... PROTECTION SYSTEM INSTRUCTION MANUAL 4 213 BLOCK Range Off Any FlexLogic operand Default Off OUTPUT RELAY X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Range Disabled Self reset Latched Default Self reset ...

Page 342: ... Latched Alarm AND SETPOINTS BLOCK Off 0 LED ALARM LATCHED ALARM RESET Command AND S R LATCH Configurable FlexLogic Operands Neutral OV 1 OP Neutral OV 1 PKP SETPOINTS PICK UP DELAY DROP OUT DELAY t PKP t RST Van 0 85 x VT Vbn 0 85 x VT Vcn 0 85 x VT OR 3_Vo PICKUP RUN CURVE SETPOINTS Do Not Operate Operate OUTPUT RELAYS 3 to 7 Phase A Voltage Va Phase B Voltage Vb Phase C Voltage Vc Phase Voltage...

Page 343: ...ked up for the time defined by Pickup time delay The element drops from Pickup without operation if the calculated Negative Sequence Voltage drops below 97 to 98 of the Pickup value before the time for operation is reached Path Setpoints Protection Group 1 6 Voltage Neg Seq OV 1 X FUNCTION Range Disabled Trip Alarm Latched Alarm Configurable Default Disabled PICKUP Range 0 00 to 3 00 x VT in steps...

Page 344: ... PICKUP LED TRIP Alarm OR OR AND Latched Alarm AND SETPOINTS BLOCK Off 0 LED ALARM LATCHED ALARM RESET Command AND S R LATCH Configurable FlexLogic Operands Neg Seq OV 1 OP Neg Seq OV 1 PKP SETPOINTS PICK UP DELAY DROP OUT DELAY t PKP t RST V_2 PICKUP RUN SETPOINTS Do Not Operate Operate OUTPUT RELAYS 3 to 7 SETPOINTS Signal Input Ph VT Bank 1 J2 Phase A Voltage Va Phase B Voltage Vb Phase C Volta...

Page 345: ...the pickup setting we use the base V Hz unit 120 60 2 such that the pickup setting value is 2 1 2 1 05 x V Hz 2 When the auxiliary voltage Vx is used regarding the condition for None phase voltage setting mentioned above then the 1 pu value is the Setpoint System Voltage Sensing Ph VT Bnk1 J2 Voltage 1 J2 Aux VT Secondary setting divided by the Setpoint System Power System Nominal Frequency settin...

Page 346: ...f the Voltage Mode selection PICKUP Range 0 80 to 4 00 V Hz in steps of 0 01 Default 1 05 V Hz Enter the Volts per Hertz value in V Hz above which the Volts per Hertz 1 element will pickup CURVE Range Definite Time Inverse A Inverse B Inverse C FlexCurve A FlexCurve B FlexCurve C FlexCurve D Default Definite Time Definite Time For the definite time curve T s TD multiplier For example setting the T...

Page 347: ... Curve B The curve for the Volts Hertz Inverse Curve B shape is derived from the formula where T Operating Time TDM Time Delay Multiplier delay in seconds V fundamental RMS value of voltage pu F frequency of voltage signal pu Pickup volts per hertz pickup setpoint pu The Volts Hertz inverse B curves are shown below Pickup F V when Pickup V TDM T º ª 1 ...

Page 348: ...lts Hertz Inverse Curve C shape is derived from the formula where T Operating Time TDM Time Delay Multiplier delay in seconds V fundamental RMS value of voltage pu F frequency of voltage signal pu Pickup volts per hertz pickup setpoint pu The Volts Hertz Inverse C curves are shown below Figure 4 82 Volts Per Hertz Curves for Inverse Curve C Pickup F V when Pickup V TDM T º ª 1 2 1 ...

Page 349: ...etting the TD multiplier to 20 results in a time delay of 20 seconds to operate when above the Volts Hz pickup setting T RESET Range 0 00 to 6000 00 in steps of 0 01 Default 1 00 Enter the time that the Volts per Hertz value must remain below the pickup level before the element resets BLOCK Range Off FlexLogic Operand Default Off The Volts per Hertz can be blocked by any asserted FlexLogic operand...

Page 350: ... V Hz SETPOINTS Configurable FUNCTION Disabled 0 Trip Alarm Latched Alarm OR AND AND AND Operate Output Relay 1 TRIP LED TRIP OR LED ALARM LATCH S R RESET Command FLEXLOGIC OPERAND SETPOINT Relays Do Not Operate Operate SIGNAL INPUT SETPOINT Phase Voltage Inputs from Ph VT Bnk1 J2 MAX WYE Delta Van Vbn Vcn Vab Vbc Vca Auxiliary Voltage Inputs from Aux VT Bnk1 J2 Ph VT Bnk1 J2 Aux VT Bnk1 J2 J2 3VT...

Page 351: ... the latter case the two wattmeter method is used The element has an adjustable characteristic angle and minimum operating power as shown in the Directional Power characteristic diagram The element responds to the following condition Where P and Q are active and reactive powers as measured per the metering convention Ɵ is a sum of the element characteristic DIR POWER 1 RCA and calibration DIR POWE...

Page 352: ...the characteristic angle adjustable and providing for both negative and positive values of the minimum operating power a variety of operating characteristics can be achieved as presented in the figure below For example section a in the figure below shows settings for reverse power while section b shows settings for low forward power applications ...

Page 353: ...CHAPTER 4 SETPOINTS PROTECTION 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 225 Figure 4 86 Sample applications of the Directional Power element ...

Page 354: ...d to permit more sensitive settings The setting virtually enables calibration of the Directional Power function in terms of the angular error of applied VTs and CTs The element responds to the sum of the DIR POWER 1 RCA and DIR POWER 1 CALIBRATION settings STAGE 1 SMIN Range 1 200 to 1 200 x Rated Power in steps of 0 001 x Rated Power Default 0 100 x Rated Power The setting specifies the minimum p...

Page 355: ...Power The setting specifies the minimum power as defined along the relay characteristic angle RCA for stage 2 of the element The setting needs to be coordinated with the setting of stage 1 STAGE 2 DELAY Range 0 000 to 6000 000 s in steps of 0 001 s Default 20 000 s The setting specifies a time delay for stage 2 For reverse power or low forward power applications for a synchronous machine stage 1 i...

Page 356: ...SETPOINTS DIR POWER 1 RCA DIRECTIONAL POWER CHARACTERISTICS SETPOINTS DIR POWER 1 STAGE 1 DELAY t PKP 100 ms FlexLogic Operands DirPwr 1 Stg2 PKP AND AND AND Command RESET OR LED ALARM LED TRIP Operate Output Relay 1 TRIP RUN SETPOINTS RELAYS Do Not Operate Operate DIR POWER 1 CALIBRATION DIR POWER 1 STAGE 1 SMIN DIR POWER 1 STAGE 2 SMIN SETPOINTS DIR POWER 1 STAGE 2 DELAY t PKP 100 ms DirPwr 1 St...

Page 357: ...e three phase to phase voltages from delta connected VTs PTs three phase to ground voltages from wye connected VTs PTs or single phase auxiliary voltage The input currents are the three phase currents The Underfrequency Pickup flag is asserted when the measured frequency of the specified source is below the PKP value and the voltage and current are above the MINIMUM levels The Underfrequency Trip ...

Page 358: ...and SIGNAL INPUT is set to Ph VT Bnk1 J2 the positive sequence voltage is used as the supervision voltage In such condition the true supervision level is internally changed to 1 sqrt 3 of the user setting since the base of VT here is the phase phase voltage MINIMUM CURRENT Range 0 000 to 30 000 x CT in steps of 0 001 x CT Default 0 200 x CT The setting sets the minimum value of current required on...

Page 359: ...TPOINTS UNDERFREQ 1 MINIMUM CURRENT I MINIMUM SETPOINTS UNDERFREQ 1 MINIMUM VOLTAGE AND SETPOINTS UNDERFREQ 1 PICKUP 0 f PICKUP FREQUENCY f RUN SETPOINTS UNDERFREQ 1 PICKUP DELAY t PKP t DPO UNDERFREQ 1 DROPOUT DELAY Underfreq 1 OP FlexLogic Operands Underfreq 1 PKP AND AND AND Command RESET OR LED ALARM LED TRIP Operate Output Relay 1 TRIP WYE DELTA VA VAB VB VBC VC VCA Vx RUN V MINIMUM RUN SETPO...

Page 360: ...h no time delay or as a definite time delayed element The Overfrequency element has a fixed minimum operating threshold to prevent undesired operation during periods of unavailable voltage The input voltages are the three phase to phase voltages from delta connected VTs PTs three phase to ground voltages from wye connected VTs PTs or single phase auxiliary voltage The settings of this function are...

Page 361: ...ence voltage is used as the supervision voltage In such condition the true supervision level is internally changed to 1 sqrt 3 of the user setting since the base of VT here is the phase phase voltage BLOCK Range Off Any FlexLogic operand Default Off OUTPUT RELAY X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Range Disabled Self reset Latched Default Self r...

Page 362: ...ne SETPOINTS OVERFREQ 1 PICKUP f PICKUP RUN SETPOINTS OVERFREQ 1 PICKUP DELAY t PKP t DPO OVERFREQ 1 DROPOUT DELAY Overfreq1 OP FlexLogic Operands Overfreq1 PKP AND AND Command RESET OR LED ALARM SETPOINTS OVERFREQ 1 MINIMUM OPERATING VOLTAGE V MINIMUM FREQUENCY f RUN SETPOINTS OUTPUT RELAYS 3 Do Not Operate Operate S LATCH Set Dominant R Trip AND LED TRIP Operate Output Relay 1 TRIP WYE DELTA VA ...

Page 363: ... is blocked The minimum and maximum frequencies set the operating frequency range out of which the element is blocked Path Setpoints Protection Group 1 6 Frequency Frequency Rate of Change 1 X FUNCTION Range Disabled Trip Alarm Latched Alarm Configurable Default Disabled The selection of the Trip Alarm Latched Alarm or Configurable setting enables the element When the Trip function is selected and...

Page 364: ...t to the required frequency level MAXIMUM FREQUENCY Range 20 00 to 80 00 Hz in steps of 0 01 Hz Default 65 00 Hz The setting defines the maximum frequency level required for operation of the element The setting may be used to effectively block the feature based on frequency For example if the intent is to monitor a decreasing trend but only if the frequency is already below a certain level such as...

Page 365: ...led Default Enabled The selection of the Enabled setting enables the events of the function TARGETS Range Disabled Self reset Latched Default Self reset This setting is used to define the operation of an element target message When set to Disabled no target message is issued upon operation of the element When set to Self Reset the target message and its LED indication follow the operate state of t...

