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GE Multilin 345, Instruction Manual

The GE 345 is a sleek and efficient device designed for seamless performance. To get started in no time, simply download the Quick Start Manual from our website for free. This comprehensive manual provides step-by-step instructions and helpful tips, ensuring a hassle-free user experience with the GE 345.

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345 TRANSFORMER PROTECTION SYSTEM – INSTRUCTION MANUAL

ELECTRICAL INSTALLATION

CHAPTER 2: INSTALLATION

RMIO module installation

Although the RMIO is internally shielded to minimize noise pickup and interference, it 
should be mounted away from high current conductors or sources of strong magnetic 
fields.

Figure 2-21: RMIO unit showing 2 IO_G modules

Figure 2-22:  RMIO terminal identification with 4 IO_G modules

Tx
Rx

IO_G

IO_G

RCU

PSU

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Com

Po

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Common

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896750.cdr

IO_G

IO_G

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Summary of Contents for 345

Page 1: ... manual 345 revision 2 3x Manual P N 1601 9098 AF GE publication code GEK 113568P 1601 9098 AF GE Grid Solutions 345 Transformer Protection System Transformer protection and control LISTED 52TL IND CONT EQ E83849 ...

Page 2: ...ilin The content of this manual is for informational use only and is subject to change without notice Part number 1601 9098 AF September 2017 Storage Store the unit indoors in a cool dry place If possible store in the original packaging Follow the storage temperature range outlined in the Specifications To avoid deterioration of electrolytic capacitors power up units that are stored in a de energi...

Page 3: ...iated circuits isolate or disconnect all hazardous live circuits and sources of electric power Failure to shut equipment off prior to removing the power connections could expose you to dangerous voltages causing injury or death All recommended equipment that should be grounded and must have a reliable and un compromised grounding path for safety purposes protection against electromagnetic interfer...

Page 4: ...h if not avoided could result in minor or moderate injury Note Indicates practices not related to personal injury For further assistance For product support contact the information and call center as follows GE Grid Solutions 650 Markland Street Markham Ontario Canada L6C 0M1 Worldwide telephone 1 905 927 7070 Europe Middle East Africa telephone 34 94 485 88 54 North America toll free 1 800 547 86...

Page 5: ...nit withdrawal and insertion 2 9 IP20 Cover optional 2 10 Electrical installation 2 11 Typical Wiring Diagrams 2 12 345 Terminal identification 2 14 Wire range 2 17 RMIO module installation 2 18 Phase sequence and transformer polarity 2 19 Current inputs 2 19 Ground and sensitive ground CT inputs 2 20 Zero sequence CT installation 2 21 Control power 2 21 Contact inputs 2 22 Trip1 and Trip2 output ...

Page 6: ... 25 Upgrading setpoint files to a new revision 3 25 Printing setpoints and actual values 3 26 Printing actual values from a connected device 3 27 Loading setpoints from a file 3 28 Uninstalling files and clearing data 3 28 Upgrading relay firmware 3 29 Loading new relay firmware 3 29 Advanced EnerVista 3 Series Setup features 3 31 Transient recorder Waveform capture 3 31 Protection summary 3 34 Pa...

Page 7: ...5 103 serial communication 6 12 IEC60870 5 104 protocol 6 12 DNP communication 6 12 3 Series IEC 61850 GOOSE details 6 13 Event recorder 6 14 Transient recorder 6 15 Fault report 6 16 Front panel with non programmable LEDs 6 17 Front panel with programmable LEDs 6 18 Installation 6 20 S2 System Setup 6 21 Current sensing 6 21 Power system 6 22 Transformer 6 22 Transformer setup phase magnitude com...

Page 8: ...Trip 6 98 Auxiliary Output Relays 3 to 6 6 100 Virtual inputs 6 101 Remote inputs 6 102 Remote outputs 6 102 S6 Monitoring 6 103 Demand 6 103 Current demand 6 104 RTD temperature monitoring 49T 6 105 7 MAINTENANCE M1 Relay information 7 2 M3 Breaker maintenance 7 4 Trip coil 7 4 Breaker trip counter 7 8 Breaker health 7 10 Reset counters 7 13 M4 Breaker monitor 7 14 M5 Relay maintenance 7 15 Ambie...

Page 9: ... and control Equipped with serial RS485 USB and Ethernet ports as well as a wide selection of protocols such as Modbus DNP3 0 IEC60870 5 103 60870 5 104 IEC 61850 GOOSE the 345 relay is the best in class for either MCCs SCADA or inter relay communications The 345 provides excellent accessibility and transparency with regard to power system conditions and events through both its four line 20 charac...

Page 10: ...relay via the EnerVista 3 Series Setup software for display and diagnostics Phasors Transients and Harmonics Current waveforms are processed four times every cycle with a DC Offset Filter and a Discrete Fourier Transform DFT The resulting phasors have fault current transients and all harmonics removed This results in an overcurrent relay that is extremely secure and reliable one that will not over...

Page 11: ... 1 Functional block diagram 897743A2 CDR 345 RELAY Metering Transient Recorder Event Recorder Fault Report Calculate Restraint Current Calculate Differential Currents Calculate Harmonics 2nd and 5th BLOCK 50P 50G SG 50G SG 51P 51G SG 51G SG 50BF 51_2 50N 51N 87G 87G 87T 50 87 Winding 2 Winding 1 49 50_2 50P 51P 50BF 51_2 50N 51N 50_2 86 49T ...

Page 12: ...egative Sequence Timed Overcurrent 51G SG gndPTOC1 gndPTOC2 hsePTOC1 hsePTOC2 Ground Sensitive Ground Timed Overcurrent 51N ndPTOC1 ndPTOC2 Neutral Timed Overcurrent 51P phsPTOC1 phsPTOC2 Phase Timed Overcurrent 86 Lockout 87G RGF 1 1 Restricted Ground Fault is sometimes coded as 87G REF 87RGF 87N 64R 64REF etc rgfPDIF1 rgfPDIF2 Restricted Ground Fault 87T pcntPDIF1 Percent Differential Descriptio...

Page 13: ...one Instantaneous Differential element two Restricted Ground Fault elements one Thermal Model two Breaker Failure elements two of each Phase Ground and Neutral Instantaneous Overcurrent elements two of each Phase Ground Neutral Timed Overcurrent elements and two Negative Sequence Timed Overcurrent elements Some of the protection elements are common for the transformer protection Percent and Instan...

Page 14: ... CT SECONDARY W1 GND CT PRIMARY W1 GND CT SECONDARY W2 PH CT PRIMARY W2 PH CT SECONDARY W2 GND CT PRIMARY W2 GND CT SECONDARY TRANSFORMER TYPE XFMR RATED LOAD W1 NOM VOLTAGE W1 GROUNDING W2 NOM VOLTAGE W2 GROUNDING XFMR PERCENT DIFF PH TOC1 FUNCTION GND TOC1 FUNCTION PH IOC1 FUNCTION GND IOC1 FUNCTION ٕ SETPOINTS S1 RELAY SETUP S2 SYSTEM SETUP S3 PROTECTION S4 CONTROLS S5 INPUTS OUTPUTS S6 MONITOR...

Page 15: ...current input G1 1 A standard ground CTs Winding 1 1 A Winding 2 1 A G5 5 A standard ground CTs Winding 1 5 A Winding 2 5 A S0 1 A and 5 A configurable sensitive ground current input S1 1 A sensitive ground CTs Winding 1 1 A Winding 2 1 A S5 5 A sensitive ground CTs Winding 1 5 A Winding 2 5 A Power Supply L 24 to 48 V DC H 110 to 250 V DC 110 to 230 V AC Current Protectionc c Current protection o...

Page 16: ...N N Phase Currents P1 1 A 3 phase CTs Winding 1 1 A Winding 2 1 A P5 5 A 3 phase CTs Winding 1 5 A Winding 2 5 A Ground Currentsa a Ground current options G1 G5 must match the corresponding P1 P5 Phase currents G1 1 A standard ground CTs Winding 1 1 A Winding 2 1 A G5 5 A standard ground CTs Winding 1 5 A Winding 2 5 A S1 1 A sensitive ground CTs Winding 1 1 A Winding 2 1 A S5 5 A sensitive ground...

Page 17: ... time to the operate times listed below Password security PASSWORD SECURITY Master Password 8 to 10 alpha numeric characters Settings Password 3 to 10 alpha numeric characters for local and remote access Control Password 3 to 10 alpha numeric characters for local and remote access Protection PHASE NEUTRAL GROUND NEGATIVE SEQUENCE TIMED OVERCURRENT 51P 51N 51G 51_2 Pickup Level 0 05 to 20 00 x CT i...

Page 18: ... 001 x CT Dropout Level 97 of Pickup I 0 1 x CT Pickup 0 002 x CT I 0 1 x CT Time Delay 0 00 to 300 00 sec in steps of 0 01 Operate Time 30 ms 60Hz I 2 0 x PKP No time delay 35 ms 50Hz I 2 0 x PKP No time delay Time Delay Accuracy 1 or 1 cycle whichever is greater Time Delay selected Level Accuracy per CT input TRANSFORMER THERMAL PROTECTION 49 Current RMS current max Ia Ib Ic Pickup Accuracy per ...

Page 19: ...figurable 1 A or 5 A must be specified with order P0G0 Nominal frequency 50 60 Hz Burden 0 1 VA at rated load Accuracy at nominal frequency 3 10 mA or 20 of reading from 0 02 to 0 19 CT whichever is greater CT withstand 1 second at 100 A 1 A option 1 second at 400 A 5 A or universal CT option 2 seconds at 40 rated current continuous at 3 rated current SENSITIVE GROUND CURRENT INPUT CT Primary 1 to...

Page 20: ...eader relay name order code firmware revision Content event number date of event cause of event per phase current ground current sensitive ground current neutral current ground differential current negative sequence current restraint current per phase differential current per phase differential second harmonic current thermal capacity Data Storage RAM battery backed up retained for 3 days CLOCK Se...

Page 21: ... to 1 cycle Timer 1 Timer 2 Level Accuracy per CT input Reset Time 14 ms typical at 2 x pickup at 60 Hz 16 ms typical at 2 x pickup at 50 Hz LOCKOUT Function Latch Trip command to Relay 1 TRIP Block Close to Relay 2 CLOSE Operation Any protection element AMBIENT TEMPERATURE High Temperature Pickup 20 C to 80 C in steps of 1 C Low Temperature Pickup 40 C to 20 C in steps of 1 C Time Delay 1 to 60 m...

Page 22: ... Pickup 1 to 250o C in steps of 1o C Pickup Hysteresis 2o C Time Delay 3 sec Elements Trip and Alarm RTD TROUBLE ALARM 49T RTD Trouble Alarm 50o C or 250o C Inputs CONTACT INPUTS Inputs 10 Selectable thresholds 17 33 84 166 VDC 10 Recognition time 1 2 cycle Debounce time 1 to 64 ms selectable in steps of 1 ms Maximum input voltage continuous current draw 300 VDC 2 mA connected to Class 2 source Ty...

Page 23: ...DC Trickle current 1 to 2 5 mA FORM C RELAYS Configuration 5 five 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 A Break AC inductive 720 VA 250 VAC Pilot duty A300 Break AC resis...

Page 24: ...ol Modbus RTU DNP 3 0 IEC 60870 5 103 Maximum distance 1200 m 4000 feet Isolation 2 kV ETHERNET COPPER Modes 10 100 MB auto detect Connector RJ 45 Protocol Modbus TCP DNP3 0 IEC 60870 5 104 IEC 61850 GOOSE IEC 61850 ETHERNET FIBER Fiber type 100 MB Multi mode Wavelength 1300 nm Connector MTRJ Protocol Modbus TCP DNP3 0 IEC 60870 5 104 IEC 61850 GOOSE IEC 61850 Transmit power 20 dBm Receiver sensit...

Page 25: ...z 10V m Voltage interruption and Ripple DC IEC 60255 26 IEC 60255 4 11 15 ripple 200ms interrupts Radiated Conducted Emissions CISPR11 CISPR22 IEC 60255 26 Section 7 1 2 7 1 3 Class A Sinusoidal Vibration IEC 60255 21 1 Class 1 Shock Bump IEC 60255 21 2 Class 1 Seismic IEC 60255 21 3 Class 2 Power magnetic Immunity IEC 60255 26 IEC 61000 4 8 1000 A m 100 A m 30A m 300 A m Voltage Dip interruption ...

Page 26: ...ght gross 4 0 kg 8 6 lbs DRAWOUT UNIT Weight net 3 9 kg 8 6 lbs Weight gross 5 0 kg 11 0 lbs Applicable Council Directive According to Low voltage directive 2014 35 EU CE compliance EMC Directive 2014 30 EU UL 508 North America cULus UL 1053 C22 2 No 14 EAC Machines and Equipment TR CU 010 2011 Lloyd s Register Rules and Regulations for the Classifications of Ships Marine Applications ENV2 ENV3 IE...

Page 27: ...OPERATING ENVIRONMENT Ambient temperatures Storage Shipping 40o C to 85o C Operating 40o C to 60o C Humidity Operating up to 95 non condensing 55o C As per IEC60068 2 30 Variant 2 6 days Altitude 2000 m max Pollution Degree II Overvoltage Category III Ingress Protection IP54 Front IP20 cover optional Noise 0 dB ...

Page 28: ...1 20 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SPECIFICATIONS CHAPTER 1 INTRODUCTION ...

Page 29: ...llation Mechanical installation This section describes the mechanical installation of the 345 system including dimensions for mounting and information on module withdrawal and insertion Dimensions The dimensions of the 345 are on the following pages Additional dimensions for mounting and panel cutouts are shown in the following sections ...

Page 30: ...RANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL MECHANICAL INSTALLATION CHAPTER 2 INSTALLATION Figure 2 1 345 dimensions Drawout unit PP PP PP PP 1 1 6 72 527 7 6 1 7 5 287 81 7 172 37 9 81 7 PP PP 1 0 7 7 6 PP ...

Page 31: ...s for reference only The text can vary 6 23 158 2mm 7 98 202 7mm 1 47 37 3mm 7 88 200 2mm 6 82 173 2mm 3 96 100 6mm mm TechnicalSupport Worldwide 19059277070 NorthAmerica 18005478629 www gegridsolutions com multilin 650MarklandStreet Markham ON CanadaL6C0M1 MFG Date Transformer Protection System Mar 11 2016 MADE IN CANADA LISTED C US L U E83849 IND CONT EQ 52TL R g Model 345 E P1 G1 H E S N N 2E N...

Page 32: ...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 mounting Drawout 8 32X3 8IN P HD PHIL BLK GE PART 1408 0306 QTY 8 TIGHTENING TORQUE 15 IN LB ...

Page 33: ... TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 2 5 Figure 2 5 Standard Panel mounting Non drawout Figure 2 6 Depth Reducing collar optional 8 32 x 3 8 P HD PHIL BLK GE P N 1408 0306 QTY 8 Tightening Torque 15 in lb 1 7 Nm Panel with Cutout NDO unit ...

Page 34: ... panel using 4 screws as shown above Figure 2 7 Mounting tabs optional 1 From the front of the panel slide the empty case into the cutout until the bottom tab clicks into place see above 2 From the rear of the panel screw the case into the panel at the 8 screw positions shown above 3 If added security is required bend the retaining V tabs outward to about 90 These tabs are located on the sides of ...

Page 35: ...imensions Figure 2 9 RMIO DIN rail mounting Base Expansion units 5 350 0 010 135 9 mm 0 25mm 4 100 0 010 104 1 mm 0 25 mm 0 200 5 1 mm Φ 6 900 0 010 175 3 mm 0 25 mm 6 000 0 010 152 4 mm 0 25 mm 4 000 0 010 101 6 mm 0 25 mm C L C L SNAP IN THE DIN CLIPS QTY 4 FOR DIN RAIL MOUNTING 0 30 7 6 mm 1 38 35 1 mm DIN 3 RAIL 853726A1 CDR ...

Page 36: ...ansion Unit screw mounting MEETS VIBRATION REQUIREMENT OF IEC 60255 SEC 21 1 21 2 21 3 2 250 57 15 mm 6 32 THREADED HOLE QTY 2 4 100 104 14 mm 853727A1 CDR 6 32X1 2 FT FLAT HEAD PHIL ZINC QTY 2 SUPPLIED GE PART 1406 0117 TIGHTENING TORQUE 10 lb in 0 356 9 03 mm 0 672 17 06 mm 1 500 38 10 mm EXPANSION UNIT OUTLINE 2 285 58 04 mm 6 32 THREADED HOLE QTY 2 853755A1 cdr ...

Page 37: ... and insertion diagram KEEP THE HANDLE IN ITS ROTATED POSITION UNTIL THE DRAW OUT UNIT IS INSERTED COMPLETELY PUSH THE HANDLE DOWN AND TIGHTEN THE SCREW UNTIL THE HANDLE IS PARALLEL WITH THE FRONT PANEL SURFACE THE HANDLE MUST BE ROTATED 90 WHILE SLIDING THE DRAW OUT UNIT INTO THE CAPTIVE UNIT 8 32X3 8IN P HD PHIL BLK GE PART 1408 0306 QTY 8 TIGHTENING TORQUE 15 IN LB ...

Page 38: ...following order A Remove the 2 mounting screws near letters A and C of label ABC item 2 and mount 2 standoffs B Remove the 2 mounting screws near the letters B and E of label ABCDE item 3 and mount 2 standoffs 2 Place the IP20 cover item 4 and secure it with 4 screws item 5 using the suggested tightening torque of 8lb in NOTE NOTE Make sure the device terminals are wired before placing the cover U...

Page 39: ...ICAL INSTALLATION 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 2 11 Electrical installation This section describes the electrical installation of the 345 system including typical wiring diagrams and terminal identification ...

Page 40: ...T USB F5 F4 F3 RS485 IRIG B F1 F2 COMMUNICATIONS CONTROL POWER A B C E5 D5 E6 D6 E7 D7 E8 D8 IA IA IB IB IC IC IG IG 7 CRITICAL FAILURE RELAY 3 AUXILIARY 4 AUXILIARY 5 AUXILIARY 6 AUXILIARY 2 TRIP 1 TRIP OPTIONAL Front Panel Rear Panel 345 Transformer Protection System 52a 52b Winding 1 Breaker Aux Contacts E9 D9 E10 D10 E11 D11 E12 D12 IA IA IB IB IC IC IG IG WINDING 1 WINDING 2 52a 52b Winding 2...

Page 41: ...C4 C3 RS485 IRIG B C1 C2 COMMUNICATIONS CONTROL POWER A B C E5 D5 E6 D6 E7 D7 E8 D8 IA IA IB IB IC IC IG IG 7 CRITICAL FAILURE RELAY 3 AUXILIARY 4 AUXILIARY 5 AUXILIARY 6 AUXILIARY 2 TRIP 1 TRIP OPTIONAL Front Panel Rear Panel 345 Transformer Protection System 52a 52b Winding 1 Breaker Aux Contacts E9 D9 E10 D10 E11 D11 E12 D12 IA IA IB IB IC IC IG IG WINDING 1 WINDING 2 52a 52b Winding 2 Breaker ...

Page 42: ...TE NOTE When installing two lugs on one terminal both lugs should 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 16 Orient the lugs correctly Figure 2 17 CORRECT INSTALLATION METHOD SCREW WASHER LOWER TERMINAL DIVIDER TERMINAL BLOCK 1 2 3 ...

Page 43: ...CHAPTER 2 INSTALLATION ELECTRICAL INSTALLATION 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 2 15 Figure 2 18 INCORRECT INSTALLATION METHOD lower lug reversed ...

Page 44: ...GND CT W1 PHASE A CT W1 PHASE B CT W1 PHASE C CT W1 GND CT W2 PHASE A CT W2 PHASE B CT W2 PHASE C CT W2 GND CT IRIG B IRIG B RS485 RS485 RS485 COM CHASSIS GND RESERVED RESERVED POWER SUPPLY CHASSIS GND W1 TRIP COM W2 TRIP N O W2 TRIP OPTV AUX 3 COM AUX 4 N C AUX 4 N O AUX 5 COM AUX 6 N C AUX 6 N O CRIT FAIL COM POWER SUPPLY W1 TRIP N O W1 TRIP OPTV W2 TRIP COM AUX 3 N C AUX 3 N O AUX 4 COM AUX 5 N...

Page 45: ...e tighten to 12 in lb 1 35 N m The uncovered communications cable shield connected to the common terminal should not exceed 1 2 5 cm for proper EMC shielding of the communications cable INPUT 1 INPUT 2 INPUT 3 INPUT 4 INPUT 5 INPUT 6 INPUT 7 INPUT 8 INPUT 9 INPUT 10 INPUT COM CHASSIS GND 1 2 3 4 5 6 7 8 9 10 11 12 W1 PHASE A CT W1 PHASE B CT W1 PHASE C CT W1 GND CT W2 PHASE A CT W2 PHASE B CT W2 P...

Page 46: ...e it should be mounted away from high current conductors or sources of strong magnetic fields Figure 2 21 RMIO unit showing 2 IO_G modules Figure 2 22 RMIO terminal identification with 4 IO_G modules Tx Rx IO_G IO_G RCU PSU P S U L N G Com Port Common B1 B2 B3 14 13 12 11 10 9 8 7 6 5 4 3 2 1 14 13 12 11 10 9 8 7 6 5 4 3 2 1 896750 cdr IO_G IO_G 14 13 12 11 10 9 8 7 6 5 4 3 2 1 14 13 12 11 10 9 8 ...

Page 47: ... Current transformers with 1 to 6000 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 will correctly measure up to 20 times the current input s nominal rating Time overcurrent curves ...

Page 48: ...tended for use with a CT in a source neutral of a high impedance grounded system or on ungrounded systems On ungrounded systems it is connected residually with the phase current inputs In this case the SENSTV GND CT PRIMARY setpoint should be programmed to a value equal to the PHASE CT PRIMARY setpoint The sensitive ground current input can be connected to a Zero Sequence CT for increased sensitiv...

Page 49: ...on the relay specifies its order code or model number The installed power supply s operating range will be one of the following LO 24 to 48 V DC Range 20 to 60 V DC HI 125 to 250 V DC 120 to 240 V AC Range 84 to 250 V DC 60 to 300 V AC 50 and 60 Hz CAUTION The relay should be connected directly to the ground bus using the shortest practical path A tinned copper braided shielding and bonding cable ...

Page 50: ...d A wet contact has one side connected to the positive terminal of an external DC power supply The other side of this contact is connected to the required contact input terminal In addition the negative side of the external source must be connected to the relay s DC negative rail at Terminal C11 The maximum external source voltage for this arrangement is 300 V DC Figure 2 27 Wet contact connection...

Page 51: ...on Form A output relays 1 Trip and 2 Trip The voltage monitor is connected across each of the two Form A contacts and the relay effectively detects healthy current through the circuit In order to do this an external jumper must be connected between terminals A2 and A3 for 1 Trip coil monitoring or and B4 and B5 for 2 Trip coil monitoring As long as the current through the Voltage Monitor is above ...

Page 52: ...tacts are shown when the breaker is open Figure 2 29 Relay 1 Trip and Relay 2 Trip circuits with voltage monitoring V A2 B3 A3 Trip Coil DC DC Output Relay 1 TRIP 52a contact V B4 A4 B5 DC Output Relay 2 TRIP 52a contact 897785 cdr Trip Coil DC V A2 B3 A3 Trip Coil DC DC Output Relay 1 TRIP 52a contact External jumper 897786 cdr V B4 A4 B5 DC Output Relay 2 TRIP 52a contact External jumper Trip Co...

Page 53: ...erminals of each RS485 port are tied together and grounded only once at the master or at the 345 Failure to do so may result in intermittent or failed communications The source computer PLC SCADA system should have similar transient protection devices installed either internally or externally Ground the shield at one point only as shown in the figure above to avoid ground loops Correct polarity is...

Page 54: ...itude modulated AM form The type of form is auto detected by the 345 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 The uncovered communications cable shield connected to the common terminal should not exceed 1 2 5 cm for p...

Page 55: ...eeder Protection System Interfacing via the relay keypad and display Interfacing via the EnerVista 3 Series Setup software This section provides an overview of the interfacing methods available with the 345 using the relay control panels and EnerVista 3 Series Setup software For additional details on interface parameters for example settings actual values etc refer to the individual chapters ...

Page 56: ...panel interface Figure 3 1 Transformer Protection System Front Panel ENTER MENU ESCAPE RESET 897351A1 cdr USB GE Multilin SR345 Transformer Protection System IN SERVICE TROUBLE SETPOINT GROUP 1 SETPOINT GROUP 2 TRIP ALARM PICKUP MAINTENANCE W1 BREAKER OPEN W1 BREAKER CLOSED W1 BREAKER OPEN W2 BREAKER OPEN W2 BREAKER CLOSED ...

Page 57: ...s indicators control keys and a USB program port The display and status indicators show the relay information automatically The control keys are used to select the appropriate message for entering setpoints or displaying measured values The USB program port is also provided for connection with a computer running the EnerVista 3 Series Setup software ୠ ඓ ඕ ENTER MENU ESCAPE RESET 897841A1 cdr USB G...

Page 58: ...ages are organized into a Main Menu pages and sub pages There are four main menus labeled Actual Values Quick Setup Setpoints and Maintenance Pressing the MENU key followed by the MESSAGE key scrolls through the five Main Menu headers which appear in sequence as follows Figure 3 3 The five Main Menu headers Pressing the MESSAGE key or the ENTER key from these Main Menu pages will display the corre...

Page 59: ...ey also decrement and increment numerical setpoints The RESET key resets any latched conditions that are not currently active This includes resetting latched output relays latched Trip LEDs breaker operation failure and trip close coil failures The Autoreclose Scheme is also reset with the shot counter being returned to zero and the lockout condition being cleared The MESSAGE and MESSAGE keys scro...

Page 60: ...of the relay features The indicator will turn off if no pickup condition is detected MAINTENANCE Orange This LED may indicate both breaker or relay maintenance depending on the programmed maintenance elements The LED will turn on upon operation of a maintenance element W1 BREAKER OPEN Red Green Orange Off programmable color default Green This LED is lit when the winding 1 breaker is detected open ...