Page 366: ...INTS FREQ RATE PICKUP DELAY t PKP 0 FreqRate1 OP FlexLogic Operands FreqRate1 Up PKP AND AND AND Command RESET OR LED ALARM LED TRIP Operate Output Relay 1 TRIP RATE OF CHANGE df dt SETPOINTS FREQ RATE TREND Decreasing Increasing Bi directional SETPOINTS FREQ RATE MIN FREQUENCY FREQ RATE MAX FREQUENCY AND AND SETPOINTS FREQ RATE PICKUP df dt PICKUP RUN SETPOINTS FREQ RATE PICKUP DELAY t PKP 0 OR F...

Page 367: ... the load capability of the installed transformer under the non sinusoidal load currents Once harmonics are present the derating factor will decrease from the ideal value of one per unit which means the load capability is reduced due to harmonics The Load Limit Reduced LED indicator is ON and an operand of Load Limit Reduced is asserted if the HDF of any winding is less than 0 96 regardless of whe...

Page 368: ...CT in steps of 0 01 x CT Default 0 10 x CT This setting sets the minimum value for all three phase currents to allow the Harmonic Derating element to operate PICKUP Range 0 01 to 0 98 in steps of 0 01 Default 0 90 PICKUP DELAY Range 0 to 60000 s in steps of 1 s Default 10 s BLOCK Range Any flexoperand Default Off OUTPUT RELAY X Range Do Not Operate Operate Default Do Not Operate EVENTS Range Enabl...

Page 369: ...URRENT IA MINIMUM RUN S LATCH Set Dominant R Phase A Current IA Phase B Current IB Phase C Current IC Phase A Harmonics Phase B Harmonics Phase C Harmonics IB MINIMUM IC MINIMUM SETPOINT OUTPUT RELAY X Do Not Operate Operate W1 Current Harmonics W1 Current Input Calculate Harmonic Derating Factor W1_HDF AND Phase A Harmonics Phase B Harmonics Phase C Harmonics W2 Current Harmonics Calculate Harmon...

Page 370: ...omputation of Hottest Spot winding temperature Aging Factor and Transformer Loss of Life Refer to SETPOINTS SYSTEM TRANSFORMER WINDING 1 2 3 and enter the windings data used to compute the transformer loading The transformer winding settings are used for calculation of the winding nominal current and the load loss at rated load The ratio of the actual load to the rated load K is used in the Hottes...

Page 371: ...elay and be included in the calculation for hottest spot winding temperature Winding Currents CT Bank 1 J1 Ambient Temperature Monthly Average January 20 C February 20 C March 20 C April 7 C May 15 C June 25 C July 30 C August 30 C September 20 C October 17 C November 14 C December 9 C Top Oil Temperature Computed System Transformer Thermal Inputs Setpoints Value Unit Status Tap Chan Thermal Funct...

Page 372: ...d for operation of the element This setting must be defined based on the maximum permissible hottest spot temperature under emergency transformer loading conditions and the maximum ambient temperature PICKUP DELAY Range 0 to 60000 min in steps of 1 min Default 1 min This setting is used to select a pickup time delay that is used to delay the operation of the protection OUTPUT RELAY 1 X Range Do No...

Page 373: ...rm Latched Alarm Configurable OR AND AND Command RESET OR LED ALARM S LATCH Set Dominant R SETPOINTS Block Off 0 AND SETPOINTS Pickup t C PKP Pickup Delay RUN SETPOINTS pkp t FLEXLOGIC OPERANDS Hottest Spot PKP Hottest Spot OP SETPOINT OUTPUT RELAY1 X excluding trip selected output relays Do Not Operate Operate METERING Hottest Spot t ...

Page 374: ...the maximum permissible aging factor under emergency loading conditions and maximum ambient temperature PICKUP DELAY Range 0 to 60000 min in steps of 1 min Default 10 min This setting is used to select a pickup time delay that is used to delay the operation of the protection OUTPUT RELAY 1 X Range Do Not Operate Operate Default Do Not Operate The menu includes a list of available output relays to ...

Page 375: ...m Latched Alarm Configurable OR AND AND Command RESET OR LED ALARM S LATCH Set Dominant R SETPOINTS Block Off 0 AND SETPOINTS Pickup FAA PKP Pickup Delay RUN SETPOINTS pkp t FLEXLOGIC OPERANDS Aging Factor PKP Aging Factor OP SETPOINT OUTPUT RELAY1 X excluding trip selected output relays Do Not Operate Operate METERING Aging Factor FAA ...

Page 376: ...r life in hours When the LOL element is enabled the loss of life computed by the relay is added to the initial loss of life in hours PICKUP Range 0 to 500000 hours in steps of 1 hr Default 200000 hours Enter the expected life in hours required for operation of the element This setting must be above the total transformer life set as a reference based on nominal loading conditions and 30º C ambient ...

Page 377: ...Disabled Alarm Latched Alarm Configurable OR AND AND Command RESET OR LED ALARM S LATCH Set Dominant R SETPOINTS Block Off 0 AND SETPOINTS Pickup LOL PKP RUN FLEXLOGIC OPERANDS Xfmr Loss Life PKP Xfmr Loss Life OP SETPOINT OUTPUT RELAY 1 X excluding trip selected output relays Do Not Operate Operate METERING Xfmr Life Lost ...

Page 378: ...g to at least one tap step and the selected Ohms or DCmA values must be smaller than the highest Ohm or DCmA measured value by a value corresponding to at least one tap step If the Tap position is used for compensation of the differential current due to the new transformation ratio and the tap position is detected below the Minimum or above the Maximum tap the relay may show small differential cur...

Page 379: ...on AND Alarm OR OR AND Latched Alarm AND SETPOINT BLOCK Off 0 TC Position Max Tap Position SETPOINT t PKP LED ALARM RESET Command S R LATCH Configurable SETPOINTS OUTPUT RELAYS Do Not Operate Operate 0 DELAY Set Dominant Tap Ch Fail PKP FlexLogic Operands Tap Ch Fail OP FlexLogic Operands ACTUAL VALUE LED PICKUP Metering Transformer Tap Changer Position System Transformer Onload Tap Changer RUN Mi...

Page 380: ...ose coil monitoring The monitor contains a level detector whose output is set to logic 1 ON when the voltage is above 20 volts The voltage monitor is used to check the health of the overall trip and closing circuit The two figures below show the two different connections of the breaker trip and close coils to the relay s trip and close output relays for either no voltage monitoring and for voltage...

Page 381: ...rip coil or and Close coil continuously regardless of the breaker position open or closed This can be achieved by connecting a suitable resistor see the table Value of Resistor R across the breaker auxiliary contact s 52a in the trip circuit across 52b contact s for Close coil With such connections the trickle current is maintained by the resistor For these applications the setting for the Bypass ...

Page 382: ...1 COM FA_1 NO FA_1 OPT V External Jumper R Bypass resistor V DC DC Output Relay 1 TRIP 52a contact Trip Coil FA_1 COM FA_1 NO FA_1 OPT V External Jumper R Bypass resistor 52a contact R Bypass resistor V DC DC Output Relay 2 CLOSE 52b contact Close Coil FA_2 COM FA_2 NO FA_2 OPT V External Jumper R Bypass resistor V DC DC Output Relay 2 CLOSE 52b contact Close Coil FA_2 COM FA_2 NO FA_2 OPT V Exter...

Page 383: ...Set the Bypass Breaker State to Enabled when a by pass resistor is connected across the breaker auxiliary contact for continuous Trip circuit monitoring The circuits are monitored regardless of breaker position BREAKER STATE CLOSED Range Off Any FlexLogic operand Contact inputs Virtual inputs Remote inputs Default Off This setpoint selects the FlexLogic operand digital input virtual input or remot...

Page 384: ... ALARM RESET Command AND S R LATCH 1 Set Dominant Configurable FlexLogic Operand Trip Coil Mon 1 OP SETPOINTS Do Not Operate Operate OUTPUT RELAY 3 X SETPOINT TCM BLOCK Off 0 AND SETPOINT TCM PICK UP DELAY SETPOINT TCM BYPASS BKR STATE Disabled 0 FlexLogic Operand Trip Coil 1 Mon PKP OR t PKP t RST TCM DROP OUT DELAY SETPOINT TCM BKR STATUS CLOSED Off 0 AND OUTPUT RLY 1 TRIP OPERATE OUTPUT RLY 1 M...

Page 385: ...pass resistor is connected across the breaker auxiliary contact for continuous Close circuit monitoring The circuits are monitored regardless of breaker position BREAKER STATE OPENED Range Off Any FlexLogic operand Contact inputs Virtual inputs Remote inputs Default Off The setpoint selects the FlexLogic operand digital input virtual input or remote input to indicate that circuit breaker is opened...

Page 386: ...ommand AND S R LATCH 1 Set Dominant Configurable FlexLogic Operand Close Coil Mon 1 OP SETPOINTS Do Not Operate Operate OUTPUT RELAY 3 X SETPOINT CCM BLOCK Off 0 AND SETPOINT CCM PICK UP DELAY SETPOINT CCM BYPASS BKR STATE Disabled 0 FlexLogic Operand Close Coil Mon 1 PKP OR t PKP t RST CCM DROP OUT DELAY SETPOINT CCM BKR STATUS OPENED Off 0 AND OUTPUT RLY 2 MONITORING VOLTAGE THRESHOLD OUTPUT RLY...

Page 387: ...arted This interval includes the operating time of the output relay any other auxiliary relays and the breaker mechanism For maximum measurement accuracy the interval between the change of state of the operand from 0 to 1 and contact separation should be measured for the specific installation Integration of the measured current continues for 100 ms which is expected to include the total arcing per...

Page 388: ...teps of 1 kA2 c Default 1000 kA2 c The setpoint specifies the threshold value kA2 cycle above which the output operand is set BLOCK Range Off Any FlexLogic operand Default Off OUTPUT RELAYS X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Range Self reset Latched Disabled Default Self reset ...

Page 389: ...te Operate OUTPUT RELAY 3 X CT Bank current IB CT Bank current IC AND SETPOINTS BKR 1 ARCING BLOCK Off 0 CT Bank current IA Disabled AND COMMAND CLEAR BKR 1 ARCING CURRENT YES 1 OR RESET IA t Integrate IB t Integrate IC t Integrate RUN RUN RUN SETPOINTS BKR 1 ARCING DELAY t delay 0 BKR 1 ARCING INITIATION Off 0 SETPOINTS OR 100ms 0 IA cycle IB cycle IC cycle Add to accumulator Set all to 0 Select ...

Page 390: ...val after the programmed delay A breaker operation function is also included where breaker operation failure is caused by either of the following conditions The breaker does not respond to a Trip command within the programmed breaker operation delay time The breaker does not respond to a Close command within the programmed time Path Setpoints Monitoring Breaker 1 Breaker Health FUNCTION Range Disa...

Page 391: ...efault 0 050 s The setting sets the Pickup level of the Close time The Close time interval is initiated by the CLOSE TRIGGER signal and stopped by the CLOSE STATUS signal INCOMPLETE TRP CLS TIME Range 0 000 to 6000 000 s in steps of 0 001 s Default 0 100 s The setting declares a breaker operation failure condition if the breaker does not respond within this time delay The setting should be greater...

Page 392: ...Y is calculated by the breaker arcing current element If the breaker arcing current element is disabled the ACR ENERGY is not calculated and this setting should not be used The ACR ENERGY used here is the individual value for each trip and not the accumulated value recorded in the Breaker Arcing Current element ALARM COUNTER Range 1 to 100 in steps of 1 Default 5 The setting sets the alarm counter...

Page 393: ...N t_arc_C t_trip 1 cyc PKP RUN SETPOINTS BKR HEALTH CLOSE TRIGER Off 0 SETPOINTS BKR HEALTH BKR CLOSE STATUS Off 0 SETPOINTS BKR HEALTH SPRING CHARGE STATUS Off 0 t _close START STOP t _charge t_close PKP RUN SETPOINTS BKR HEALTH CLOSE TIME PICKUP t_charge PKP RUN SETPOINTS BKR HEALTH CHARGE TIME PICKUP START START START Arc Energy Inputs IA2t cycle IB2t cycle IC2 t cycle IA2 t PKP RUN SETPOINTS B...

Page 394: ...ges are above a threshold and one or more currents are above 0 002 x CT Power Factor element delay timers are only allowed to time when the voltage threshold is exceeded on all phases and the Power Factor remains outside of the region between the programmed Switch In and Switch Out levels In the same way when a Power Factor condition starts the Power Factor delay timer if all three phase voltages ...

Page 395: ...TPOINTS MONITORING 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 267 Figure 4 108 Conventions for Power Factor For example the applications of Switch In and Switch Out levels are shown in the figures below ...

Page 396: ...4 268 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL MONITORING CHAPTER 4 SETPOINTS ...

Page 397: ...hreshold below which the element is reset Path Setpoints Monitoring Functions Power Factor 1 X FUNCTION Range Disabled Alarm Latched Alarm Configurable Default Disabled SWITCH IN Range 0 01 to 0 99 1 0 99 to 0 01 For 845 PC program 0 01 Lead 0 02 Lead 0 98 Lead 0 99 Lead 1 0 99 Lag 0 98 Lag 0 02 Lag 0 01 Lag Default 0 08 Lag The setting sets the Power Factor Switch In level The negative value is u...

Page 398: ...us operation is selected by the time delay setting of 0 000 s MINIMUM VOLTAGE Range 0 00 to 1 25 x VT in steps of 0 01 x VT Default 0 30 x VT The setting sets the minimum voltage for Power Factor element operation specified per times VT BLOCK Range Off Any FlexLogic operand Default Off OUTPUT RELAY X For details see Common Setpoints EVENTS Range Enabled Disabled Default Enabled TARGETS Range Disab...

Page 399: ...hase s wye connected VTs SETPOINT POWER FACTOR 1 MINIMUM VOLTAGE VAB MINIMUM RUN IA 0 002 xCT VBC MINIMUM VCA MINIMUM IB 0 002 xCT IC 0 002 xCT AND OR SETPOINTS POWER FACTOR 1 DELAY t DLY 0 SETPOINTS POWER FACTOR 1 SWITCH IN PF SWITCH IN both PF and SWITCH IN are lag or lead RUN SETPOINTS POWER FACTOR 1 SWITCH OUT PF passing SWITCH OUT RUN SETPOINTS POWER FACTOR 1 DELAY t DLY 0 AND PF 1 Switch Out...

Page 400: ...hermal Demand equivalent based on d t D 1 e kt Where d demand value after applying input quantity for time t in minutes D input quantity constant k 2 3 thermal 90 response time Figure 4 110 Thermal Demand Characteristic 15 min response The 90 thermal response time characteristic defaults to 15 minutes A setpoint establishes the time to reach 90 of a steady state value just as with the response tim...

Page 401: ...ONSE TIME Range 5 min 10 min 15 min 20 min 30 min Default 15 min This setpoint sets the time required for a steady state current to indicate 90 of the actual value and allows the user to approximately match the response of the relay to analog instruments The setpoint is visible only if MEASUREMENT TYPE is Thermal Exponential TIME INTERVAL Range 5 min 10 min 15 min 20 min 30 min Default 20 min This...

Page 402: ...Calculate Phase A CURRENT DEMAND SETPOINTS PICKUP IA Demand PICKUP RUN Current Dmd1 PKP AND AND Command RESET OR LED ALARM THERMAL 90 RESPONSE TIME TIME INTERVAL Phase B Current IB Calculate Phase B CURRENT DEMAND Phase C Current IC Calculate Phase C CURRENT DEMAND IB Demand PICKUP RUN IC Demand PICKUP RUN OR Current Dmd1 PKP A Current Dmd1 PKP B Current Dmd1 PKP C SETPOINTS OUTPUT RELAYS Do Not O...

Page 403: ... the time required for steady state Real Power to indicate 90 of the actual value and allows the user to approximately match the response of the relay to analog instruments The setpoint is visible only if MEASUREMENT TYPE is Thermal Exponential TIME INTERVAL Range 5 min 10 min 15 min 20 min 30 min Default 20 min This setpoint sets the time period over which the Real Power Demand calculation is to ...

Page 404: ...Disabled Alarm Latched Alarm Configurable OR SETPOINTS REAL PWR DEMAND MEASUREMENT TYPE Calculate Real Power Demand SETPOINTS REAL PWR DEMAND REAL POWER PICKUP P Demand PICKUP RUN RealPwr Dmd PKP AND AND Command RESET OR LED ALARM REAL PWR DEMAND THERMAL 90 RESPONSE TIME REAL PWR DEMAND TIME INTERVAL Three Phase Real Power P SETPOINTS OUTPUT RELAYS X Do Not Operate Operate FlexLogic Operands S LAT...

Page 405: ...e required for a steady state Reactive Power to indicate 90 of the actual value and allows the user to approximately match the response of the relay to analog instruments The setpoint is visible only if MEASUREMENT TYPE is Thermal Exponential TIME INTERVAL Range 5 min 10 min 15 min 20 min 30 min Default 20 min The setpoint sets the time period over which the Reactive Power Demand calculation is to...

Page 406: ...m Latched Alarm Configurable OR SETPOINTS REACTIVE PWR DMD MEASUREMENT TYPE Calculate Reactive Power Demand SETPOINTS REACTIVE PWR DMD REACTIVE POWER PICKUP Q Demand PICKUP RUN ReactvPwr Dmd PKP AND AND Command RESET OR LED ALARM REACTIVE PWR DMD TIME INTERVAL Three Phase Reactive Power Q SETPOINTS SETPOINTS OUTPUT RELAY X Do Not Operate Operate FlexLogic Operands S LATCH Set Dominant R 89 1 cdr R...

Page 407: ...min Default 15 min The setpoint sets the time required for a steady state Apparent Power to indicate 90 of the actual value and allows the user to approximately match the response of the relay to analog instruments The setpoint is visible only if MEASUREMENT TYPE is Thermal Exponential TIME INTERVAL Range 5 min 10 min 15 min 20 min 30 min Default 20 min The setpoint sets the time period over which...

Page 408: ... Latched Alarm Configurable OR SETPOINTS APPARENT PWR DMD MEASUREMENT TYPE Calculate Apparent Power Demand SETPOINTS APPARENT PWR DMD APPARENT POWER PICKUP S Demand PICKUP RUN ApprntPwr Dmd PKP AND AND Command RESET OR LED ALARM APPARENT PWR DMD THERMAL 90 RESPONSE TIME APPARENT PWR DMD TIME INTERVAL Three Phase Apparent Power S SETPOINTS SETPOINTS OUTPUT RELAY X Do Not Operate Operate FlexLogic O...

Page 409: ...antities are displayed in MWh and MVarh with resolutions of 1 kWh and 1 kVarh respectively Path Setpoints Monitoring Functions Pulsed Outputs FUNCTION Range Disabled Enabled Default Disabled POS WHS PULSE INCREMENT Range 0 000 to 1000 000 MWh in steps of 0 001 MWh Default 10 000 MWh The setpoint specifies the positive Watthours threshold pulse increment after which the output pulse and output oper...

Page 410: ...4 282 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL MONITORING CHAPTER 4 SETPOINTS EVENTS Range Disabled Enabled Default Enabled TARGETS Range Disabled Self reset Latched Default Self Reset ...

Page 411: ...UN MWh REAL ENERGY NEGATIVE Wh ACTUAL VALUE SETPOINT NEG WHS PULSE INCREMENT STORING Wh AT PULSE Do Not Operate Operate RUN FlexLogic Operands Pos Varh Pulse OP SETPOINTS OUTPUT RELAYS X MVARh MVARhprev PMVARhP value MVARhprev RUN MVARh REACTIVE ENERGY POSITIVE VARh ACTUAL VALUE SETPOINT POS VARHS PULSE INCREMENT STORING VARh AT PULSE Do Not Operate Operate RUN FlexLogic Operands Neg Varh Pulse OP...

Page 412: ...set value before counting operations begin as in the case where a substitute relay is installed in place of an in service relay or while the Counter is running COMPARE Range 2147483648 0 2147483647 Default 0 The setpoint sets the value to which the accumulated count value is compared Three FlexLogic output operands are provided to indicate if the present value is more than HI equal to EQL or less ...

Page 413: ...nd for freezing capturing the accumulating count value into a separate register with the associated date and time of the operation while resetting the count to either 0 or the pre set value depending on the state of the Counter 1 Set to Pre set operand FREEZE COUNT Range Off Any FlexLogic operand Default Off The setpoint selects the FlexLogic operand for freezing capturing the accumulating count v...

Page 414: ...ETPOINT DGTL CNTR 1 RESET OFF 0 SETPOINT DGTL CNTR 1 FREEZE RESET OFF 0 SETPOINT DGTL CNTR 1 FREEZE COUNT OFF 0 OR OR AND AND SET TO PRE SET VALUE SET TO 0 RUN STORE DATE AND TIME SETPOINT DGTL CNTR 1 COMPARE COUNT COMPARE COUNT COMPARE DGTL CNTR 1 NAME DGTL CNTR 1 UNITS COUNT COMPARE FlexLogic Operand COUNTER 1 LOW SETPOINTS Do Not Operate Operate FlexLogic Operand COUNTER 1 HI SETPOINTS Do Not O...

Page 415: ...e updated every protection pass The THD is updated every three cycles which is not recommended as a blocking signal Path Setpoints Monitoring Harmonic Detection Harmonic Detection 1 X FUNCTION Range Disabled Alarm Latched Alarm Configurable Default Disabled HARMONIC Range 2nd 3rd 4th 5th THD Default 2nd This setting selects the specified harmonic or THD to be monitored The harmonic or THD is expre...