Page 61: ...on Breaker Control or communications in all cases after the fault condition has cleared ALARM Orange This LED will flash upon detection of an alarm condition with element functions selected as alarm The LED will automatically turn off if the alarm condition clears The LED will remain steady ON if the function of the operated protection was selected as latched alarm LED 1 Red programmable source si...

Page 62: ...GET MESSAGES where they can be reviewed If the target messages have not been cleared before the user presses a pushbutton different from RESET they will reappear on the screen after the time specified under the SETPOINTS S1 RELAY SETUP FRONT PANEL MESSAGE TIMEOUT setting that will start timing out from the last pressed pushbutton The following shows the format of a typical Target Message Figure 3 ...

Page 63: ...se of major self test failure Record the major self test failure in the Event Recorder Figure 3 6 Typical Self test warning Table 3 1 Minor Self test Errors Self test Error Message Latched Target Message Description of Problem How Often the Test is Performed What to do MAINTENANCE ALERT IRIG B Failure No A bad IRIG B input signal has been detected Every 5 seconds Ensure IRIG B cable is connected c...

Page 64: ...l communications board does not match the order code Every 5 seconds Contact factory MAINTENANCE ALERT RMIO Mismatch No RMIO Module is not validated communications with the RMIO module are lost or interrupted Every 5 seconds Validate the RMIO Module check CANBUS communication Self test Error Message Latched Target Message Description of Problem How Often the Test is Performed What to do UNIT FAILU...

Page 65: ...ult flash message time is 4 seconds Figure 3 7 Typical Flash message SETPOINT STORED This flash message is displayed in response to the ENTER key while on any setpoint message see example above The edited value was stored as entered COMMAND EXECUTED This flash message is displayed in response to executing a command ON OFF YES NO etc INVALID PASSWORD This flash message appears upon an attempt to en...

Page 66: ...ow option is accessed from the Tree which launches on clicking EnerVista 3 Series Setup Software Although settings can be entered manually using the control panel keys a PC can be used to download setpoints through the communications port The EnerVista 3 Series Setup software is available from GE Multilin to make this as convenient as possible With EnerVista 3 Series Setup running it is possible t...

Page 67: ...ws 7 32 bit or 64 bit Windows 8 1 32 bit or 64 bit Windows 10 32 bit or 64 bit 1 GB of RAM 2 GB recommended 500 MB free hard drive space 1 GB recommended 1024 x 768 display 1280 x 800 recommended The EnerVista 3 Series Setup software can be installed from either the GE EnerVista CD or the GE Multilin website at http www gegridsolutions com multilin Installing the EnerVista 3 Series Setup software ...

Page 68: ...ss 7 Select the complete path including the new directory name where the EnerVista 3 Series Setup software will be installed 8 Click on Next to begin the installation The files will be installed in the directory indicated the USB driver will be loaded into the computer and the installation program will automatically create icons and add EnerVista 3 Series Setup software to the Windows start menu 9...

Page 69: ...communicate from your computer to the 345 Relay using the USB port 10 Plug the USB cable into the USB port on the 345 Relay then into the USB port on your computer 11 Launch EnerVista 3 Series Setup from LaunchPad 12 In EnerVista Device Setup 13 Select USB as the Interface type 14 Select 345 Relay as the USB device ...

Page 70: ...e GE Multilin F485 converter will be required Refer to the F485 manual for additional details To configure the relay for Ethernet communications see Configuring Ethernet Communications below 1 Install and start the latest version of the EnerVista 3 Series Setup software available from the GE Multilin web site See the previous section for the installation procedure 2 Click on the Device Setup butto...

Page 71: ...st window or Online window located in the top left corner of the main EnerVista 3 Series Setup window The 345 Site Device has now been configured for USB communications Proceed to Connecting to the Relay below to begin communications Using the Quick Connect feature The Quick Connect button can be used to establish a fast connection through the front panel USB port of a 345 relay or through the Eth...

Page 72: ...USB is selected in the interface drop down list Select SR3 Relay and press the Connect button Ethernet can also be used as the interface for Quick Connect as shown above When connected a new Site called Quick Connect will appear in the Site List window The 345 Site Device has now been configured via the Quick Connect feature for either USB or Ethernet communications Proceed to Connecting to the Re...

Page 73: ... the upper left list 5 Click the Add Device button to define the new device 6 Enter the desired name in the Device Name field and a description optional 7 Select Ethernet from the Interface drop down list This will display a number of interface parameters that must be entered for proper Ethernet functionality 8 Enter the IP address slave address and Modbus port values assigned to the 345 relay fro...

Page 74: ...oints Maintenance 3 Expand the SETTINGS RELAY SETUP list item and double click on Front Panel to open the Front Panel settings window as shown 4 The Front Panel settings window opens with a corresponding status indicator on the lower left of the EnerVista 3 Series Setup window 5 If the status indicator is red verify that the serial USB or Ethernet cable is properly connected to the relay and that ...

Page 75: ...box This will display three arrows two to increment decrement the value and another to launch the numerical keypad 4 Clicking the arrow at the end of the box displays a numerical keypad interface that allows the user to enter a value within the setpoint range displayed near the top of the keypad Click to exit from the keypad and keep the new value Click on X to exit from the keypad and retain the ...

Page 76: ...rce label This opens a Quick Navigation window 4 Select a Type for the LED Latched or Self Reset and a Color if applicable 5 Repeat this process for all programmable LED Source Type and Color parameters 6 In the Setpoint S1 Relay Setup Front Panel dialog box click Save to save the values into the 345 Click YES to accept any changes Click Restore to retain previous values Click Default to restore D...

Page 77: ... 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 saving the settings when complete Creating editing settings files while connected to a communicating relay then saving them to the relay when complete Settings fil...

Page 78: ... defined and configured as shown in Connecting EnerVista 3 Series Setup to the Relay above 2 Select the desired device from the site list 3 Select the Online Read Device Settings from Device 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 will request the name and destination ...

Page 79: ... 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 and path to store the file or select any displayed file name to replace an existing file All 345 setpoint files sho...

Page 80: ...ity of setpoint files For current order codes refer to the GE Multilin website at http www gegridsolutions com multilin 7 Enter any special comments about the setpoint file in the Description field 8 Select the desired firmware version from the New File Version field 9 When complete click OK to convert the setpoint file to the desired revision See Loading Setpoints from a File below for instructio...

Page 81: ...selecting the Print Device Information or Print Settings File options Printing actual values from a connected device A complete list of actual values can also be printed from a connected device with the following procedure 1 Establish communications with the desired 345 device 2 From the main window select the Online Print Device Information menu item 3 The Print Export Options dialog box will app...

Page 82: ...file version 3 Right click on the selected file and select the Write Settings File to Device item 4 Select the target relay from the list of devices shown and click Send If there is an incompatibility an error of the following type will occur If there are no incompatibilities between the target device and the settings file the data will be transferred to the relay An indication of the percentage c...

Page 83: ...Setpoints Files for details on saving relay setpoints to a file Loading new relay firmware Loading new firmware into the 345 flash memory is accomplished as follows 1 Connect the relay to the local PC and save the setpoints to a file as shown in Downloading and Saving Setpoints Files 2 Select the Maintenance Update Firmware menu item 3 The EnerVista 3 Series Setup software will request the new fir...

Page 84: ...ll not be in service and will require 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 back into the relay See Loading Setpoints from a File for details Modbus addresses assigned to firmware modules features settings and corresponding data items i e default valu...

Page 85: ... Trigger Waveform to trigger a waveform capture Waveform file numbering starts with the number zero in the 345 so that the maximum trigger number will always be one less than the total number of triggers available Click on the Save to File button to save the selected waveform to the local PC A new window will appear requesting the file name and path One file is saved as a COMTRADE file with the ex...

Page 86: ...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 87: ...nd 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 will reappear based on the selected graph attributes To view a vector graph of the quantities contained in the waveform capture press the Vector Display button to display the following window Preference Button ...

Page 88: ...erent settings from Grouped Elements Control Elements and Maintenance screens Protection Summary Screen allows the user to view the output relay assignments for the elements modify the output relay assignments for the elements view the enable disable status of Control Elements navigate to the respected Protection Element screen on a button click An example of the Protection Summary screen follows ...

Page 89: ...CHAPTER 3 INTERFACES SOFTWARE SETUP 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL 3 35 ...

Page 90: ...e is to be used the user must first change the Master Password from the initial Null setting this can only be done over communications not from the front panel keypad The new Master Password must be 8 to 10 characters in length and must have minimum 2 letters and 2 numbers The letters are case sensitive Set Change Master Password to Yes to enable password security After entering a valid Master Pas...

Page 91: ...been changed from the initial NULL value to a valid one Local Passwords must be 3 to 10 characters in length 6 If any Remote password has never been set that level will not be attainable except when logged in as the Master Level The same logic applies to the Local passwords 7 When passwords have been set the user will be prompted to enter the appropriate password depending on the interface being u...

Page 92: ...3 38 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL SOFTWARE SETUP CHAPTER 3 INTERFACES ...

Page 93: ...for easy reference as shown below Figure 4 1 Main Actual Values menu A2 METERING WINDING 1 CURRENTS XFMR THERM CAP WINDING 2 CURRENTS XFMR DIFF CURRENTS ٕ A1 STATUS CLOCK CONTACT INPUTS OUTPUT RELAYS LOGIC ELEMENTS VIRTUAL INPUTS REMOTE INPUTS REMOTE OUTPUTS C INPUTS SUMMARY OUT RELAYS SUMMARY LOGIC ELEM SUMMARY GOOSE STATUS GOOSE HDR STATUS ٕ ACTUAL VALUES A1 STATUS A2 METERING A3 RECORDS A4 TARG...

Page 94: ... BRK CI 2 Contact Input 2 OFF Range Off On The status of this contact shows the W1 breaker close open state when wired to a 52b breaker auxiliary contact 52a W2 BRK CI 3 Contact Input 3 OFF Range Off On The status of this contact shows the W2 breaker close open state when wired to a 52a breaker auxiliary contact 52b W2 BRK CI 4 Contact Input 4 OFF Range Off On The status of this contact shows the ...

Page 95: ... is in service Logic elements PATH ACTUAL VALUES A1 STATUS LOGIC ELEMENTS LOGIC ELEMENT 1 to 16 OFF Range Off On The state ON or OFF for each logic element depends on its programmed logic triggering inputs blocking inputs plus any pickup and or reset time delay Virtual inputs The state of all active virtual inputs is displayed here PATH ACTUAL VALUES A1 STATUS VIRTUAL INPUTS VIRTUAL INPUTS 1 to 32...

Page 96: ...ct functioning of the 345 relay This output relay shows the status ON when the 345 relay is powered up and set to Ready and no self test alarms are active under SETPOINTS S1 RELAY SETUP S1 INSTALLATION RELAY STATUS Logic elements summary PATH ACTUAL VALUES A1 STATUS LOGIC ELEM SUMMARY LOGIC ELEM SUMMARY This display shows a summary of the states of all logic elements 52a OFF CI 5 OFF 52b OFF CI 6 ...

Page 97: ...e is an error in the CID file with no 61850 services operative A corrected CID file must be sent to the relay using the IEC 61850 Configurator Ready there is a validated CID file in the SCL validated directory with all 61850 services operative Default CID no CID file was found in either SCL notvalidated or SCL validated so a default CID files was loaded After the next reboot the default CID file w...

Page 98: ...ing the Up Down keys the relay shows one by one all metered values as follows Winding 1 Current Path ACTUAL VALUES A2 METERING WINDING 1 CURRENT W1 PH A CURRENT 0 0 A 0o lag Range 1 to 6000 A 0 to 359o lag W1 PH B CURRENT 0 0 A 0o lag Range 1 to 6000 A 0 to 359o lag W1 PH C CURRENT 0 0 A 0o lag Range 1 to 6000 A 0 to 359o lag W1 NTRL CURRENT 0 0 A 0o lag Range 1 to 6000 A 0 to 359o lag W1 GND CURR...

Page 99: ...lag Range 1 to 600 A 0 to 359o lag W2 NEG SEQ CURRENT 0 0 A 0o lag Range 1 to 6000 A 0 to 359o lag W2 GND DIFF CURRENT 0 00 x CT 0o lag Transformer Differential and Restraint Currents Path ACTUAL VALUES A2 METERING XFMR DIFF CURRENTS PH A DIFF CURRENT 0 00 x CT 0o lag PH A RESTR CURRENT 0 00 x CT 0o lag DIFF 2 HARM PH A 0 0 f0 DIFF 5 HARM PH A 0 0 f0 PH B DIFF CURRENT 0 00 x CT 0o lag PH B RESTR C...

Page 100: ...mand calculations are based on the measurement type selected under S6 MONITORING 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 A3 RECORDS CLEAR RECORDS command Path A2 METERING CURR...

Page 101: ...D T MM DD YY HH MM SS CUR DEMAND 1 PH B D T MM DD YY HH MM SS CUR DEMAND 1 PH C D T MM DD YY HH MM SS Clear current demand 1 2 Path ACTUAL VALUES A2 METERING CLEAR CURR DEMAND 1 2 CLEAR CURR DEMAND 1 2 NO Range No Yes When set to YES pressing the ENTER key will clear all current demand 1 or current demand 2 data ...