Page 416: ...ange 0 03 to 1 00 x CT in steps of 0 01 Default 0 10 x CT This setting sets the minimum value of current required to allow the Harmonic Detection element to operate If PHASES FOR OPERATION is set to AVERAGE the average of three phase currents is used for supervision A similar adaptive average algorithm is applied to calculate the average of operation current magnitude OUTPUT RELAY X For details se...

Page 417: ...CURRENT IA MINIMUM RUN S LATCH Set Dominant R Phase A Current IA Phase B Current IB Phase C Current IC Phase A Harmonics Phase B Harmonics Phase C Harmonics IB MINIMUM IC MINIMUM SETPOINT OUTPUT RELAY X Do Not Operate Operate W1 Current Harmonics W1 Current Input Calculate Harmonic Derating Factor W1_HDF AND Phase A Harmonics Phase B Harmonics Phase C Harmonics W2 Current Harmonics Calculate Harmo...

Page 418: ... DCmA inputs and seven DCmA outputs Additionally the relay can be furnished with up to two optional RTD cards each of them having 6 RTD input channels Only slots B and C can accept the optional RTD cards NOTE NOTE If only one RTD card is ordered at the time the relay is ordered this RTD card is always shown in slot B The order code selection does not allow for an RTD card in slot C if no RTD card ...

Page 419: ... RTD trip and alarm functions if the RTD connection is detected as Open or Shorted and generates RTD Open and RTD Shorted FlexLogic operands An RTD is detected as Open when the RTD TEMPERATURE RESISTANCE IN OHMS C F 100 Ω PT IEC 60751 120 Ω NI 100 Ω NI 10 Ω CU 40 40 84 27 92 76 77 30 7 49 30 22 88 22 99 41 82 84 7 88 20 4 92 16 106 15 88 45 8 26 10 14 96 09 113 00 94 17 8 65 0 32 100 00 120 00 100...

Page 420: ... NAME Range Up to 13 alphanumeric characters Default RTD 1 TYPE Range 100 Ω Platinum 100 Ω Nickel 120 Ω Nickel Default 100 Ω Platinum Selects the type of the RTD used TRIP TEMPERATURE Range 1 C to 250 C in steps of 1 C 33 F to 482 F in steps of 2 F Default 155 C 311 F TRIP PICKUP DELAY Range 0 s to 600 s in steps of 1 s Default 2 s TRIP DROPOUT DELAY Range 0 s to 600 s in steps of 1s Default 0 s T...

Page 421: ...CHAPTER 4 SETPOINTS MONITORING 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 4 293 EVENTS Range Disabled Enabled Default Enabled TARGETS Range Disabled Self reset Latched Default Latched ...

Page 422: ...Command RTD 1 Trip PKP FLEXLOGIC OPERANDS RTD 1 Trip OP RTD 1 Alarm PKP FLEXLOGIC OPERANDS RTD 1 Alarm OP SETPOINT Trip Output Relay X Do Not Operate Operate SETPOINT Alarm Output Relay X Do Not Operate Operate OR tº Trip Temperature RUN Alarm Temperature SETPOINT Tº Alarm Temperature Resistance Temperature Convertion Name RTD 1 Type SETPOINT SETPOINT AND RUN RUN R 250 C R 40 C Temperature Display...

Page 423: ...nts Monitoring RTD Trouble FUNCTION Range Disabled Alarm Latched Alarm Default Disabled ALARM OUTPUT RELAY X For details see Common Setpoints EVENTS Range Disabled Enabled Default Enabled TARGETS Range Disabled Self reset Latched Default Latched Figure 4 120 RTD Trouble logic diagram 894178A1 cdr SETPOINT Latched Alarm Alarm Function Disabled Alarm OR RTD Trouble OP FLEXLOGIC OPERANDS RTD Trouble ...

Page 424: ...N Range Disabled Trip Alarm Latched Alarm Configurable Default Disabled INTERFACE Range Serial Serial Ethernet Ethernet All Default Serial Only the protocols associated with the selected interface are shown in this screen as options For example if Ethernet is selected the user will select the Ethernet protocols to monitor The Ethernet protocols selection is defined as EthernetProtocolBitmask bitma...

Page 425: ...Status Inactive AN D Operate Output Relay1 TRIP LED TRIP OR O R AN D A N D SETPOINT FUNCTION Disabled 0 Trip Alarm Latched Alarm PICKUP DELAY LED ALARM RESET Command AN D S R LATCH LED PICKUP SETPOINTS Do Not Operate Operate OUTPUT RELAYS Configurable Loss of Comms PKP FLEXLOGIC OPERANDS Loss of Comms OP FLEXLOGIC OPERANDS Set Dominant ...

Page 426: ...reclose SETPOINT GROUPS If there is a conflict in the selection of the active group between a setpoint inputs and inputs from functions the higher numbered group is made active For example if the inputs for Group 2 4 and 6 are all asserted the relay uses Group 6 If the logic input for Group 4 then becomes de asserted the relay uses Group 3 Under some application conditions the user requires that t...

Page 427: ...Logic operand Default Off The setpoint selects the FlexLogic operand that initiates change of the Active Setpoint Group GROUP CHANGE INHIBIT 1 UP TO 16 Range Off Any FlexLogic operand Default Off The setpoint selects the FlexLogic operand that inhibits change of the active setpoint group EVENTS Range Disabled Enabled Default Enabled ...

Page 428: ...HIBIT 16 Off OR AND OR AND OR AND OR AND OR AND OR AND AND AND AND AND FLEXLOGIC OPERAND S GROUP 5 ACTIVE FLEXLOGIC OPERAND S GROUP 4 ACTIVE FLEXLOGIC OPERAND S GROUP 3 ACTIVE FLEXLOGIC OPERAND S GROUP 2 ACTIVE FLEXLOGIC OPERAND S GROUP 1 ACTIVE AND OR AND OR AND OR AND OR AND OR AND OR TO PROTECTION SETPOINT GROUPS Setpoint Group 2 Setpoint Group 3 Setpoint Group 4 Setpoint Group 5 Setpoint Group...

Page 429: ...are designated for Tag Block and Bypass Block for each component upon selection In this mode the Local Open and Local Close setpoints for Breaker Control or Switch Control see the respective logic are active Remote when Remote Mode is enabled the switches are controlled open close from any assigned FlexLogic operand contact input virtual input virtual output remote input or via communication The C...

Page 430: ...onfirmation and when in Remote mode the breaker is directly controlled by executing the remote open and close commands from the configured setpoints When the Select Before Operate setpoint is set to Enabled the navigation the breaker or switch selection as well as the blocking bypassing and tagging are operational when in Local mode When switched to Remote mode the remote blocking and bypassing wi...

Page 431: ...Control for breakers Local Control for switches When the block is active the letter B appears in the SLD next to the controlled component 894195A1 cdr MESSAGE SLD Breaker Selection 5 min Timer Clears the selection Setpoint Bkr Sw Select Timeout OR AND OR SLD Switch Selection PB ESCAPE BKR 1 BKR 2 BKR 3 Local Mode ON FLEXLOGIC OPERAND BKR 1 Selected FLEXLOGIC OPERANDS BKR 2 Selected BKR 3 Selected ...

Page 432: ...reakeror disconnect switch is tagged the open and close controls are inhibited Both remote and local control commands are blocked if the tagged operand BKR Tag ON or SW Tag ON is active for the selected particular breaker or switch respectively The breaker or switch is tagged by pressing the SLD pushbutton Tag If the selected switching device is tagged a letter T appears under its symbol Tagging c...

Page 433: ...locking or bypassing block is retained for this component after it s been deselected To change the status of the applied action the component need be reselected FASTPATH The Local Mode control allows programming of separate pair of PBs for Open and Close commands to breakers and for Open and Close commands to switches If desired one pair of pushbuttons can be programmed for Open and Close commands...

Page 434: ...tion logic FLEXLOGIC OPERAND BKR1 Selected from Bkr Sw selection logic AND FLEXLOGIC OPERAND Block ON from Local Block logic FLEXLOGIC OPERAND Bypass Block ON From Local Bypass Block logic The logic shows the local breaker control for Breaker 1 with Enabled and Disabled Select Before Operate setpoint FLEXLOGIC OPERAND BKR1 Rem Blk Open By FLEXLOGIC OPERAND BKR1 Rem Blk Open AND FLEXLOGIC OPERAND B...

Page 435: ...itch 1 when Select Before Operate setpoint is set to Enabled The local switch control is not available when SBO is set to Disabled SETPOINT Switch1 Local Open Off 0 Pushbutton ON 1 SETPOINT Local Mode Off 0 FLEXLOGIC OPERAND Local Mode ON Local Mode OFF LM Shows on display banner AND FLEXLOGIC OPERAND Tag ON from Tagging logic AND AND AND FLEXLOGIC OPERAND SWt1 Opened FLEXLOGIC OPERAND SW1 Closed ...

Page 436: ...is setting specifies the available time for open close commands after a breaker or a disconnect switch has been selected in the single line diagram BKR LOCAL OPEN Range Off Pushbutton 1 ON Pushbutton 10 ON Contact Input X Default Pushbutton 1 ON This setpoint is active when Local Mode is activated The breaker open command can be initiated by the selected faceplate pushbutton BKR LOCAL CLOSE Range ...

Page 437: ...or a switch is tagged both the local and remote control of the device is inhibited FASTPATH Tagging is applied only from the TAG key and is mostly used for maintenance purposes and in general when either the open or close control must be inhibited The tagging cannot be bypassed and can only be disabled untagged by pressing the TAG key again EVENTS Range Disabled Enabled Default Enabled TARGETS Ran...

Page 438: ...Control BKR1 X REMOTE OPEN Range Off Any FlexLogic operand Default Off The setting specifies the input which when asserted initiates a Trip command to output relay 1 TRIP When the selected input is asserted the Trip contact is energized and stays energized until the input drops off the breaker opens and the selected Trip seal in time expires This setpoint provides the flexibility to operate the Tr...

Page 439: ... is not bypassed and Close is applied for an application where the breaker is located on radial feeders or the line is powered by one source only the DEAD SOURCE PERM setpoint from the Synchrocheck menu shall not be disabled FASTPATH The 845 relay has one three phase voltage inputs a single auxiliary voltage input and one Synchrocheck element It is strongly recommended to connect the relay voltage...

Page 440: ...Blk Cls By FLEXLOGIC OPERAND BKR1 Remote Open OPEN command Relay Ready 1 BKR1 Trip Relay Select Setpoints System Breakers BKR1 To Selected BKR 1 Trip Output CLOSE command BKR 1 Close Relay Select FLEXLOGIC OPERAND BKR1 Remote Close To Selected BKR 1 Close Output AND AND From Synchrocheck 1 Sync 1 BKR Cls Perm OR SETPOINTS CLOSE SYNCHROCHECK SPVN BKR 1 Bypass Sync 1 Cls Perm Setpoints System Breake...

Page 441: ...ission for open or close is required FASTPATH The switch Remote Block Open Remote Block Close Bypass Remote Block Open and Bypass Remote Block Close flags are inhibited when the setpoint Select Before Operate residing under Local Control Mode menu is set to Disabled The remote open and close commands are still operational Path Setpoints Control Switch Control SW 1 X Control REMOTE OPEN Range Off A...

Page 442: ...ts the disconnect switch from closing BYPASS REM BLK OPEN Range Off Any FlexLogic operand Default Off This setting specifies the selection of an input which when asserted bypasses the block to the disconnect open control The Open command is permitted BYPASS REM BLK CLOSE Range Off Any FlexLogic operand Default Off This setting specifies the selection of an input which when asserted bypasses the bl...

Page 443: ...XLOGIC OPERAND SW1 Rem Blk Open SW1 Rem Blk Open By FLEXLOGIC OPERAND SW1 Rem Blk Close SW1 Rem Blk Cls By Relay Ready 1 SW 1 Open Relay Select Setpoints System Switches SW1 to output relay selected to open SW1 FLEXLOGIC OPERAND SW1 Open Cmd Relay Ready 1 SW 1 Close Relay Select Setpoints System Switches SW1 to output relay selected to close SW1 FLEXLOGIC OPERAND SW1 Close Cmd from Control Mode lo...

Page 444: ...ected status of the Virtual Input is also shown here The status is a state OFF logic 0 or ON logic 1 If the corresponding Virtual Input selected under Setpoints Inputs Virtual Inputs is set to Latched the On command initiated from this menu stays On and the status of this Virtual Input is also On until the Off command is received If the Virtual Input type is Self Reset the command and status of th...

Page 445: ...c operand Default Off These settings select a FlexLogic operand to be assigned as an input to the Trip Bus LATCHING Range Enabled Disabled Default Disabled The setting enables or disables latching of the Trip Bus output This is typically used when lockout is required or user acknowledgement of the relay response is required RESET Range Off Any FlexLogic operand Default Off The trip bus output is r...

Page 446: ...RIP BUS 1 BLOCK Off 0 LED ALARM LATCHED ALARM Command AND S R LATCH SET DOMINANT Configurable FlexLogic Operands Trip Bus 1 OP SETPOINTS TRIP BUS 1 LATCHING Disabled 0 SETPOINTS TRIP BUS 1 PICKUP DELAY TRIP BUS 1 DROPOUT DELAY t PKP t DPO SETPOINTS Do Not Operate Operate OUTPUT RELAYS 3 X SETPOINTS TRIP BUS 1 INPUT 2 Off 0 SETPOINTS TRIP BUS 1 INPUT 16 Off 0 OR RESET AND SETPOINTS TRIP BUS 1 RESET...

Page 447: ...pe of supervision is equipped with a time delay after which a failed breaker is declared and Trip signals are sent to all breakers required to clear the zone The delays are associated with breaker failure timers 1 2 and 3 Timer 1 logic is supervised by current level only If fault current is detected after the delay interval an output is issued The continued presence of current indicates that the b...

Page 448: ...s of 0 001 x CT Default 1 000 x CT This setpoint specifies the neutral current Retrip level which when exceeded after Breaker Failure initiation will Retrip its own breaker The setting detects the lowest expected fault current on the protected circuit Neutral Retrip current supervision is used to provide increased sensitivity SUPERVISION Range Current 52b Current 52b Default Current The setpoint s...

Page 449: ...ET PICKUP Range 0 050 to 30 000 x CT in steps of 0 001 x CT Default 1 000 x CT The setpoint specifies the neutral current output supervision level The setting detects the lowest expected fault current on the protected circuit Neutral current supervision is used to provide increased sensitivity LOWSET DELAY Range 0 000 to 6000 000 s in steps of 0 001 s Default 0 000 s The setting provides the lowes...

Page 450: ...f reset Latched Default Self reset Initiate Path Setpoints Control Breaker Failure 1 BF1 Initiate EXTERNAL INITIATE Range Off Any FlexLogic operand Default Off The setpoint selects the FlexLogic operand that initiates the Breaker Failure scheme typically the trip signals from external devices FASTPATH The trip signals from internal protection functions may be used with the help of FlexLogic but fo...

Page 451: ...PICKUP IN AND OR SETPOINT BF1 BREAKER CLOSED Off 0 OR RESET SETPOINTS BF1 SUPERVISION Current 52b Current 52b AND AND IA PICKUP IB PICKUP IC PICKUP RUN RUN RUN IN PICKUP RUN SETPOINTS BF1 PHASE HIGHSET PICKUP BF1 NTRL HIGHSET PICKUP IA PICKUP IB PICKUP IC PICKUP RUN RUN RUN IN PICKUP RUN BF1 PHASE LOWSET PICKUP BF1 NTRL LOWSET PICKUP SETPOINTS BF1 T1 PICKUP DELAY t1 PKP 0 SETPOINTS BF1 T2 PICKUP D...

Page 452: ...nsor Trouble are asserted Very fast detection of the Arc flash light event is also possible using Light as the only detection parameter for alarm purposes In addition a user can design customized logic using individual AF1 Light PKP and Arc Flash 1 S OP operands from different light sensors in the FlexLogic engine Path Setpoints Control Arc Flash Arc Flash 1 FUNCTION Range Disabled Trip Alarm Latc...

Page 453: ...el for Sensor 3 Light Sensor 2 Input Factory PKP Level Auto Calibration Level for Sensor 2 OR AND AND AND AND OR Arc Flash 1 OP FlexLogic Operands Arc Flash 1 S1 OP Arc Flash 1 S2 OP Arc Flash 1 S3 OP Arc Flash 1 S4 OP FlexLogic Operands RESET Command AF 1 Light 1 PKP AF 1 Light 2 PKP AF 1 Light 3 PKP AF 1 Light 4 PKP FlexLogic Operands AF 1 HS Phase Current A Iahs AF 1 HS Phase Current B Ibhs AF ...

Page 454: ...quency difference F slip frequency It can be defined as the time it would take the voltage phasor BUS or LINE to traverse an angle equal to 2 Φ at a frequency equal to the frequency difference F This time can be calculated by where Φ phase angle difference in degrees F frequency difference in Hz Example For the values of Φ 30 and F 0 1 Hz the time during which the angle between the two voltages is...

Page 455: ...s bigger than 5 the Synchrocheck will not work Path Setpoints Control Synchrocheck 1 X FUNCTION Range Disabled Enabled Default Disabled BUS VOLTS INPUT Range dependant upon the order code Default Ph VT Bnk1 J2 The setting provides selection of the Bus Volts input either three phase voltages from the three phase VTs connected to the relay or a single voltage from the Auxiliary VT also connected to ...

Page 456: ... the breaker to be closed when one or both of the two voltages Bus Voltage or and Line Voltage are below the maximum voltage threshold A dead or live source is declared by monitoring the voltage level Six options are available The voltage levels that determine whether a source is dead or live are configurable in the four setpoints following this one The DEAD SOURCE PERMISSION range is as follows D...

Page 457: ...int establishes a maximum voltage magnitude for the Line Voltage Below this magnitude the Line Voltage input used for Synchrocheck is be considered Dead or de energized BLOCK Range Off Any FlexLogic operand Default Off The Synchrocheck is blocked when the selected operand is asserted Typically 52a the circuit breaker closed contact is used to block Synchrocheck Synchrocheck is needed only when the...

Page 458: ...IFF Vbus LIVE BUS V MIN SETPOINT LIVE BUS VOLTS MIN Vline LIVE LINE V MIN SETPOINT LIVE LINE VOLTS MIN Vbus DEAD BUS V MAX SETPOINT LIVE BUS VOLTS MAX Vline DEAD LINE V MAX SETPOINT DEAD LINE VOLTS MAX D LINE D BUS D LINE OR D BUS D LINE XOR D BUS OR XOR AND AND AND AND AND OR AND AND AND AND AND AND OR Sync1 Close Perm Sync1 Live Bus Sync1 Live Line Sync1 Dead Bus Sync 1 Dead Line MAX FREQ HYSTER...

Page 459: ...ereas an indication of a Class B failure is the presence of positive sequence current and an insignificant amount of positive sequence voltage These noted indications of fuse failure could also be present when faults are present on the system so a means of detecting faults and inhibiting fuse failure declarations during these events is provided Once the fuse failure condition is declared it is sea...

Page 460: ... LATCH 1 Set Dominant Configurable FlexLogic Operands VT Fuse Fail 1 OP VT Fuse 1 V Loss TIMER 2 cyc 20 cyc SETPOINTS Do Not Operate Operate OUTPUT RELAY 3 X V_1 0 05 p u RUN I_1 0 075 p u RUN V_1 0 80 p u RUN I_1 0 05 p u RUN V_1 I_1 AND OR AND AND OR S R S R LATCH 2 Reset Dominant LATCH 3 Reset Dominant AND AND AND OR I_1 I_1 0 04 p u I_2 I_2 0 04 p u I_0 I_0 0 04 p u Where I is 2 cycles old I_2...

Page 461: ...g and digital outputs The major sub systems of a generic 8 series relay involved in this process are shown as follows NOTE NOTE For information on the Logic Designer and Logic Monitor menu items see Help User Manual Logic Designer Monitor in the EnerVista 8 Series Setup software Figure 4 137 FlexLogic Display Hierarchy The states of all digital signals used in the 845 are represented by flags Flex...

Page 462: ... schemes and outputs is field programmable through the use of logic equations that are sequentially processed The use of virtual inputs and outputs in addition to hardware is available internally and on the communication ports for other relays to use distributed FlexLogic FlexLogic allows users to customize the relay through a series of equations that consist of operators and operands The operands...

Page 463: ... Phs Gnd IOC elements Detection of any trouble in light sensor 1 or corresponding fiber Detection of any trouble in light sensor 2 or corresponding fiber Detection of any trouble in light sensor 3 or corresponding fiber Detection of any trouble in light sensor 4 or corresponding fiber Detection of any trouble in any of the 4 light sensors or corresponding fibers Auxiliary OV Aux OV PKP Aux OV OP A...

Page 464: ...rison value Digital counter 1 output is equal to comparison value Digital counter 1 output is less than comparison value Digital counter 1 reached limit Same set of operands as for Counter 1 Directional Power DirPwr 1 Stg1 PKP DirPwr 1 Stg2 PKP DirPwr 1 PKP DirPwr 1 Stg1 OP DirPwr 1 Stg2 OP DirPwr 1 OP DirPwr 2 Stage 1 of the directional power element 1 has picked up Stage 2 of the directional pow...