Page 102: ...intained even in the case where relay control power is lost Shown below is an example of an event record caused by a Breaker Open operation and the recorded information at the time of this record PATH ACTUAL VALUES A3 RECORDS EVENT RECORDS Table 4 1 Example of Event Record A3 EVENT REC T 5655 E5655 Jan 05 10 Ph IOC1 Trip OP 17 32 28 376 E5655 TRIP Ph IOC1 Trip OP W1 Ia x CT W1 0 08 x CT 0 Lag E565...

Page 103: ...W2 0 00 x CT E5655 TRIP Ph IOC1 Trip OP W2 Igr x CT W2 0 00 x CT E5655 TRIP Ph IOC1 Trip OP W2 I_2 x CT W1 0 00 x CT E5655 TRIP Ph IOC1 Trip OP Ph A Diff x CT W1 0 08 E5655 TRIP Ph IOC1 Trip OP Ph BDiff x CT W1 0 00 E5655 TRIP Ph IOC1 Trip OP Ph C Diff x CT W1 0 00 E5655 TRIP Ph IOC1 Trip OP Ph A Rest x CT W1 0 00 E5655 TRIP Ph IOC1 Trip OP Ph B Rest x CT W1 0 00 E5655 TRIP Ph IOC1 Trip OP Ph C Re...

Page 104: ... up Trip Events TRIP These are events that occur when a breaker trip is initiated Alarm and Latched Alarm Events ALARM These are events that occur when an alarm is initiated Control Events CONTROL These are events that occur when a control element is activated Dropout Events DROPOUT These are events that occur when a protection element drops out after a corresponding pickup event Contact Input Eve...

Page 105: ...345 EP5G5HEMNN2EDN NAME XFMR 5 F W REVISION 2 20 W1 PH A CURRENT 0 0 A 0o lag W1 PH B CURRENT 0 0 A 0o lag W1 PH C CURRENT 0 0 A 0o lag W1 NTRL CURRENT 0 0 A 0o lag W1 GND CURRENT 0 0 A 0o lag W2 PH A CURRENT 0 0 A 0o lag W2 PH B CURRENT 0 0 A 0o lag W2 PH C CURRENT 0 0 A 0o lag W2 NTRL CURRENT 0 0 A 0o lag W2 GND CURRENT 0 0 A 0o lag PH A DIFF CURRENT 0 00 x CT 0o lag PH A RESTR CURRENT 0 00 x CT...

Page 106: ...d each of the RTD temperature values is captured For each RTD if the captured RTD temperature value is greater than the RDT maximum temperature already stored the RDT maximum temperature is set to this latest captured RTD temperature value The RTD maximum temperature values are maintained in non volatile memory to carry over a relay power interruption Clear learned data CLEAR LEARNED DATA No Range...

Page 107: ...lear all transient records Clear thermal capacity record PATH ACTUAL VALUES A3 RECORDS CLEAR THERM CAP CLEAR No Range No Yes When set to Yes pressing the ENTER key will clear all thermal capacity records Clear fault report PATH ACTUAL VALUES A3 RECORDS CLEAR FAULT REPORT CLEAR No Range No Yes When set to Yes pressing the ENTER key will clear all fault reports ...

Page 108: ...when the respective element operates with the element function set to TRIP or LATCHED ALARM The message will stay on the display after the condition clears and will disappear upon Reset command If the element function is selected to ALARM or CONTROL the message will disappear from the display when the condition causing operation clears The Breaker Open and Breaker Close messages will appear on the...

Page 109: ...he 200 ms time delay expires the display shows the following message only A4 TARGET MESSAGES Ph IOC1 Alarm STATE OP Example 3 Phase IOC1 Settings PH IOC1 FUNCTION Alarm PH IOC1 PICKUP 1 00 x CT PH IOC1 DELAY 0 20 s When current greater than the IOC1 pickup level is applied the 345 display shows the following target message A4 TARGET MESSAGES Ph IOC1 Alarm STATE PKP After the 200 ms time delay expi...

Page 110: ...4 18 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL A4 TARGET MESSAGES CHAPTER 4 ACTUAL VALUES ...

Page 111: ... can be easily set NOTE NOTE Ensure the relay is in Relay Ready state before using Quick Setup Figure 5 1 Quick Setup menu ACTUAL VALUES COMMANDS QUICK SETUP SETPOINTS MAINTENANCE QUICK SETUP RELAY STATUS NOMINAL FREQUENCY W1 PH CT PRIMARY W1 PH CT SECONDARY W1 GND CT PRIMARY W1 GND CT SECONDARY W2 PH CT PRIMARY W2 PH CT SECONDARY W2 GND CT PRIMARY W2 GND CT SECONDARY TRANSFORMER TYPE XFMR RATED L...

Page 112: ...W1 GND SGND CT PRIMARY Range 1 A to 6000 600 A in steps of 1 Default 5 A W2 PH CT PRIMARY Range 1 A to 6000 A in steps of 1 Default 5 A W2 GND SGND CT PRIMARY Range 1 A to 6000 600 A in steps of 1 Default 5 A TRANSFORMER TYPE Range Refer to above Transformer Types table Default Y y0 XFMR RATED LOAD Range 0 00 to 200 00 MVA in steps of 0 01 MVA Default 5 0 MVA W1 NOM VOLTAGE Range 0 01 to 250 00 kV...

Page 113: ...2 Range 50 to 100 in steps of 1 Default 95 PH TOC1 FUNCTION Range Disabled Trip Latched Alarm Alarm Default Disabled PHASE CT INPUT Range CT W1 CT W2 Default CT W1 PH TOC1 PICKUP Range 0 05 to 20 00 x CT in steps of 0 01 x CT Default 1 00 x CT PH TOC1 CURVE Range ANSI Extremely Very Moderately Normally Inverse Definite Time IEC Curve A B C and Short Inverse IAC Extremely Very Inverse Short Default...

Page 114: ... 00 RLY1 TRIP W1 BKR Range Do not operate Operate Default Do not operate RLY2 TRIP W2 BKR Range Do not operate Operate Default Do not operate PH IOC1 FUNCTION Range Disabled Trip Latched Alarm Alarm Default Disabled PH CT INPUT Range CT W1 CT W2 Default CT W1 PH IOC1 PICKUP Range 0 05 to 20 00 x CT in steps of 0 01 x CT Default 1 00 x CT RLY1 TRIP W1 BKR Range Do not operate Operate Default Do not...

Page 115: ...IP W1 BKR Range Do not operate Operate Default Do not operate RLY2 TRIP W2 BKR Range Do not operate Operate Default Do not operate NOTE NOTE The settings changed using the Quick Setup menu are available for review and modification by navigating through S1 RELAY SETUP S2 SYSTEM SETUP and S3 PROTECTION in the SETPOINTS main menu ...

Page 116: ...5 6 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL QUICK SETUP SETTINGS CHAPTER 5 QUICK SETUP FRONT CONTROL PANEL ...

Page 117: ...etpoints found on that menu Figure 6 1 Setpoints main menu S3 PROTECTION SETPOINT GROUP 1 SETPOINT GROUP 2 S5 INPUTS OUTPUTS CONTACT INPUTS OUTPUT RELAYS VIRTUAL INPUTS REMOTE INPUTS S4 CONTROLS CHANGE SETP GROUP VIRTUAL INPUTS LOGIC ELEMENTS W1 BREAKER FAIL W2 BREAKER FAIL RESET LOCKOUT ٕ S2 SYSTEM SETUP CURRENT SENSING POWER SYSTEM TRANSFORMER WNDG 1 BREAKER WNDG 2 BREAKER ٕ S1 RELAY SETUP CLOCK...

Page 118: ...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 descriptions for this class of setpoint throughout the manual a general description is presented in this overview Details that are specific to a particular feature are included in the discussion of the feature The fo...

Page 119: ...nput level change to a contact closure of the 1 Trip relay is the time selected as time delay in this setpoint plus approximately up to 2 power frequency periods Logic diagrams The logic diagrams provide a complete comprehensive understanding of the operation of each feature These sequential logic diagrams illustrate how each setpoint input parameter and internal logic is used in the feature to ob...

Page 120: ...iations 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 121: ...t priority so if IRIG B is not the synchronization source but SNTP is then any other source of synchronization should be rejected Synchronization commands are all eventually translated into a MODBUS function and as such are blocked from the MODBUS layer as required Any synchronization commands other than Modbus IEC60870 5 103 IEC60870 5 104 or DNP will be accepted only if IRIG B and SNTP are not t...

Page 122: ...ets the week of the month for the end of the DLS time DLS END WEEKDAY Range Not Set Mon Tue Wed Thu Fri Sat Sun Default Not Set This setting sets the weekday for the end of the DLS time PATH SETPOINTS S1 RELAY SETUP CLOCK IRIG B Range Disabled Enabled Default Disabled This setting enables the IRIG B signal for time stamp synchronization 1 Set the IRIG B to Enabled if the IRIG B device is connected...

Page 123: ...rd enables password security Each interface RS485 Ethernet USB and front panel keypad is independent of one another meaning that enabling setpoint access on one interface does not enable access for any of the other interfaces The password must be explicitly entered via the active interface in order to change setpoints and execute commands The Master Password cannot be set from the keypad and must ...

Page 124: ...equiring control access listed below Changing the Local or Remote Setpoint Password depending on the interface being accessed CONTROL LEVEL Virtual Input commands Clearing of event records transient records and other data Changing the Local or Remote Control Password depending on the interface being accessed MASTER LEVEL Setting and changing of all passwords including the Master Password Disabling...

Page 125: ...the new password does not meet the password requirements If a valid password was entered the user will be prompted to re enter the new password CONFIRM PASSWORD The user is prompted to re enter the new Local Setpoints Password If the passwords do not match an ENTRY MISMATCH message will appear the password will remain unchanged and the user will be returned to the Enter New Password page If the pa...

Page 126: ...following settings are available to configure the RS485 port BAUD RATE Range 9600 19200 38400 57600 115200 Default 115200 This setting specifies the baud rate bits per second for the RS485 port PARITY Range None Odd Even Default None This setting specifies the parity for the RS485 port REAR RS485 PROTOCOL Range Modbus IEC60870 5 103 DNP 3 0 Default Modbus This setting specifies the protocol to be ...

Page 127: ... register commands Refer to the 3 Series Communications Guide for additional details on the Modbus protocol and the Modbus memory map The Modbus server can simultaneously support two clients over serial RS485 The server is capable of reporting any indication or measurement and operating any output present in the device A user configurable input and output map is also implemented The 345 operates a...

Page 128: ... protocol Figure 6 7 IEC 60870 5 104 protocol settings PATH SETPOINTS S1 RELAY SETUP COMMUNICATIONS IEC61870 5 104 Please refer to the 3 Series Communications Guide for details on how to set up the IEC 60870 5 104 protocol For a complete list of Binary inputs see Format Code FC134B in the 3 Series Communications Guide Note that the format codes differ for each relay model DNP communication Figure ...

Page 129: ...n either the transmit or receive direction a file system to maintain SCL ICD or CID files for IEC61850 GOOSE As such the implementation stores GOOSE configuration using MODBUS set points Configuration of transmission and reception settings for the GOOSE feature are performed using EnerVista 3 Series Setup software The 345 firmware accepts GOOSE messages from UR F650 and UR Plus The interoperabilit...

Page 130: ...all programmed relay elements set to trip the breaker The text TRIP followed by the name of the operated element is recorded ALARM EVENTS Range Disabled Enabled Default Enabled These events include the elements programmed as an ALARM or LATCHED ALARM function which detect power system conditions considered as an alarm CONTROL EVENTS Range Disabled Enabled Default Enabled If set to Enabled the even...

Page 131: ...of which has been Enabled to activate the trigger The transient recorder trigger may also be activated when any of the selected trigger inputs 1 to 3 is detected as having On status The following path is available using the keypad For instructions on how to use the keypad please refer to Chapter 3 Working with the Keypad PATH SETPOINTS S1 RELAY SETUP TRANSIENT RECDR NUM OF RECORDS Range 1 3 6 Defa...

Page 132: ...he selected input changes to On Fault report The 345 relay has a Fault Report which captures measured analog signals at the time of the trip The Fault Report stores only the last recorded values in relay s non volatile memory The Fault Report has two configurable setpoints FAULT TRIGGER and DELAY OTHER TRIGGERS The high state of the selected Fault Trigger operand will trigger the Fault Report The ...

Page 133: ...rough Modbus Refer to the 3 Series Communications Guide for register details PATH SETPOINTS S1 RELAY SETUP FRONT PANEL FLASH MESSAGE TIME Range 1 s to 65535 s Default 5 s Flash messages are status warning error or information messages displayed for several seconds in response to certain key presses during setting programming These messages override any normal messages The duration of a flash messa...

Page 134: ...d from a list of logic operands and can be programmed to be either Self Reset or Latched The LED color for LED5 to LED8 can also be programmed By default the programmable LEDs are all Off with no source selected The LEDs on the relay front panel are ordered as shown Programmable LEDs can be configured using the keypad or the EnerVista 3 Series Setup software as described in Chapter 3 Software Setu...