Page 465: ...D Local Open command has been initiated to SW X Local Close command has been initiated to SW X Open command to the switch is blocked Close command to the switch is blocked Open switch command is permitted Block Open signal is bypassed Close switch command is permitted Block Close signal is bypassed The selected breaker switch is tagged The selected breaker switch is untagged Disconnect Switch 1 8 ...

Page 466: ...erential has picked up At least one Percent differential element has picked up Phase A differential has operated Phase B differential has operated Phase C differential has operated At least one Percent differential element has operated Percent differential current exceeded 0 5 x PKP for 10 seconds Percent differential protection has been blocked Percent differential flag triggered on phase A Perce...

Page 467: ...e set of operands as per PF 1 Programmable Pushbuttons PB 1 ON PB 1 OFF Pushbuttons 2 and 3 Pushbutton 1 ON state has been asserted Pushbutton 1 OFF state has been asserted The same set of operands as shown for Pushbutton 1 Pulse Output Pos Wthrs Pulse OP Neg Wthrs Pulse OP Pos Varh Pulse OP Neg Varh Pulse OP Positive Watthours pulse occurs at the end of the programed energy increment Negative Wat...

Page 468: ...e command to Switch X is blocked The block open signal for Switch X is bypassed The block close signal for Switch X is bypassed X the element number Synchrocheck Sync1 OK Sync1 Live Bus Sync1 Live Line Sync1 Dead Bus Sync1 Dead Line Sync1 Dead Src OK Sync1 Close Perm Synchrocheck 1 permission is given Synchrocheck 1 bus voltage is live Synchrocheck 1 line voltage is live Synchrocheck 1 bus voltage...

Page 469: ...ts per Hertz element 2 has operated VT Fuse Failure VT Fuse Fail1 OP VT Fuse1 V Loss VT fuse failure detector 1 has operated VT fuse 1 failure has lost voltage signals V2 below 10 AND V1 below 5 of nominal Wattmetric Ground Fault Watt GndFlt 1 PKP Watt GndFlt 1 OP Wattmetric directional element 1 has picked up Wattmetric directional element 1 has operated Xfmr Loss Life Xfmr Loss Life PKP Xfmr Los...

Page 470: ...6 previous parameters AND 2 AND 16 2 input AND gate 16 input AND gate Operates on the 2 previous parameters Operates on the 16 previous parameters NOR 2 NOR 16 2 input NOR gate 16 input NOR gate Operates on the 2 previous parameters Operates on the 16 previous parameters NAND 2 NAND 16 2 input NAND gate 16 input NAND gate Operates on the 2 previous parameters Operates on the 16 previous parameters...

Page 471: ...Seconds Minutes Default Milliseconds The setpoint is used to select the time measuring unit TIMER 1 PICKUP DELAY Range 0 to 60000 s in steps of 1 s Default 0 s The setpoint sets the time delay to Pickup If a Pickup delay is not required set this function to 0 TIMER 1 DROPOUT DELAY Range 0 to 60000 s in steps of 1 s Default 0 s The setpoint sets the time delay to Dropout If a Dropout delay is not r...

Page 472: ...enables or disables the Non volatile Latch function NV LATCH 1 TYPE Range Reset Dominant Set Dominant Default Reset Dominant The setting characterizes NV LATCH 1 to be set or reset dominant NV LATCH 1 SET Range Any FlexLogic operand Default Off If asserted this specified FlexLogic operand SET NV LATCH 1 LATCH 1 RESET Range Any FlexLogic operand Default Off If asserted this specified FlexLogic oper...

Page 473: ...Graphics section for more details Logic Design Last Saved Logic Design Last Compiled and FlexLogic Editor Last Saved Each of these three read only variables holds the time stamp that represents the time that the operation of the respective variable was performed 1 When no Logic New file creation is present these timestamps are set to default text representations 2 Time stamps are displayed in the ...

Page 474: ...user tries to open the FlexLogic Equation Editor of a particular device or file If the Logic Designer screen is open and in Edit mode a message prompts the user to save any changes The FlexLogic Equation Editor is not launched If the Logic Designer is open and in saved mode no edits to save or compile the Logic Designer screen is closed and then the FlexLogic Equation Editor launch is initiated So...

Page 475: ...tion To View the FlexLogic Graphic Click on the View button at the top of the Type column in the FlexLogic Equation screen see previous figure Provided the equation is entered correctly this generates a graphical representation of the expression previously entered If any operator inputs are missing or any FlexLogic rules have been violated the EnerVista 8 Series Setup software displays a message b...

Page 476: ...gender current and current in any combination phase symmetrical phase phase kA A differential restraint etc voltage and voltage as above active power and active power Watts and Watts reactive power and reactive power Vars and Vars apparent power and apparent power VA and VA angle and angle any no matter what signal for example angle of voltage and angle of current are a valid pair and any for exam...

Page 477: ...nt does not operate if the two input signals are of different types for example if one tries to use active power and phase angle to build the effective operating signal PICKUP Range 30 000 to 30 000 pu in steps of 0 001 pu Default 1 000 This setting specifies the operating threshold for the effective operating signal of the element If the Over direction is set the element picks up when the operati...

Page 478: ...PLES 13 8 kV power system Phase VT Connection Wye Phase VT Secondary 66 4 V Phase VT Ratio 120 1 phase to neutral primary voltage 120 66 4 7968 V Aux VT Connection Vab Aux VT Secondary 115 V Aux VT Ratio 120 1 phase phase primary voltage 13800V Phase CTs Primary 2000 A Ground CT Primary 500 A Frequency 60Hz Phase Angle DegBASE 360 deg Harmonic Content HBASE 100 of nominal THD THDBASE 100 Frequency...

Page 479: ...en the selected inputs becomes bigger than 276 Volts the FlexElement will pickup and operate which can be used to energize contact or initiate alarm or trip Detecting current difference between Neutral and Ground currents In a balanced system the computed neutral and the measured ground currents is 0 Amps However during ground faults their values are not zero More specifically if the phase and gro...

Page 480: ... abs 0 7 PFBASE 100 20 FASTPATH The minimum pickup should not be less than 0 01 pu as the measurement resolution for the Power Factor is 0 01 Input 1 Pwr1 PF Input 2 Off Operating Mode Signed Input Comparison Mode Level Direction Under Pickup 0 700 pu Hysteresis 20 0 Detecting high THD Total Harmonic Distortion THDBASE 100 A FlexElement can be programmed to detect excessive amount of harmonics in ...

Page 481: ...th oil pumps forcing the circulation of the oil or problems associated with the transformer cooling equipment A FlexElement can be programmed to detect the Top Bottom oil difference and issue an alarm trip or energize a contact used for switching in out transformer equipment The setpoints of the FlexElement below reflect detecting a 5 C degree temperature difference between the istalled RTDs measu...

Page 482: ...erarchy Path Setpoints Testing Simulation Test LEDs Contact Inputs Output Relays The 8 Series can simulate current and voltage inputs when the Simulation feature is enabled Other test operations are also possible such as the LED lamp test of each color contact input states and testing of output relays Pre Fault Setpoints Device System Inputs Outputs Protection Monitoring Control FlexLogic Level 1 ...

Page 483: ... Range Disabled Prefault State Fault State Postfault State Default Disabled Program the Simulation State to Disabled if actual system inputs are to be monitored If programmed to any other value the relay is in test mode and actual system parameters are not monitored including Current Voltage and Contact Inputs The system parameters simulated by the relay are those in the following section that cor...

Page 484: ...re not available if the corresponding VT Bank PHASE VT CONNECTION setpoint is Delta Voltages are set in secondary VT units The CT and VT Bank availability is dependent on the installed Order Code options Path Setpoints Testing Simulation Pre Fault J2 Prefault Van Vbn Vcn Vx Voltage Range 0 00 to 300 00 V in steps of 0 01 Default 0 00 V J2 Prefault Van Vbn Vcn Vaux Angle Range 359 9 to 0 0 in steps...

Page 485: ... K1 K2 Fault la lb lc lg Angle Range 359 9 to 0 0 in steps of 0 1 Default 0 0 Post Fault The Post fault state is intended to simulate a system that has tripped by replacing the normal input parameters with programmed post fault values Voltage magnitudes and angles are entered as Wye values only The voltage setpoints are not available if the corresponding VT Bank PHASE VT CONNECTION setpoint is Del...

Page 486: ...ch contact input when in test mode The number of Contact Inputs available is dependent on the installed Order Code options NOTE NOTE Contact Inputs setpoints here in test will revert to default values at power up Path Setpoints Testing Contact Inputs CI 1 X Range Off On Default Off The item name displays the user configurable name for the contact input Output Relays The Output Relays section is us...

Page 487: ...ons of the loop back test TEST START Range No Yes Default No This setting is used to initiate the test when the command is set to Yes ACTUAL VALUES TEST STATUS Range None Testing Passed Failed Default None This value indicates the result of the test TESTS RUN Range 0 to 65535 in steps of 1 Default 0 The remaining test iterations once the loop back test has been initiated TESTS PASSED Range 0 to 65...

Page 488: ...r of tests that passed and failed respectively Table 4 41 Modbus Addresses Data Item Data type Ethernet Port 4 Modbus Address Ethernet Port 5 Modbus Address Number of Tests Setpoint 16 bit value 0XF212 0XF218 Test Start Command Setpoint 16 bit enumeration 0XF213 0XF219 Test Status Actual Value 16 bit enumeration 0XF214 0XF21A Tests to Run Actual Value 16 bits 0xF215 0XF21B Tests Passed Count Actua...

Page 489: ...845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 5 1 845 Transformer Protection System Chapter 5 Status GE Grid Solutions Status Figure 5 1 Main Status Screen ...

Page 490: ...p Dn or Up Dn Left Right navigation keys highlights BKR1 and navigates through BKR1 2 3 etc and then through Switch1 2 3 etc If the Up Dn Left Right keys are used the selection moves to the closest available breaker switch from the currently highlighted object To select the breaker switch press the enter key Upon pressing the Enter key the tab labels change to the programmable tab pushbutton label...

Page 491: ...re are two ways to navigate to the Tab Pushbutton control pages Relay Home Screens Path Status Summary Tab Pushbuttons from relay Home Screens By default the Tab Pushbuttons summary page is programmed as one of the Home Screens Press the home button repeatedly to cycle through the programmed Home Screens FASTPATH Tab pushbuttons can only be controlled physically through the front panel of the rela...

Page 492: ...r can cycle through all five pushbutton screens To go from page 2 to page 1 one must press 4 times to cycle through and navigate to page 1 with pushbuttons 1 to 4 Alternatively one can escape to the overall summary screen and navigate to any desired page of pushbuttons Breakers The status of the breaker breakers is displayed individually If the selected trip output relay is Form A type the status ...

Page 493: ...ture It is always ON Path Status Last Trip Data CAUSE Range Off any FlexLogic Operand Default No trip to Date EVENT Range 0 to 4294967295 in steps of 1 Default 0 DATE Range MM DD YYYY HH MM Default 01 01 08 00 00 00 PARAMETER 1 to 64 Range 2147483648 to 2147483647 in steps of 1 Default 0 Arc Flash Path Status Arc Flash Arc Flash 1 The status value shows the state of the given Flex operand related ...

Page 494: ...s is shown here see device menu via the menu path The Off On display indicates the logic state of the Contact Input Output Relays Path Status Output Relays The status of all output relays is shown here see above In the ITEM NAME column the value indicates the label on the output terminal The value column indicates the present ON or OFF state of the output relay ...

Page 495: ...L 5 7 Virtual Inputs Path Status Virtual Inputs 1 X The state of all virtual inputs is shown here see next figure The value for each Virtual Input is shown on the control panel graphically as a toggle switch in either the On state or the Off O state Figure 5 5 Status of Virtual Inputs ...

Page 496: ...ons each with 64 items per transmission or reception Non structured GOOSE is supported Each item within the GOOSE message can be a digital or analog value Messages are launched within one scan of a digital point status change or an analog exceeding its deadband The 845 server supports a subset of the server features described in part 7 2 of the IEC61850 standard GOOSE MESSAGING As indicated above ...

Page 497: ...ate for the remote input GGIO1 INDICATIONS Path Status Communications GGIO1 Indications The present state of the 32 GGIO1 Indications are shown here There are up to 32 GGIO indications that can be used to map any FlexLogic operand into the IED 61850 information model Default value is Off GOOSE STATUS Path Status Communications GOOSE Status GOOSE 1 to 64 Status Range OFF ON Default OFF GOOSE HEADER...

Page 498: ...ult NO RUNNING SAVING CID TO FLASH Range NO YES Default NO CID HANDLING DONE Range YES NO Default YES NUMBER OF CONNECTED CLIENTS Default 0 CLIENT 1 8 IP ADDRESS Range 0 0XFFFFFFFF Default 0 ACTIVITY STATUS The communication state for each enabled communication type is shown by its value The main CPU and Comms software sets resets the active bits for all enabled communication types The communicati...

Page 499: ...T DEVICENET Range NONE ACTIVE Default NONE ETHERNET PROFIBUS Range NONE ACTIVE Default NONE CONNECTIONS Path Status Communications Connections MMS TCP Maximum Range 0 to 99 in steps of 1 Default 0 MMS TCP Remaining Range 0 to 99 in steps of 1 Default 0 Modbus TCP Maximum Range 0 to 99 in steps of 1 Default 0 Modbus TCP Remaining Range 0 to 99 in steps of 1 Default 0 DNP TCP Maximum Range 0 to 99 i...

Page 500: ...ER 5 STATUS IEC 104 Remaining Range 0 to 99 in steps of 1 Default 0 OPC UA Maximum Range 0 to 99 in steps of 1 Default 0 OPC UA Remaining Range 0 to 99 in steps of 1 Default 0 SFTP Maximum Range 0 to 99 in steps of 1 Default 0 SFTP Remaining Range 0 to 99 in steps of 1 Default 0 ...

Page 501: ...ld time Product Serial The relay serial number Order Code The installed Order Code MAC Address 1 The MAC address for copper Ethernet port 1 CANBUS RMIO The commissioned value of the CANBUS IO is displayed here If the relay has never been commissioned then the value will be None i e default None and Range 6 alphanumeric characters RMIO RTDs The number of remote RTDs detected Comms CPU The Informati...

Page 502: ...MM DD YY and HH MM SS Average Humidity The average of all the humidity measurements taken over time last 1 hr by the EAM Maximum Humidity The maximum humidity measurement taken by the EAM since it began recording data Minimum Humidity The minimum humidity measurement taken by the EAM since it began recording data Average Ambient Temp The average of all the instantaneous temperature measurements ta...

Page 503: ... CID HANDLING DONE Range YES NO Default YES SELF TEST FAULT Range YES NO Default NO MAINTENANCE Range YES NO Default NO IN SERVICE Range YES NO Default YES PICKUP STATE Range YES NO Default YES BREAKER CONNECTED Range YES NO Default YES BREAKER CLOSED Range YES NO Default NO BREAKER TRIPPED Range YES NO Default NO ALARM Range YES NO Default NO TRIP Range YES NO Default NO ACTIVE GROUP Range SP Gro...

Page 504: ...d by PTP to be globally unique so one can always know which clock is grandmaster in a system with multiple grandmaster capable clocks RTC Accuracy is the estimated maximum time difference at present in the Real Time Clock RTC considering the quality information imbedded in the received time signal how long the relay has had to lock to the time source and in the case of time signal interruptions th...

Page 505: ...rposes all phasor angles in a given relay are referred to an AC input channel pre selected as the phase A voltage If there is no voltage input the phase A current is used for angle reference The phase angle of the reference signal always display zero degrees and all other phase angles are relative to this signal If the preselected reference signal is not measurable at a given time the phase angles...

Page 506: ...ree 3 times a second for readability All phasors and symmetrical components are referenced to the A N voltage phasor for wye connected VTs to the A B voltage phasor for delta connected VTs or to the phase A current phasor when no voltage signals are present Figure 6 2 An example of the Metering Summary submenu All the measured values can be viewed on the front panel display or monitored by remote ...

Page 507: ...ING 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 6 3 Figure 6 3 Current Metering Screen EnerVista 8 Series The complete list of actual values available in the Metering menu is covered in the following sections ...

Page 508: ...FORMER PROTECTION SYSTEM INSTRUCTION MANUAL SUMMARY CHAPTER 6 METERING Summary Path Metering Summary The Metering Summary menu consists of display screens including a graphical presentation of key phasor quantities ...

Page 509: ...tion and the CTs from the Delta winding in Wye connection In the past the magnitude correction has been accomplished using interposing CTs or tapped relay windings This however is not required any more when installing the 845 relay The 845 relay simplifies the process by performing the magnitude and phase shift compensations automatically internally Upon entering settings for the protected transfo...

Page 510: ...isplayed in primary amperes Windings The harmonic derating factor for each of the windings shows the effect of non sinusoidal load currents on the power transformer s rated full load current The actual values messages display the harmonic derating factor for windings 1 through 3 The 845 displays winding load parameters as follows Path Metering Transformer Windings Winding 1 load W1 Load of rated R...

Page 511: ...mal Elements actual values starts at the time the relay is first powered up Therefore the Daily Rate Loss of Life starts accumulating in the next 24 hour period All records can be cleared either from the relay s keypad or from the EnerVista 8 Series Setup PC program using the Clear Loss of Life command from the menu Records Clear Records Tap Changer Path Metering Transformer Tap Changer Tap Positi...

Page 512: ...ral In Range 0 000 to 12000 000 A Phase A Ia RMS Range 0 000 to 12000 000 A Phase B Ib RMS Range 0 000 to 12000 000 A Phase C Ic RMS Range 0 000 to 12000 000 A Ground Ig RMS Range 0 000 to 12000 000 A Sensitive Ground Isg RMS Range 0 000 to 1200 000 A Neutral In RMS Range 0 000 to 12000 000 A Phase A Angle Ia Angle Range 0 0 to 359 9 Phase B Angle Ib Angle Range 0 0 to 359 9 Phase C Angle Ic Angle...

Page 513: ...ial Igd Range 0 000 to 12000 000 A Ground Differential Angle Igd Angle Range 0 0 to 359 9 Load I Range 0 0 to 100 0 NOTE NOTE Percent of load to trip is calculated from the phase with the highest current reading This metered value is the ratio between the highest phase current injected for the current bank and the lowest pickup setting among all Phase Timed and Instantaneous overcurrent elements I...

Page 514: ...A Vca Range 0 00 to 600000 00 V Neutral Vn Range 0 00 to 600000 00 V Auxiliary Vaux Range 0 00 to 600000 00 V Phase A Van RMS 0 00 V Range 0 00 to 600000 00 V Phase B Vbn RMS Range 0 00 to 600000 00 V Phase C Vcn RMS Range 0 00 to 600000 00 V Phase to Phase AB Vab RMS Range 0 00 to 600000 00 V Phase to Phase BC Vbc RMS Range 0 00 to 600000 00 V Phase to Phase CA Vca RMS Range 0 00 to 600000 00 V N...

Page 515: ...to 600000 00 V Average Phase V AVG L N Range 0 00 to 600000 00 V Zero Sequence V0 0 00 V Range 0 00 to 600000 00 V Positive Sequence V1 Range 0 00 to 600000 00 V Negative Sequence V2 Range 0 00 to 600000 00 V Zero Sequence Angle V0 Angle Range 0 0 to 359 9 Positive Sequence Angle V1 Angle Range 0 0 to 359 9 Negative Sequence Angle V2 Angle Range 0 0 to 359 9 Frequency Path Metering Frequency 1 J F...

Page 516: ...4294967 295 in steps of 0 001 J1 Phase C 5th Harm Mag Range 0 000 to 4294967 295 in steps of 0 001 K1 Phase A 2nd Harm Mag Range 0 000 to 4294967 295 in steps of 0 001 K1 Phase B 2nd Harm Mag Range 0 000 to 4294967 295 in steps of 0 001 K1 Phase C 2nd Harm Mag Range 0 000 to 4294967 295 in steps of 0 001 K1 Phase A 5th Harm Mag Range 0 000 to 4294967 295 in steps of 0 001 K1 Phase B 5th Harm Mag R...

Page 517: ...ortion Phase A THD Range 0 0 to 100 0 Phase B Total Harmonic Distortion Phase B THD Range 0 0 to 100 0 Phase C Total Harmonic Distortion Phase C THD Range 0 0 to 100 0 Phase A Second Harmonic Phase A 2 Range 0 0 to 100 0 Phase B Second Harmonic Phase B 2 Range 0 0 to 100 0 Phase C Second Harmonic Phase C 2 Range 0 0 to 100 0 Phase A Third Harmonic Phase A 3 Range 0 0 to 100 0 Phase B Third Harmoni...

Page 518: ...s in the Harmonic Detection element are calculated and updated every protection pass Path Metering Harmonic Detection Synchrocheck Path Metering Synchrocheck If a Synchrocheck function setting is Disabled the corresponding metering display is not displayed Bus Voltage Magnitude Bus Volts Magnitude Range 0 00 to 600000 00 V Bus Voltage Angle Bus Volts Angle Range 0 0 to 359 9 Bus Voltage Frequency ...

Page 519: ...s seen by the 8 series relays Voltage Generator Generator Inductive Inductive Resistive Resistive Generator Generator 8 SERIES IED G G M M G G VCG IC VAG IA VBG IB VCG IC VAG IA VBG IB VCG IC VAG IA VBG IB VCG IC VAG IA VBG IB Q Q Q Q PF Lead PF Lead PF Lead PF Lead PF Lag PF Lag PF Lag PF Lag PF Lag PF Lag PF Lag PF Lag PF Lead PF Lead PF Lead PF Lead Q Q Q Q P P P P P P P P IA IA IA IA S VI LOAD...