Page 135: ...s Default Off Selects the signal source of programmable LED 1 through 8 LED1 8 TYPE Range Self reset Latched Default Self reset Selects the type of programmable LED 1 through 8 LED5 8 COLOR Range Off Red Orange Green Default Orange Selects the color of programmable LED 5 through 8 NOTE NOTE Note that programmable LEDs 1 through 4 have fixed colors LED1 Red LED2 Orange LED3 Orange LED4 Orange Figur...

Page 136: ...eeder Name The RELAY NAME setting allows the user to uniquely identify a relay This name will appear on generated reports This name is also used to identify specific devices which are engaged in automatically sending receiving data over the communications channel RELAY STATUS Range Not Ready Ready Default Not Ready Allows the user to activate deactivate the relay The relay is not operational when ...

Page 137: ... A Default 5 A Enter the rated ground CT primary current of the ground current transformers associated with Winding 1 W1 GND CT SECONDARY Range 1 A to 5 A in steps of 1 A Default 1 A Configurable 1 A or 5 A secondary must be specified with order code P0G0 Enter the rated ground CT secondary current of the ground current transformers associated with Winding 1 W2 PH CT PRIMARY Range 1 A to 6000 A in...

Page 138: ...em Transformer PATH SETPOINTS S2 SYSTEM SETUP TRANSFORMER XFMR RATED LOAD Range 0 00 to 200 00 MVA in steps of 0 01 Default 5 00 MVA Enter the self cooled 100 load rating for the power transformer TRANSFORMER TYPE Range Refer to above Transformer Types table Default y y0 Select the transformer connection from a list of transformer types shown in table 6 1 Transformer types PHASE COMPENSATION Range...

Page 139: ...nding Transformer windings that are grounded inside zone protection allow zero sequence current flow in that winding and therefore it is from these windings that zero sequence removal is necessary Transformer setup phase magnitude compensations Percent biased differential protection is the main type of protection for power transformers with respect to detecting all types of transformer internal fa...

Page 140: ...that shows how CT ratios transformer voltage ratios and transformer phase shifts are used to generate the correction factors These correction factors are applied to the current signals to obtain extremely accurate differential currents The menu paths in the example are shown graphically in the above figure Consider a typical Wye Delta power transformer with the following data Connection Y d30 i e ...

Page 141: ...ey are always used by the relay as a magnitude reference Based on 100 transformer loading 5MVA the measured winding currents are Winding 1 CT measured Eq 3 winding 1 nominal current Winding 2 CT measured Eq 4 winding 2 nominal current Based on 100 transformer loading the compensated currents expressed in times CT w1 as a reference and used by the percent differential protection will be as shown Eq...

Page 142: ...he delta winding currents lag the wye winding currents by 30 which is in agreement with the transformer nameplate Now assume that a source with a sequence of ACB is connected to transformer terminals A C B respectively The currents that would be present for a balanced load are shown below Figure 6 14 Phasors for ACB sequence Note that the delta winding currents leads the wye winding currents by 30...

Page 143: ...mple The 345 performs this phase angle correction internally based on the following setpoint Set S2 SYSTEM SETUP TRANSFORMER TRANSFORMER TYPE to Y d30 The 345 supports all standard two winding transformer types Each transformer type from the Transformer Types table below provides the following information As shown in the Y d30 entry of the transformer types table the 30 lag of the Delta results in...

Page 144: ...tection allow zero sequence current flow in that winding and therefore it is from these windings that zero sequence removal is necessary The 345 performs this phase angle compensation and zero sequence removal automatically based on the settings entered for the transformer All CTs are connected Wye polarity markings pointing away from the transformer All currents are phase and zero sequence compen...

Page 145: ... 1 2 0 Y y0 1 WYE gnd 1 2 0 2 WYE gnd 2 3 0 0 2 WYE gnd 2 3 0 0 Y y180 1 WYE gnd 1 2 180 lag Y d30 1 WYE gnd 1 2 30 lag 2 WYE gnd 2 3 180 lag 0 2 DELTA gnd 2 3 30 lag 0 Y d150 1 WYE gnd 1 2 150 lag Y d210 1 WYE gnd 1 2 210 lag 2 DELTA gnd 2 3 150 lag 0 2 DELTA gnd 2 3 210 lag 0 Y d330 1 WYE gnd 1 2 330 lag D d0 1 DELTA gnd 1 2 0 2 DELTA gnd 2 3 330 lag 0 2 DELTA gnd 2 3 0 0 D d60 1 DELTA gnd 1 2 6...

Page 146: ... WYE gnd 2 3 30 lag 330 lag D y150 1 DELTA gnd 1 2 0 D y210 1 DELTA gnd 1 2 0 2 WYE gnd 2 3 150 lag 210 lag 2 WYE gnd 2 3 210 lag 150 lag D y330 1 DELTA gnd 1 2 0 Y z30 1 WYE gnd 1 2 30 lag 2 WYE gnd 2 3 330 lag 30 lag 2 ZIG ZAG gnd 2 3 30 lag 0 Y z150 1 WYE gnd 1 2 150 lag Y z210 1 WYE gnd 1 2 210 lag 2 ZIG ZAG gnd 2 3 150 lag 0 2 ZIG ZAG gnd 2 3 210 lag 0 Transformer Type Wdg Connection Voltage ...

Page 147: ...t Y z330 1 WYE gnd 1 2 330 lag D z0 1 DELTA gnd 1 2 0 2 ZIG ZAG gnd 2 3 330 lag 0 2 ZIG ZAG gnd 2 3 0 lag 0 D z60 1 DELTA gnd 1 2 60 lag D z120 1 DELTA gnd 1 2 120 lag 2 ZIG ZAG gnd 2 3 60 lag 0 2 ZIG ZAG gnd 2 3 120 lag 0 D z180 1 DELTA gnd 1 2 180 lag D z240 1 DELTA gnd 1 2 240 lag 2 ZIG ZAG gnd 2 3 180 lag 0 2 ZIG ZAG gnd 2 3 240 lag 0 D z300 1 DELTA gnd 1 2 300 lag 3W External Correction 1 WYE...

Page 148: ... TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL S2 SYSTEM SETUP CHAPTER 6 SETPOINTS Table 6 2 ΦCOMP W GROUNDING W NOT WITHIN ZONE GROUNDING W WITHIN ZONE 0 30 lag 60 lag 90 lag 120 lag 150 lag 180 lag 210 lag ...

Page 149: ... compensation calculations Complete magnitude phase angle and zero sequence compensation is as follows Winding 1 compensated currents Winding 2 compensated currents where magnitude phase and zero sequence compensated winding w phase currents magnitude compensation factor for winding 2 see previous sections 240 lag 270 lag 300 lag 330 lag ΦCOMP W GROUNDING W NOT WITHIN ZONE GROUNDING W WITHIN ZONE ...

Page 150: ...llowing phase and zero sequence compensation equations would be used For Winding 1 Wye grounded neutral For Winding 2 Delta The complete compensated winding 1 and winding 2 currents would be as follows DIFFERENTIAL AND RESTRAINT CURRENT CALCULATIONS Differential currents are calculated as follows Restraint currents are calculated as follows where are the phase differential currents and ...

Page 151: ...TH SETPOINTS S2 SYSTEM SETUP WNDG 1 BREAKER 52a CONTACT Range Disabled Contact Input 1 Default Disabled Select Contact Input 1 52a CI 1 if connected to breaker auxiliary contact 52a 52b CONTACT Range Disabled Contact Input 2 Default Disabled Select Contact Input 2 52b CI 2 if connected to breaker auxiliary contact 52b BKR CONNECTED Range Contact Input 5 to 10 Disabled Default Disabled Select a con...

Page 152: ... SETUP S2 BREAKER should be programmed to an additional contact input When this additional input is closed a single 52a or 52b contact will show both breaker states When the breaker is racked out this additional breaker connected input should be open In this case both breaker status indicators will be off The logic for Breaker Open and Breaker Close status is shown in the table below Table 6 3 Bre...

Page 153: ...g 2 breakers respectively These setpoints are only visible when the FUNCTION setpoint is set to Trip and supports triping individual breakers 2 Set one or both of the setpoints RLY1 TRIP W1 BKR and RLY2 TRIP W2 BKR to Operate to enable triggering the corresponding output relay or relays upon operation of the element NOTE NOTE A few 345 elements such as Percent Differential Instantaneous Differenti...

Page 154: ...SETPOINTS When the function setpoint is changed to Trip additional setpoints can be configured as shown Setting Phase TOC1 Relay 1 Trip W1 Breaker to Operate results in output relay 1 W1 breaker tripping when the Phase TOC1 element operates Figure 6 16 Breaker tripping logic diagram ...

Page 155: ...et to Trip RLY1 TRIP W1 BKR Operate 1 RLY2 TRIP W2 BKR Operate 1 RLY2 TRIP W2 BKR Operate 1 The selection of Output Relay 2 RLY2 TRIP W2 BKR appears in Protection Control and Monitoring element menu when Function set to Trip OR OR AND AND TRIP W1 BREAKER FLEXLOGIC OPERAND To Output Relay 1 RLY 1 W1 BKR TRIP TRIP W2 BREAKER FLEXLOGIC OPERAND To Output Relay 2 RLY 2 W2 BKR TRIP From Element 1 menu F...

Page 156: ...aint characteristic The purpose of this characteristic is to provide a zone for differential protection operation and a zone for no operation where the user can define protection sensitivity and dependability during internal faults and security during external faults The differential current is calculated per phase as a vector sum of currents from both windings after magnitude and angle compensati...

Page 157: ...e transformer magnetizing current CT inaccuracies and a transformer ratio that may change as a result of the transformer on load tap changer SLOPE 1 Range 15 to 100 in steps of 1 Default 30 This setting is applicable for restraint through currents of zero to kneepoint 1 and defines the ratio of differential restraint currents above which the element will operate The slope is set to ensure sensitiv...

Page 158: ...turate on a 5 MVA transformer with a ratio of 13 8kV 4 16kV and a Winding1 CT 500 5 rating the Breakpoint 2 setting will be 6 02 x CT In this example SLOPE 2 Range 50 to 100 in steps of 1 Default 95 The Slope 2 setting ensures stability during fault conditions of the type that produce CT saturation and spurious high differential current Slope 2 should be set high to cater for the worst case scenar...

Page 159: ...aptive and depends on the magnitude of the differential current per phase If the differential current on any of the three phases goes below the differential current cut off level of 0 04 x CT the 2nd harmonic current from that phase gets dropped zeroed from the equation for averaging and the dividing number divisor is decreased from 3 to 2 The same happens if the magnitude of the differential curr...

Page 160: ... 1 BREAKPOINT 1 BREAKPOINT 2 SLOPE 2 INRUSH INHIBIT LEVEL RUN RUN RUN INRUSH INHIBIT LEVEL INRUSH INHIBIT MODE IA2d LEVEL SETPOINT RUN RUN SETPOINT OVEREXCITATION INHIBIT FUNCTION Disabled 0 5th harmonic 1 Phase A current IA5d Phase B current IB5d Phase C current IC5d Differential 5th Harmonic OVEREXC INHIBIT LEVEL SETPOINT RUN RUN RUN AND AND AND PCNT DIFF PH C PKP Message Event Recorder Transien...

Page 161: ...following criteria The pickup setting xCT is selected to be higher than the maximum inrush current during transformer energization The pickup setting is set higher than the fault current for faults occurring outside the zone of protection The pickup setting is selected to be lower than the maximum fault current during internal fault conditions PATH SETPOINTS S3 PROTECTION S3 PROTECTION GROUP 1 2 X...

Page 162: ...LED TRIP Alarm OR AND Trip AND SETPOINT BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR OR Trip To Breaker Failure Phase A Diff current IAd Phase B Diff current IBd Phase C Diff current ICd Phase Differential Currents INST DIFF PKP Message LED PICKUP IAd Pickup IBd Pickup ICd Pickup RUN RUN RUN INST DIFF OP Event Recorder OR LED ALARM RESET Command AND S R LATCH Operate Output Relay 2 W1 BKR TRIP SET...

Page 163: ... neutral point since the fault voltage is not the system voltage but rather the result of the transformation ratio between the primary windings and the percentage of shorted turns Therefore the resultant differential currents may be below the pickup and or the slope setting of the main differential element where the fault will go undetected Application of the restricted ground fault protection ext...

Page 164: ...sured by the relay satisfies the selected GND CURRENT SUPERVISION LEVEL before making operation decision The ground current supervision is not active if the GND CURRENT SUPERVISION is selected as Disabled The RGF protection works without the supervision as well PATH SETPOINTS S3 PROTECTION S3 PROTECTION GROUP 1 2 RESTRICTED GROUND FAULT 1 2 RGF FUNCTION Range Disabled Latched Alarm Alarm Trip Defa...

Page 165: ... fault GND CURRENT SPVSN Range Disabled Enabled Default Disabled This setting enables or disables the ground current supervision of the RGF function If set to Disabled the RGF function will work without ground current supervision The ground current level is monitored if the setting is set to Enabled GND SUPV LEVEL Range 0 02 to 10 00 x CTg W1 in steps of 0 01 Default 0 10 x CTg W1 This setting def...