Page 520: ...48364 7 kvar Phase A Apparent Ph A Apparent Range 0 kVA to 214748364 7 kVA Phase B Apparent Ph B Apparent Range 0 kVA to 214748364 7 kVA Phase C Apparent Ph C Apparent Range 0 kVA to 214748364 7 kVA Power Factor Total PF Range 0 01 Lag to 1 00 to 0 01 Lead Phase A Power Factor Ph A PF Range 0 01 Lag to 1 00 to 0 01 Lead Phase B Power Factor Ph B PF Range 0 01 Lag to 1 00 to 0 01 Lead Phase C Power...

Page 521: ...ted under MONITORING FUNCTIONS DEMAND For each quantity the relay displays the Demand over the most recent Demand time interval the maximum Demand since the last maximum Demand reset and the time and date stamp of this maximum Demand value Maximum Demand quantities can be reset to zero with the RECORDS CLEAR RECORDS MAX CURRENT DEMAND Path Metering Current Demand 1 Reset J1 Reset Demand Date Time ...

Page 522: ... 12000 000 A Date Time Phase A Demand K1 Date Time Ph A Demand MM DD YY HH MM SS Date Time Phase B Demand K1 Date Time Ph B Demand MM DD YY HH MM SS Date Time Phase C Demand K1 Date Time Ph C Demand MM DD YY HH MM SS Current Demand K2 Path Metering Current Demand K2 Reset K2 Reset Demand Date Time MM DD YY 00 00 00 Phase A Demand K2 Ph A Demand Range 0 000 to 12000 000 A Phase B Demand K2 Ph B Dem...

Page 523: ...y be useful to calibrate the feature by compensating the angular errors of the CTs and VTs with the use of the RCA and CALIBRATION settings Directional Power 1 Directional Power 1 Range 214748364 8 kW to 214748364 7 kW Default 0 0 kW Directional Power 2 Directional Power 2 Range 214748364 8 kW to 214748364 7 kW Default 0 0 kW Directional Power X Directional Power X Range 214748364 8 kW to 21474836...

Page 524: ...rature can be displayed in Celsius or Fahrenheit degrees The selection is made in Setpoints Device Installation Temperature Display Reset RTD Date Time Range DD MM YY hh mm ss NOTE NOTE Maximum RTD values can be cleared reset by setting the value of Setpoints Records Clear Records RTD Maximums to ON Executing this command loads 40 C as the initial Maximum RTD value RTD 1 13 Max Range 40 to 250 C t...

Page 525: ... are displayed in pu values using the definitions of the base units in the Definitions of the Base Unit for the FLEXELEMENT table This table is in the Setpoints FlexLogic FlexElements section FlexElement Operating Signals FlexEI 1 Op Signal FlexEI 2 Op Signal FlexEI 3 Op Signal FlexEI 4 Op Signal FlexEI 5 Op Signal FlexEI 6 Op Signal FlexEI 7 Op Signal FlexEI 8 Op Signal ...

Page 526: ...6 22 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL FLEXELEMENTS CHAPTER 6 METERING ...

Page 527: ...ed The event number is incremented for each new event The Event Recorder captures contextual data associated with the last 1024 events listed in chronological order from most recent to oldest Events for a particular element are captured if the setpoint Events from its menu is selected to Enabled By default the Events setpoint from all elements is set to Enabled Path Records Event Records The event...

Page 528: ... which the last report was generated LAST CLEAR DATE TIME Range MM DD YY HH MM SS This value is the date and time on which the record was cleared FAULT REPORT X TIME Range MM DD YY HH MM SS This value is the date and time on which the specified fault report was generated Data Logger The 845 Data Logger record can be retrieved and seen from this window It displays the oldest and newest timestamps a...

Page 529: ...five values and average of values since last reset are recorded calculated and displayed When the DETECTION mode is selected the values displayed here can be used as the reference for user settings The values are saved into non volatile memory to avoid the loss of data during the power down period Path Records Breaker Health Digital Counters The present status of the sixteen Digital Counters is sh...

Page 530: ...he operand is set to Low when there is a successful communication attempt The Time of Last Successful Poll is updated if the update for all pooled data was success This is a timestamp value for the last successful read Path Records Remote Modbus Device Device 1 Status DEVICE STATUS Range Offline Online Default Offline LAST SUCCESSFUL POLL Range MM DD YYYY HH MM SS Default 01 01 2000 00 00 This is ...

Page 531: ...147483648 to 2147483647 in steps of 1 Default 0 Up to 64 FlexAnalog operands can be shown here The displayed text see Item Name field in EnerVista 8 Series Setup software is the FlexAnalog name defined in the Generic Modbus Device Setpoint label field in the CID file The value displayed is based on the Data Type and the Units field defined in the Generic Modbus Device Setpoint for a specific analo...

Page 532: ... for Analog Values of BSG3 Clear Records The Clear Records command is accessible from the front panel and from the EnerVista 8 Series Setup software Clear records from here Path Records Clear Records Records can be cleared either by assigning On to the appropriate setting or by assigning a FlexLogic operand ...

Page 533: ... Protection Relay and M D monitoring and diagnostics devices are connected and operated in client server mode of operation The contents from the M D device are organized as per the menu tree shown below under Transformer M D menu NOTE NOTE Detailed information on the Transformer M D menu tree contents i e DGA Monitoring DGA Models etc is available in the M D User Guide ...

Page 534: ...ration parameters are used for establishing the communication between the 845 relay and DGA device IP ADDRESS Range standard IPv4 address Default 0 0 0 0 This setting specifies the IP address of the M D DGA device that communicates with the 845 relay SLAVE ADDRESS Range 0 to 254 Default 0 This setting is the slave ID field unit ID within the Modbus protocol It is the ID of the M D device and each ...

Page 535: ...m provides the device ID and serial number of the DGA device connected to the 845 relay Dissolved Gas Analysis The 845 relay reads gas ppm values at regular intervals of time based on the DGA device type and displays the latest gas ppm values along with a measurement date timestamp For HM2 DGA device types data is read at 15 minute intervals For Transfix DGA 500 and Minitrans device types data is ...

Page 536: ...records up to 365 data record sets from actual transformer operation This data can be used to evaluate the changes trends over time in transformer models The records can only be retrieved using the EnerVista 8 Series Setup software Learned Data records are calculated each day at mid night 12 00 00 AM with a total of 365 records supported based on the FIFO concept ...

Page 537: ... supported by the 845 relay based on the FIFO concept Each energization record contains Transient record data with 10 cycles of user configured energization winding source voltage and current waveform data of each phase sampled at 64 samples cycle Computed energization parameters through data captured in the metering module from the initial 10 cycles of captured raw data during an energization eve...

Page 538: ...rical phasor data generated during a trip condition Pre and post fault gas ppm data Electrical and thermal data captured during fault DGA models computed with pre post fault gas ppm data and A PDF report capturing integrated fault data Models Models consist of transformer operational data represented in a constructive manner using electrical thermal and DGA data This section contains transformer m...

Page 539: ...odel in this section is a customized trend chart where the user can select the required parameter trends to display DGA Models DGA models consist of the standard Duval Triangle and Gas Ratios model which is computed based on the latest 50 DGA data samples The Key Gas model is computed based on the latest DGA data ...

Page 540: ... of the parameter Transformer Health Report The Transformer health report gives an executive summary on transformer operational data within a user selectable date times range in the form of a PDF report The health report PDF consists of report data online DGA status nameplate data energization summary protection events summary key learned data parameter trends historical maximum data DGA data and ...

Page 541: ...L TREND 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 8 9 DGA Historical Trend DGA historical trend provides a trend chart of DGA parameters with the latest 100 gas ppm values displayed as a varying trend based on the DGA device type ...

Page 542: ...8 10 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL DGA HISTORICAL TREND CHAPTER 8 TRANSFORMER M D ...

Page 543: ...e Path Maintenance Environmental Awareness Health Report Over the life of the 845 product remedial action can be required The 845 has a module which can record environmental data Environmental Health Report Prolonged exposure to harsh environments and transient conditions that exceed those stated in Section 1 Specifications reduce the life of electronic products The 845 has an Environmental Awaren...

Page 544: ...9 2 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL ENVIRONMENTAL HEALTH REPORT CHAPTER 9 MAINTENANCE ...

Page 545: ...spection for any damage corrosion dust or loose wires 4 Event recorder file download with further events analysis Out of service Maintenance 1 Check wiring connections for firmness 2 Analog values currents voltages RTDs analog inputs injection test and metering accuracy verification Calibrated test equipment is required 3 Protection elements setting verification analog values injection or visual v...

Page 546: ...9 4 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL GENERAL MAINTENANCE CHAPTER 9 MAINTENANCE ...

Page 547: ...ts GE manufactured products for 10 years For warranty details including any limitations and disclaimers see the GE Digital Energy Terms and Conditions at https www gegridsolutions com multilin warranty htm For products shipped before 1 October 2013 the standard 24 month warranty applies Revision history Table A 1 Revision History MANUAL P N RELEASE DATE 1601 0651 A1 24 May 2015 1601 0651 A2 August...

Page 548: ... and remove the breaker disconnected dependencies 4 Revised Undercurrent logic diagram to 894205A1 cdr to add setting for signal input 4 Added new SOTF section to Setpoints Protection 4 Revised Negative Sequence Directional OC logic diagram to 894204A1 cdr to add setting for signal input 4 Revised Broken Conductor logic diagram to 894043A2 cdr to add setting for signal input 4 Revised Load Encroac...

Page 549: ...inding transformer with VTs on LV side 894011A3 cdr with 892822A1 pdf 2 11 2 12 Replaced typical wiring diagram for 2 winding transformer without VTs 894012A3 cdr with 892823A1 pdf 2 12 2 13 Replaced typical wiring diagram for 3 winding transformer 894013A3 cdr with 892789A1 pdf 4 5 6 7 4 5 6 7 Removed the HMIs associated with the path description in each chapter 4 28 4 29 Replaced single communic...

Page 550: ... section Table A 5 Major Updates for 845 A2 PAGE NUMBER A1 PAGE NUMBER A2 CHANGES Manual revision number from A1 to A2 and product version revision from 1 4x to 1 5x 1 8 1 8 Updated 845 order codes see slots B C G and H 1 10 1 10 Added Arc Flash specifications to Specifications Protection 1 22 1 23 1 22 1 23 Added Analog Inputs and Analog Outputs to Specifications Inputs and Specifications Outputs...

Page 551: ...CHAPTER A APPENDIX A REVISION HISTORY 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL A 5 Table A 6 Major Updates for 845 A1 PAGE NUMBER CHANGES Manual revision number A1 first release ...

Page 552: ...A 6 845 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL REVISION HISTORY CHAPTER A APPENDIX A ...

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