Page 166: ...st of the time the transformer runs at lower than the nominal loads the slope setting can be set to higher value 70 load the slope setting would be 36 485 A 100 7 50 load the slope setting would be 36 346 A 100 10 30 load the slope setting would be 36 208 A 100 17 The ground current supervision feature and or the RGF pickup time delay can be used if CT saturation due to heavy external faults is a ...

Page 167: ...1 2 Phase C current Ic Winding Phase Currents RUN Imax max Ia Ib Ic RGF PICKUP LED PICKUP RGF PKP Message and Event Recorder RGF OP Message and Event Recorder RGF PKP TIME DELAY SETPOINT t PKP 0 AND OR LED ALARM RESET Command AND S R LATCH W1 2 Ground current Ig Winding Ground Current In 3I0 Igd I 3I0 Ig I SETPOINT GND CURRENT SUPV Disabled 0 Enabled 1 GND CURNT SPV LEVEL Ig LEVEL x CT1 AND OR AND...

Page 168: ...n the previous time step Otherwise the formula uses the cooling time constant The time to trip is estimated when the load current exceeds the PKP setting and the 49 element picks up At the same time the thermal capacity will start to increase at a rate depending on the current amplitude and the prior loading condition of the cable When the thermal capacity exceeds the alarm level the element will ...

Page 169: ...the keypad please refer to Chapter 3 Working with the Keypad PATH SETPOINTS S3 PROTECTION SETPOINT GROUP 1 2 THERMAL OVLD THERMAL OVLD FUNC Range Disabled Trip Latched Alarm Alarm Default Disabled The output relays 1 TRIP W1 BKR and 2 TRIP W2 BKR will operate only if the Trip function is selected and the accumulated thermal capacity for any of the phases is over 100 The ALARM LED will turn on if t...

Page 170: ...the one computed in the previous time step COOL TIME CONSTANT τC Range 1 00 to 6 00 x τH in steps of 0 01 x τH Default 2 00 x τH This time constant is used to compute the thermal capacity when the thermal capacity at each time step is less than the one computed in the previous time step OUTPUT RELAY X For details see Common setpoints BLOCK 1 2 3 For details see Common setpoints NOTE NOTE The therm...

Page 171: ...P Event Recorder Transient Recorder Alarm OR OR Phase Currents AND Trip AND SETPOINT BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR Message THERMAL OVERLOAD Ph A Thermal OP Ph B Thermal OP Ph C Thermal OP OR HEATING T CONSTANT COOLING T CONSTANT T TRIP ph B T TRIP ph C T TRIP ph A Thermal Capacity ph A Thermal Capacity ph B Thermal Capacity ph C ACTUAL VALUES Ph A Thermal Alarm Message OR SETPOINT A...

Page 172: ...e created by entering the trip times at 80 different current values see S2 SYSTEM SETUP FLEXCURVE A Curve formulas are given for use with computer based coordination programs Calculated trip time values are only valid for I Ipu 1 Select the appropriate curve shape and multiplier thus matching the appropriate curve with the protection requirements The available curves are shown in the table below E...

Page 173: ... 6 0 7 0 8 0 9 0 10 0 ANSI Extremely Inverse 0 5 2 000 0 872 0 330 0 184 0 124 0 093 0 075 0 063 0 055 0 049 1 0 4 001 1 744 0 659 0 368 0 247 0 185 0 149 0 126 0 110 0 098 2 0 8 002 3 489 1 319 0 736 0 495 0 371 0 298 0 251 0 219 0 196 4 0 16 004 6 977 2 638 1 472 0 990 0 742 0 596 0 503 0 439 0 393 6 0 24 005 10 466 3 956 2 208 1 484 1 113 0 894 0 754 0 658 0 589 8 0 32 007 13 955 5 275 2 944 1 ...

Page 174: ...2 133 2 043 1 972 10 0 13 509 7 574 4 776 3 818 3 324 3 020 2 815 2 666 2 554 2 465 IEC BS Curve Shape K E IEC Curve A BS142 0 140 0 020 IEC Curve B BS142 13 500 1 000 IEC Curve C BS142 80 000 2 000 IEC Short Inverse 0 050 0 040 Multiplier TDM Current I Ipickup 1 5 2 0 3 0 4 0 5 0 6 0 7 0 8 0 9 0 10 0 IEC Curve A 0 05 0 860 0 501 0 315 0 249 0 214 0 192 0 176 0 165 0 156 0 149 0 10 1 719 1 003 0 6...

Page 175: ...58 0 054 0 052 0 20 0 612 0 356 0 223 0 175 0 150 0 135 0 124 0 115 0 109 0 104 0 40 1 223 0 711 0 445 0 351 0 301 0 269 0 247 0 231 0 218 0 207 0 60 1 835 1 067 0 668 0 526 0 451 0 404 0 371 0 346 0 327 0 311 0 80 2 446 1 423 0 890 0 702 0 602 0 538 0 494 0 461 0 435 0 415 1 00 3 058 1 778 1 113 0 877 0 752 0 673 0 618 0 576 0 544 0 518 IAC Curve Shape A B C D E IAC Extreme Inverse 0 0040 0 6379 ...

Page 176: ...OINTS S3 PROTECTION SETPOINT GROUP 1 2 PHASE TOC 1 2 PH TOC1 2 FUNCTION Range Disabled Latched Alarm Alarm Trip Default Disabled For details see Common setpoints The output relays 1 R1 TRIP and 2 R2 TRIP will operate when the Trip setting is selected and the Phase TOC operates 1 0 2 901 1 312 0 537 0 343 0 266 0 227 0 202 0 186 0 174 0 165 2 0 5 802 2 624 1 075 0 687 0 533 0 453 0 405 0 372 0 349 ...

Page 177: ...emely Inverse curve is selected with TDM 2 and the fault current was 5 times bigger than the PKP level the operation of the element will not occur before an elapsed time after pickup of 2 59 seconds PH TOC 1 2 RESET Range Instantaneous Linear Default Instantaneous The Instantaneous reset method is intended for applications with other relays such as most static relays which set the energy capacity ...

Page 178: ...OC INPUT setpoint AND Trip AND PH TOC PH A OP PH TOC PH B OP PH TOC PH C OP PH TOC OP PH TOC PH A PKP PH TOC PH B PKP PH TOC PH C PKP PH TOC PKP PH TOC RESET TIME RUN IA PICKUP RUN IB PICKUP RUN IC PICKUP SETPOINTS BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR LED ALARM RESET Command AND S R LATCH LED TRIP To Breaker Failure Trip SETPOINTS configurable only if TRIP function selected Operate trip ou...

Page 179: ... 2 PKP Range 0 05 to 20 00 x CT in steps of 0 01 x CT Default 1 00 x CT This setting sets the instantaneous overcurrent pickup level For example a PKP setting of 0 9 x CT with 300 5 CT translates into 270A primary current PH IOC1 2 DELAY Range 0 00 to 300 00 sec in steps of 0 01 sec Default 0 00 sec This setting provides selection for the time delay used to delay the protection operation RLY1 TRIP...

Page 180: ...Off 0 OR Message and Event Recorder IB PICKUP IA PICKUP IC PICKUP SETPOINT PH IOC A PKP PHASE IOC PKP t PKP 0 t PKP 0 t PKP 0 OR OR LED ALARM RESET Command AND S R LATCH PH IOC B PKP PH IOC C PKP PH IOC A OP PHASE IOC OP PH IOC B OP PH IOC C OP LED TRIP SETPOINTS configurable only if TRIP function selected Operate trip output relays upon selection RLY2 TRIP W2 BKR RLY1 TRIP W1 BKR To Breaker Failu...

Page 181: ...r Ground TOC protection GND TOC1 2 FUNCTION Range Disabled Trip Alarm Latched Alarm Default Disabled For details see Common setpoints If the Trip setting is selected the TOC menu allows the user to select the operation of either RLY1 TRIP W1 BKR RLY2 TRIP W2 BKR or both trip output relays GND CT INPUTS Range CT W1 CT W2 Default CT W1 The Ground Timed Over Current menu provides for the selection fo...

Page 182: ...s selected the time to reset is calculated based on the following linear equation Eq 19 where TRESET reset time in seconds E energy capacity reached per unit M curve multiplier CR characteristic constant 5 for ANSI IAC Definite Time and FlexCurvesTM 8 for IEC curves RLY1 TRIP W1 BKR and RLY2 TRIP W2 BKR Range Do not operate Operate Default Do not operate The menu for the two trip output relays RLY...

Page 183: ...rip GND TOC RESET Ground Sens Ground current Ig SETPOINTS BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR GND TOC INPUT CT W1 CT W2 ground current selected under GND TOC INPUT Message and Event Recorder GND TOC PKP LED TRIP OR AND SETPOINTS Do Not Operate Operate OUTPUT RELAY X AND To Breaker Failure Trip Message and Event Recorder LED ALARM RESET Command AND S R LATCH GND TOC OP SETPOINTS configurab...

Page 184: ...2 TRIP W2 BKR or both GND CT INPUTS Range CT W1 CT W2 Default CT W1 The Ground Instantaneous Overcurrent menu provides for selection of either the ground CT of Winding 1 CT W1 or the ground CT of Winding 2 CT W2 input If CT W1 is selected the GND IOC element will use the ground CT rating of Winding 1 entered on the relay under SYSTEM SETUP S2 CURRENT SENSING If CT W2 setting is selected the relay ...

Page 185: ...the OC menu regardless of the selected OC function These output relays will not operate if either Alarm or Latched Alarm is selected as an OC function regardless of the Operate Do Not Operate value selected The output relays are operational only if the OC function is selected as Trip OUTPUT RELAY X For details see Common setpoints BLOCK 1 2 3 For details see Common setpoints ...

Page 186: ...ed 0 Latched Alarm Alarm Trip GND IOC PKP DELAY SETPOINT t PKP 0 LED ALARM RESET Command AND S R LATCH LED TRIP To Breaker Failure Trip SETPOINTS configurable only if TRIP function selected Operate trip output relays upon selection RLY 2 TRIP W2 BKR SETPOINTS Do Not Operate Operate OUTPUT RELAY X Message and Event Recorder GND TOC OP Ground Sens Ground current Ig CT W1 CT W2 ground current selecte...

Page 187: ...rip output relays RLY1 TRIP W1 BKR RLY2 TRIP W2 BKR or both NTRL CT INPUTS Range CT W1 CT W2 Default CT W1 The menu of the Neutral Time OverCurrent element provides for selection of either CT W1 or CT W2 input currents If CT W1 is selected the NTRL TOC element will use the neutral current computed by the relay based on Winding 1 phase currents and the Winding 1 CT ratings If CT W2 setting is selec...

Page 188: ...t Operate The menu for the two trip output relays RLY1 TRIP W1 BKR and RLY2 TRIP W2 BKR is available only if the Trip setting is selected as a function for the Neutral Timed Overcurrent element One or both trip output relays can be selected to operate upon Neutral TOC operation NOTE NOTE The RLY1 TRIP W1 BKR and RLY2 TRIP W2 BKR setpoints will be displayed on the OC menu regardless of the selected...

Page 189: ...RL TOC RESET SETPOINTS BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR NTRL TOC CT INPUT Message and Event Recorder NTRL TOC PKP LED TRIP OR AND AND To Breaker Failure Trip Message and Event Recorder LED ALARM RESET Command AND S R LATCH NTRL TOC OP SETPOINTS configurable only if TRIP function selected Operate trip output relays upon selection RLY 1 TRIP W1 BKR Neutral current IN CT W2 CT W2 neutral ...

Page 190: ...tral Overcurrent menu provides selection for either CT W1 or CT W2 phase inputs If CT W1 is selected the NTRL IOC element will use the neutral current computed by the relay based on Winding 1 phase currents and the Winding 1 CT ratings If CT W2 setting is selected the relay will use the computed neutral current based on Winding 2 phase currents and Winding 2 CT ratings NTRL IOC1 2 PKP Range 0 05 t...

Page 191: ...POINTS BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR NTRL IOC CT INPUT Message and Event Recorder NTRL TOC PKP LED TRIP OR AND SETPOINTS Do Not Operate Operate OUTPUT RELAY X AND To Breaker Failure Trip Message and Event Recorder LED ALARM RESET Command AND S R LATCH Neutral IOC PKP SETPOINTS configurable only if TRIP function selected Operate trip output relays upon selection RLY 1 TRIP W1 BKR Neu...

Page 192: ...lier For example the operating time for TOC set to Definite Time and a TDM set to 5 will result in 5 0 1 0 5s PATH SETPOINTS S3 PROTECTION SETPOINT GROUP 1 2 NEG SEQ TOC1 2 NEG SEQ TOC1 2 FUNC Range Disabled Latched Alarm Alarm Trip Default Disabled For details see Common setpoints If the Trip setting is selected the IOC menu allows the user to select the operation ofeither one of the two trip out...

Page 193: ... curves The 100 energy capacity for the TOC element is defined by the selection of PKP TDM and points from the inverse curve A memory variable based on actual values currents is monitored for accumulation of energy capacity where if it reaches a level of 100 of the set energy capacity level the element operates and if it goes below 97 98 of this level the element will tend to reset The accumulated...

Page 194: ...rate OUTPUT RELAY X Trip AND To Breaker Failure Trip SETPOINTS BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR LED PICKUP Message and Event Recorder Message and Event Recorder I_2 LED ALARM RESET Command AND S R LATCH SETPOINTS RUN NEG SEQ TOC PICKUP NEG SEQ TOC CURVE NEG SEQ TOC TDM I_2 PICKUP Adjust PKP NEG SEQ TOC RESET I_2 x t NEG SEQ TOC OP SETPOINTS configurable only if TRIP function selected O...

Page 195: ...load they do detect the negative sequence current present in unbalanced load For this reason select an element pickup setting above the maximum expected current due to load unbalance PATH SETPOINTS S3 PROTECTION SETPOINT GROUP 1 2 NEG SEQ IOC NEG SEQ IOC FUNCTION Range Disabled Latched Alarm Alarm Trip Default Disabled For details see Common setpoints NEG SEQ IOC PKP Range 0 05 to 20 00 x CT in st...

Page 196: ...NCTN Disabled 0 Latched Alarm NEG SEQ IOC PICKUP AND Operate Output Relay 1 TRIP Event Recorder Transient Recorder LED TRIP Alarm OR OR AND SETPOINTS Do Not Operate Operate OUTPUT RELAY X Trip AND To Breaker Failure Trip SETPOINTS BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR RUN LED PICKUP Event Recorder Transient Recorder NegSeq IOC Message I_2 PICKUP NEG SEQ IOC DELAY SETPOINT t PKP I_2 LED ALAR...

Page 197: ...group was Group 1 at the time of a trip the breaker opens and the input configured under BLK GROUP CHANGE is asserted the relay will maintain Setpoint Group 1 even if the input SET GROUP 2 ACTIVE is asserted Vice versa if the BLK GROUP CHANGE input is asserted the relay will not switch from Group 2 to Group 1 even if the input under SET GROUP 2 ACTIVE is de asserted The relay will default to Setpo...

Page 198: ...f Reset or Latched specified If Self Reset type was selected entering On command will lead to a pulse of one protection pass To prolong the time of the virtual input pulse one can assign it as a trigger source to a Logic Element with a dropout timer set to the desired pulse time If Latched type is selected the state of the virtual input will be latched upon entering On command Refer to the logic d...

Page 199: ... The PICKUP LED will turn on upon a Logic Element pickup condition except when the Logic Element function is selected as Control The ALARM LED will turn on upon Logic Element operation if the Logic Element function selected is either Alarm or Latched Alarm The TRIP LED will turn on upon Logic Element operation if the Logic Element function is selected as Trip The option to trigger auxiliary output...

Page 200: ... four blocks can be selected BLOCK 1 4 Range Off Any input from the list of inputs Default Off Each of the blocks is configurable by allowing the assigning of an input selected from a list of inputs This input can be a contact input a virtual input a remote input or an output flag from a protection or control element as well as an input from any of the other seven logic inputs See the list of avai...

Page 201: ...electable to any boolean operator such as OR AND NAND NOR XOR or XNOR All four block inputs are programmed with contact inputs 1 to 4 and the Block logic setpoint is programmed into an OR gate These inputs may include Maintenance input Breaker disconnected input Protection disabled input etc Output Relay 3 is selected to energize upon operation of Logic Element 1 to denote a Breaker Alarm With pic...

Page 202: ...SETPOINT Do Not Operate Operate OUTPUT RELAY X RST TIME DELAY Logic Elem 1 OP Logic Elem 1 DPO Logic Elem 1 PKP LED PICKUP Message SETPOINT LOGIC EL FUNCTION Disabled 0 Latched Alarm Operate Output Relay 1 TRIP LED ALARM LED TRIP Alarm OR OR AND RESET Command Trip AND AND Control S R LATCH t PKP TRIGGER LOGIC SETPOINT TRIGGER SOURCE 8 t PKP TRIGGER INPUTS SETPOINT 2 to 8 BLOCK 1 Off Off OR AND NOR...

Page 203: ...d the element operated operand name Alarm DPO The function setpoint of the element has been programmed as Alarm and the element operation dropped out operand name Block The operation of the element has been blocked operand name Off The status of the selected input or output is OFF operand name On The status of the selected input or output is ON Element Operands Event Description Contact Inputs Con...

Page 204: ...s the presence of syncheck conditions Testing Testing ON Testing feature is Enabled Testing OFF Testing feature is Disabled Element Operands 2nd Harmonic Differential 2nd Hmnc Diff OP 2nd Hmnc Diff Ph B 2nd Hmnc Diff Ph A 2nd Hmnc Diff Ph C 5th Harmonic Differential 5th Hmnc Diff OP 5th Hmnc Diff Ph B 5th Hmnc Diff Ph A 5th Hmnc Diff Ph C Ambient Temperature HI Amb Temp PKP LO Amb Temp PKP HI Amb ...

Page 205: ...rm OP NSeq TOC2 Trip OP NSeq TOC1 Trip OP NSeq TOC1 Alrm DPO NSeq TOC2 Trip DPO NSeq TOC1 Trip DPO NSeq TOC1 Blk NSeq TOC2 Alrm DPO NSeq TOC1 Alrm PKP NSeq TOC2 Alrm PKP NSeq TOC2 Blk NSeq TOC2 Trip PKP NSeq TOC2 Alrm OP Neutral Instantaneous Overcurrent Ntrl IOC1 Trip PKP Ntrl IOC1 Alrm PKP Ntrl IOC2 Trip DPO Ntrl IOC1 Trip OP Ntrl IOC1 Alrm OP Ntrl IOC2 Block Ntrl IOC1 Trip DPO Ntrl IOC1 Alrm DP...

Page 206: ...m OP Ph TOC1 Trip OP Ph TOC1 Alarm OP Ph TOC2 Alrm DPO Ph TOC1 Trip DPO Ph TOC1 Alarm DPO Ph TOC2 Trip OP Ph TOC1 Block Ph TOC2 Block Ph TOC2 Trip DPO Ph TOC2 Alrm PKP Ph TOC2 Trip PKP Ph A TOC1 Alrm PKP Ph A TOC2 Alrm PKP Ph A TOC1 Trip PKP Ph A TOC1 Alrm OP Ph A TOC2 Alrm OP Ph A TOC1 Trip OP Ph A TOC1 Alrm DPO Ph A TOC2 Alrm DPO Ph A TOC1 Trip DPO Ph B TOC1 Alrm PKP Ph B TOC2 Alrm PKP Ph B TOC1...

Page 207: ...OC1 Alrm OP SGnd TOC2 Trip DPO SGnd TOC1 Trip DPO SGnd TOC1 Alrm DPO SGnd TOC2 Alrm DPO SGnd TOC1 Block SGnd TOC2 Alrm PKP SGnd TOC2 Block SGnd TOC2 Trip PKP SGnd TOC2 Alrm OP Thermal Overload Therm O L Trip OP Therm Lvl Alrm OP Therm O L Block Therm O L Trip DPO Therm Lvl Alrm DPO Therm PhA Alrm OP Therm PhC Alrm OP Therm PhB Trip OP Therm PhA Alrm DPO Therm PhC Alrm DPO Therm PhB Trip DPO Therm ...

Page 208: ... to Trip and the CT INPUT set to CT W2 When the 345 relay allows the configuration of only one breaker failure function this function is always associated with the Winding 1 breaker and will be triggered upon operation of any protection element with a FUNCTION setting set to Trip and the CT INPUT set to CT W1 The following path is available using the keypad For instructions on how to use the keypa...

Page 209: ... Ib Phase C current Ic Alarm OR OR Trip Phase Currents AND Ia PICKUP OR AND SETPOINT BF EXT INITIATE Off 0 Range Contact Input Virtual Input Remote Input Logic Element From Protection operation OR BF TIME DELAY 1 SETPOINT t PKP RUN BF TIME DELAY 2 SETPOINT t PKP RUN LED ALARM RESET Command AND S R LATCH SETPOINTS Do Not Operate Operate OUTPUT RELAY X Message and Event Recorder W1 W2 Breaker Failur...

Page 210: ...ontact virtual or remote input selected under the Lockout Reset setpoint FUNCTION Range Disabled Enabled Default Disabled For details see Common setpoints INPUT 1 10 Range Off Any Logic Operand Default Off This setting selects an operand from the list of logic operands The assertion of the selected operand triggers lockout Ten trigger input setpoints are provided LOCKOUT SUPERVISION Range Off Any ...

Page 211: ... the breaker directly bypassing the relay outputs i e from the breaker control switch while the protective relay applies lockout on its two TRIP outputs the breaker may not close as the trip signal would have priority over the close signal Figure 6 39 Lockout logic diagram Set Dominant SETPOINT BLOCK 1 Off 0 BLOCK 2 Off 0 BLOCK 3 Off 0 OR SETPOINT LOCKOUT FUNCTION Disabled 0 Enabled SETPOINT ANY T...

Page 212: ...duced voltage Because of de bouncing momentary contacts must have a minimum dwell time greater than half power frequency cycle The debounce time is adjustable by the user PATH SETPOINTS S5 INPUTS OUTPUTS CONTACT INPUTS SELECT DC VOLTAGE Range 17 V 33 V 84 V 166 V Default 84 V CONTACT INPUT 1 Range 14 characters Default Bkr1 52a CI 1 CONTACT INPUT 2 Range 14 characters Default Bkr1 52b CI 2 CONTACT...

Page 213: ...te of the circuit breaker as monitored by a 52a or 52b contact The Trip relays reset after the breaker is detected in a state corresponding to the command When a relay feature sends a command to one of these special relays it will remain operational until the requested change of breaker state is confirmed by a breaker auxiliary contact and the initiating condition has reset If the initiating featu...

Page 214: ...current BLOCK RLY 1 TRIP For details see Common setpoints This setting defines a block to the Trip Output relay When the selected input is asserted the Trip Output relay will be blocked Output Relay 2 W2 breaker Trip PATH SETPOINTS S5 INPUTS OUTPUTS OUTPUT RELAYS RLY 2 W2 BKRTRIP RLY2 SEAL IN Range 0 00 to 9 99 s in steps of 0 01 Default 0 04 s This setting defines the time to be added to the rese...

Page 215: ...en OR At least one contact programmed AND OR TRIP No feedback change OR timed reset SETPOINT BF BF FUNCTION Disabled 0 Latched Alarm Alarm BF TIME DELAYS SETPOINT BF RUN OR OR OR AND AND Trip Output Seal In time SETPOINT t RST AND LED TRIP TRIP Operate Output Relay 1 W1 BKR TRIP Trip to Breaker Failure OR Local Open Relay Keypad Remote Open Relay Ready 1 RESET Relay Keypad RESET Communications RES...

Page 216: ... in operating mode and will reset when the element drops out If the Latched type is selected the output relay will stay energized after the element dropout and will be de energized upon the reset command PATH SETPOINTS S5 INPUTS OUTPUTS OUTPUT RELAYS RELAY 3 6 AUXILIARY OUTPUT TYPE Range Self Reset Latched Default Self Reset Figure 6 42 Auxiliary relays From Protection Feature OR From Control Feat...

Page 217: ...desired pulse time Selecting the Latched type will latch the virtual input state when the On command is executed NOTE NOTE The On state of the Virtual Input will be retained in the case of cycling of the relay control power supply PATH SETPOINTS S5 INPUTS OUTPUTS VIRTUAL INPUTS The following path is available using the keypad For instructions on how to use the keypad please refer to Chapter 3 Work...

Page 218: ...the 3 Series Communications Guide for details Remote outputs Remote Inputs are available for programming under the EnerVista 3 Series Setup software Refer to the 3 Series Communications Guide for details SETPOINT V INPUT FUNCTION Disabled 0 Enabled 1 AND SETPOINT V INPUT 1 TYPE Latched Self Reset AND AND Virtual Input 1 to ON 1 Virtual Input 1 to OFF 0 S R LATCH OR ACTUAL VALUES V INPUT 1 NAME Ope...

Page 219: ...parent power on each phase every second and assumes the circuit quantity remains at this value until updated by the next measurement It calculates the Thermal 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 6 45 Thermal Demand Characteristic 15 min response The 90 therma...

Page 220: ...abled For details see Common setpoints CT INPUT Range CT W1 CT W2 Default CT W1 Select the current inputs from W1 CT or W2 CT MEASUREMENT TYPE Range Blk Interval Exponential Rolling Dmd Default Blk Interval This setting sets the measurement method Three methods can be applied THERMAL 90 RESPONSE TIME Range 5 min 10 min 15 min 20 min 30 min Default 15 min This setpoint sets the time required for a ...

Page 221: ...TS MEASUREMENT TYPE 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 FlexLogic Op...

Page 222: ...trip will be issued If the RTD is chosen to vote with itself the voting feature is disabled Each RTD may also be configured as being of application type Ambient Top Oil Bottom Oil or Other The table below RTD Temperature vs Resistance lists RTD resistance versus temperature PATH SETPOINTS S6 MONITORING RTD TEMPERATURE RTD 1 12 RTD 1 to 12 APPLICATION Range None Top oil Bottom oil Ambient Other Def...

Page 223: ...e Trip pickup delay time RTD 1 to 12 TRIP DPO DELAY Range 0 00 to 600 00 s in steps of 0 01 s Default 0 00 s Sets the Trip dropout delay time RTD 1 to 12 TRIP VOTING Range Off RTD 1 to 12 Default Off Sets the redundant RTD that must also exceed this RTD s trip temperature for a trip to occur OUTPUT RELAY X For details see Common setpoints BLOCK 1 to 3 For details see Common setpoints ...

Page 224: ... RESET Off 0 SETPOINTS S4 CONTROLS BREAKER CONTROL RESET LOCKOUT Off 0 OR KEYPAD RESET Logic is shown for RTD 1 other RTDs are similar RTD 1 RTD 2 RTD 3 RTD 10 RTD 11 RTD 12 1 2 3 10 11 12 OFF Setting Off Setting RTD 1 S3 RTD PROTECTION Disabled 0 Disabled 0 SETPOINTS S4 CONTROLS LOCKOUT AND LATCH S R ASSIGNABLE AUX RELAYS Operate output relays upon selection AND AND Alarm Pickup Delay SETPOINTS A...

Page 225: ...rouble Alarm functionality OUTPUT RELAY X For details see Common setpoints BLOCK 1 to 3 For details see Common setpoints Table 6 11 RTD Temperature vs Resistance Temperature 100 Ω Pt DIN 43760 oC oF 50 58 80 31 40 40 84 27 30 22 88 22 20 4 92 16 10 14 96 09 0 32 100 00 10 50 103 90 20 68 107 79 30 86 111 67 40 104 115 54 50 122 119 39 60 140 123 24 70 158 127 07 80 176 130 89 90 194 134 70 100 212...

Page 226: ... Off 0 BLOCK 2 BLOCK 3 Off 0 Off 0 LOGIC OPERAND RTD Trouble Alarm OP Any Alarm OP TARGET MESSAGE RTD Trouble Alarm State Operate 896829A3 cdr S3 RTD TROUBLE ALARM RTD 12 Temp T12 T12 OR RTD 1 Temp T1 o T1 250 C o T1 50 C T1 OR RTD TROUBLE ALARM o T12 250 C o T12 50 C ACTUAL VALUE RTD 1 Temp RTD 12 Temp SETTINGS RUN From other RTDs OR From other RTDs Disabled 0 SETTINGS OUTPUT RELAY X Do Not Opera...

Page 227: ...nance GE Grid Solutions Maintenance Information about the relay and the breaker can be obtained through the features included in the Maintenance page Figure 7 1 Main maintenance menu MAINTENANCE M1 RELAY INFO M3 BKR MAINTENANCE M4 BKR MONITOR M5 RELAY MAINTENANCE M6 FACTORY SERVICE M7 TESTING ٕ 898761A2 cdr ...

Page 228: ...IN BUILD DATE Aug 16 2015 This screen shows the relay firmware build date MAIN BUILD TIME 16 12 32 This screen shows the relay firmware build time MAIN BOOT REVISION 1 20 This screen shows the relay boot code revision MAIN BOOT DATE Dec 11 2015 This screen shows the relay boot code date MAIN BOOT TIME 10 44 54 This screen shows the relay boot code time COMM FIRMWARE REV 1 40 This screen shows the ...

Page 229: ...SYSTEM INSTRUCTION MANUAL 7 3 COMM BOOT TIME 16 22 41 This screen shows the relay communication boot code time SERIAL NUMBER ML0T09000001 Each 345 relay has a unique Serial Number ETHERNET MAC ADR 00 A0 F4 08 A0 E9 Each 345 relay has a unique Mac Address FPGA VERSION 1 00 ...

Page 230: ...Trip coil circuit gets disconnected or if in general a high resistance is detected in the circuitry a Trip alarm will be set and the ALARM and MAINTENANCE LEDs will be on Example 1 The figure below shows the connections of the breaker trip coil to the relay s trip output relay for voltage monitoring of the trip circuit Figure 7 3 Trip Coil circuit with voltage monitoring Example 2 Some application...

Page 231: ...rm Default Disabled For details see Common setpoints The ALARM and MAINTENANCE LEDs will light up upon detection of a RLY1 2 coil circuitry problem RLY1 2 COIL DELAY Range 1 to 10 sec in steps of 1 sec Default 5 s This setting defines the RLY1 2 Coil Monitor Delay before targets appear on the display ALARM and MAINTENANCE LEDs light up on the front panel and selected output relays operate Trip Coi...

Page 232: ...when a by pass resistor is connected across the breaker auxiliary contact for continuous RLY1 2 circuit integrity monitoring The circuits will be monitored regardless of breaker position When BYPASS BKR STATE is set to Disabled monitoring of the RLY1 2 coil will be blocked when the breaker is open OUTPUT RELAY X Range Do not operate Operate Default Do not operate For details see Common setpoints ...

Page 233: ...arm Event Recorder Transient Recorder Alarm OR OR AND SETPOINT Do Not Operate Operate OUTPUT RELAY X Trip Coil Montr OP Message Trip Coil current above threshold AND OR 52a b INPUTS Breaker Closed Trip From output relay 1 2 SETPOINT BYPASS BKR STATE Enabled 1 Disable 0 AND TRIP COIL DELAY SETPOINT t PKP LED MAINTENANCE Trip Coil Montr PKP Message LED ALARM RESET Command AND S R LATCH 898020A1 cdr ...

Page 234: ...COUNTER TRIP COUNT FUNC Range Disabled Alarm Latched Alarm Default Disabled For details see Common setpoints INITIAL TRIPS Range 0 to 10000 in steps of 1 Default 0 This setting defines the number of breaker trips that occurred before enabling the breaker trip counter for breaker monitoring TRIP COUNTER LIMIT Range 1 to 10000 trips in steps of 1 Default 1 trip This setting defines the limit number ...

Page 235: ... Count Alm OP Message SETPOINT TRIP COUNTER FUNC Disabled 0 Latched Alarm Alarm OR OR AND INITIAL BKR TRIPS SETPOINT Increment Counter TRIP COUNTER LIMIT BRK TRIP COUNTER ACTUAL VALUES Breaker Initial trips Counter Initial trips new trips RST W1 BKR TRIP COUNT SETPOINT No 0 Yes Set to Zero AND Counter 0 LED ALARM RESET Command AND S R LATCH AND Trip W1 Breaker 52a b contact W1 Breaker Open 0 ms t ...

Page 236: ... based on historical true values The tripping time closing time and spring charging time are measured and displayed under MAINTENANCE M4 BKR MONITOR The Breaker Alarm Counter element does not pick up when in detection mode Monitoring mode is the normal mode where measurements are analyzed and the element picks up accordingly ALARM COUNTER LIMIT Range 0 to 100000 in steps of 1 Default 0 This settin...

Page 237: ...irtual Input 1 to 32 Remote Input 1 to 32 Logic Elements 1 to 16 Default Off This setting selects the signal to show the status of Spring Charge Normally the contact input connected to the auxiliary contact of the limit switch can be used CHARGE TIME PICKUP Range 0 00 to 60 00 s in steps of 0 01 s Default 15 00 s This setting defines the pickup level of the Spring Charge time The Spring Charge tim...

Page 238: ...t_close Ｐ Ｋ Ｐ RUN SETPOINTS BREAKER HEALTH CLOSE TIME PICKUP t_charge Ｐ Ｋ Ｐ RUN SETPOINTS BREAKER HEALTH CHARGE TIME PICKUP BKR Close Time Alm BKR Chrge Time Alm OR BKR Health Alarm AND AND IN Alarm Counter RESET Real Counter Alarm RUN SETPOINTS BREAKER HEALTH ALM COUNTER LIMIT Command CLEAR SETPOINTS OUTPUT RELAYS X Do Not Operate Operate Any Trip from breaker status from breaker status SETPOINTS...

Page 239: ...vent Reset Alarm Counter will be recorded RST W1 W2 BKR TRIP TIMES Range No Yes Default No Entering a Yes command will clear the Trip Time Counters and an event Reset Trip Time Coutner will be recorded RST W1 W2 BKR CLOSE TIMES Range No Yes Default No Entering a Yes command will clear the Close Time Counters and an event Reset Close Time Counter will be recorded RST W1 W2 BKR CHARGE TIMES Range No...

Page 240: ...breaker is provided under BKR TRIP COUNTER where the 345 stores the number of trips The counter can be reset under M3 RESET COUNTERS RST BKR TRIP COUNT set to Yes PATH MAINTENANCE M4 W1 W2 BKR MONITOR W1 W2 BKR TRIP COIL Healthy Range Healthy Unhealthy W1 W2 BKR TRIP COUNTER 5 Range 0 to 10000 trips W1 W2 BKR ALARM COUNTER 5 Range 0 to 10000 trips W1 W2 LAST TRIP TIME 5 Range 0 to 10000 ms W1 W2 A...

Page 241: ...mbient temperature Installation of the relay should be for normal operation CT VT inputs outputs PATH MAINTENANCE M5 RELAY MAINTENANCE AMBIENT TEMP AMBIENT TEMPERATURE Range Disabled Alarm Latched Alarm Default Disabled For details see Common setpoints HI ALARM LEVEL Range 20 C to 80 C in steps of 1 C Default 60 C This setting specifies the temperature level monitored by the Ambient Temperature Al...

Page 242: ...EMP ALARM Hi Alarm Level Low Alarm Level T High Temp T Low Temp RUN OR Amb Temp HI Alarm State Operate AND AND INPUTS Emergency Restart Input Lockout Reset Input SETTINGS Off 0 Lockout Reset Off 0 Emergency Restart S4 CONTROLS Remote Reset Input Remote Reset Off 0 AND OR KEYPAD RESET Disabled 0 SETTING TIME DELAY RUN t RST SETTINGS Output Relay X Do Not Operate Operate OR AND OR AND LATCH S R LOGI...

Page 243: ...e following path is available using the keypad For instructions on how to use the keypad please refer to Chapter 3 Working with the Keypad PATH MAINTENANCE M7 TESTING FORCE LEDS FORCE LEDS Range Disabled Enabled Default Disabled When the Force LEDs setpoint is set to Enabled the relay Maintenance LED starts flashing faceplate option E the In service LED turns off and the Critical Failure Relay is ...

Page 244: ...th the programmed state When the FORCE OUTP RELAYS setpoint is set to Enabled the relay Maintenance LED starts flashing faceplate option E the In service LED turns off the Trouble LED starts blinking orange and the Critical Failure Relay is de energized indicating the relay is in test mode Output relays may then be turned on and off individually using the setpoints listed below NOTE NOTE Note that...

Page 245: ...nspection 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 ...

Page 246: ...7 20 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL GENERAL MAINTENANCE CHAPTER 7 MAINTENANCE ...

Page 247: ...ty For products shipped as of 1 October 2013 GE warrants most of its GE manufactured products for 10 years For warranty details including any limitations and disclaimers see our Terms and Conditions at https www gegridsolutions com multilin warranty htm For products shipped before 1 October 2013 the standard 24 month warranty applies ...

Page 248: ...ack the unit in a box with bubble wrap foam material or styrofoam inserts or packaging peanuts to cushion the item s You may also use double boxing whereby you place the box in a larger box that contains at least 5 cm of cushioning material Ship the unit by courier or freight forwarder along with the Commercial Invoice and RMA to the factory Customers are responsible for shipping costs to the fact...

Page 249: ...CHANGES Changed manual revision number to AF Chapter 1 Updated Table 1 2 Correction to order codes Current Protection option M Updated notes at the beginning of the Specifications section Updated voltage and current input accuracy to be at nominal frequency Updated power supply power consumption Chapter 6 S4 Controls Logic Elements note added General Minor Corrections Table 3 Major Updates to SR34...

Page 250: ... Monitoring Chapter 1 Updated Order Codes Updated Line Diagram and Table 1 1 Protection Elements Chapter 6 Breaker Tripping section adding under S3 Protection Chapter 7 Breaker Health section adding under M3 Breaker Maintenance General Minor Corrections Table 3 Major Updates to SR345 AE Page Number CHANGES ...

Page 251: ...ications Controls Breaker Failure added Reset Time Specifications Testing and certification Added EAC certification Added Country of origin Date of manufacture Declaration of Conformity Updated Dielectric voltage withstand test levels Specifications added Physical and Environmental from QSG Chapter 2 Added IP20 cover optional Chapter 3 Added Upgrading the software Updated Downloading and saving se...

Page 252: ...ansformer percent differential BREAK 2 description Table 8 Major Updates to SR345 A9 Page Number CHANGES Change manual revision number to A9 Chapter 6 Clarify SR3 IEC 61850 GOOSE Details Table 9 Major Updates to SR345 A8 Page Number CHANGES Change manual revision number to A8 Chapter 1 Updated Testing and Certification table General Minor Corrections Table 10 Major Updates to SR345 A7 Page Number ...

Page 253: ...al revision number to A5 Chapter 1 Add Comm option 3E to Order Code Table Chapter 7 Add Ambient Temp section Ch 7 Maintenance General Increase number of Logic Elements to 16 General Minor Corrections General Add support for additional safety protection elements Table 13 Major Updates for SR345 A3 and A4 Page Number CHANGES Minor changes ...

Page 254: ...A 8 345 TRANSFORMER PROTECTION SYSTEM INSTRUCTION MANUAL CHANGE NOTES ...

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