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Basler BE1-11g, Instruction Manual

The Basler BE1-11g Instruction Manual provides comprehensive guidance on operating this high-performance product. You can easily download the manual for free from our website. This manual includes detailed instructions on installation, operation, and troubleshooting for maximum efficiency and performance. Get your copy now at manualshive.com.

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490 

 

9424200994 Rev U 

Directional Overcurrent (67) Test 

 

BE1-11

g

 

Table 222. Directional, Voltage Polarizing, Neutral Operational Settings 

Setting 

Value 

BESTCOMSPlus Screen 

Description 

Polarization 
Method 

IG=unchecked 
Q=unchecked 
V=checked 

Protection, Current, Directional 
(67-1) 

Selects negative 
sequence polarization 

Zero Sequence 
Mode 

VOIN 

Protection, Current, Directional 
(67-1) 

Selects VOIN for zero 
sequence mode 

Pickup 

0 A 

Protection, Current, Instantaneous 
Overcurrent (50-1) 

Sets 50-1 pickup to 0 
amps 

Pickup 

2.0 A 

Protection, Current, Instantaneous 
Overcurrent (50-2) 

Sets 50-2 pickup to 2.0 
amps 

Pickup 

0 A 

Protection, Current, Instantaneous 
Overcurrent (50-3) 

Sets 50-3 pickup to 0 
amps 

Step 24:  Apply a 120 Vac, three-phase voltage source at nominal frequency to terminals C13 (A-phase), 

C14 (B-phase), C15 (C-phase), and C16 (Neutral). Reduce the A-phase voltage to 40 Vac. 
View the Metering screen on the front-panel display to verify that the zero sequence voltage is 
greater than 80 volts. 

Step 25:  Set A-phase current source to 0 amps with an angle of 80 degrees lagging (zero sequence line 

angle) and slowly increase the current until OUT2 closes. Decrease A-phase current until OUT2 
just drops out. Pickup will occur within 

±

2% of the 50-2 pickup setting (1.96 A to 2.04 A). 

Dropout will occur at approximately 95% of the actual pickup value. Verify that there is a 50-2-
67-Residual target on the front-panel display. 

Step 26:  With the same voltage still applied, increase the A-phase current until OUT2 closes. Swing the 

angle of the applied c90 degrees and –90 degrees away from the 80-degree zero-
sequence line angle. Verify that OUT2 opens at approximately 170 degrees lagging and 350 
degrees lagging. OUT2 should remain closed from 170 through 80 to 350 degrees lagging 
(defined as forward trip direction). Steps 23 through 26 verify polarizing reference quantities 
V0IN, with 50-2 set to operate for calculated 3I0 as per Table 217. The 50-2 element can also 
be set to operate for measured ground current IG while still being polarized by V0IN. To verify, 
connect A-phase current in series with IG current. That is, polarity current should go in D1 out 
D2, in D7 out D8. Repeat steps 24 through 26 with 50-2 mode set for IG operate and 50-2 
target set for 50-2-67-IND GND. Verify that there is a 50-2-67-IND GND target on the front-
panel display. 

Step 27:  Set Zero Sequence Mode to VOIG on the Protection, Current, Directional (67-1) screen. The 

polarizing reference quantities are V0 compared to IG measured. This compares calculated V0 
to measured IG (independent ground input). Repeat steps 24 through 26 with A-phase current 
connected in series with IG current. That is, polarity current should go in D1 out D2, in D7 out 
D8.Verify that there is a 50-2-67-IND GND target on the front-panel display. Note that 50-2 can 
also be set to operate for calculated IN (3I0) while still being polarized by V0IG. Verify operation 
by repeating steps 24 through 26 with 50-2 set for 3I0 operate. Verify that there is a 50-2-67-
Residual target on the front-panel display. 

Step 28:  Set Zero Sequence Mode to VXIG on the Protection, Current, Directional (67-1) screen. Set 50-

2 mode to IG on the Protection, Current, Instantaneous Overcurrent (50-2) screen. The 
polarizing reference quantities are an external source of 3V0 applied at the VX input compared 
to measured IG (independent ground input). Apply polarity of a single-phase voltage source (30 
Vac at nominal frequency) to terminal C17 and non-polarity to C18 at an angle of 180 degrees 
lagging. An angle of 180 degrees is used to simulate a broken delta voltage where polarity to 
non-polarity is 180 degrees out of phase with, for example, the A-phase current during an A-
phase to ground fault. The BE1-11

g

 internally compensates for the 180 degree phase difference 

such that polarity voltage from the broken delta source connected to polarity of the BE1-11

g

 

results in a 0 degree condition for a Forward fault. To verify, connect A-phase current in series 
with IG current. That is, polarity current should go in D1 out D2, in D7 out D8. Repeat steps 25 
and 26 with 50-2 set for IG operate. Verify that there is a 50-2-67-IND GND target on the front-

Summary of Contents for BE1-11g

Page 1: ...INSTRUCTION MANUAL FOR BE1 11g Generator Protection System Publication 9424200994 Revision U Jul 17...

Page 2: ......

Page 3: ...onal instruction manuals for the BE1 11g include Modbus communication protocol Basler Electric part number 9424200774 Distributed Network Protocol DNP Basler Electric part number 9424200773 IEC 61850...

Page 4: ...on operation or maintenance For terms of service relating to this product and software see the Commercial Terms of Products and Services document available at www basler com terms This publication con...

Page 5: ...ions 45 Operational Settings 46 Settings Example 47 Sync Check 25 Protection 51 Element Operation 51 Logic Connections 54 Operational Settings 54 Phase Undervoltage 27P Protection 57 Element Operation...

Page 6: ...ization Methods 113 Maximum Torque Angle and Directional Tests 115 Theory of Using Sequence Impedances for Fault Direction 116 Phase Current Differential 87 Protection 119 Element Operation 119 Logic...

Page 7: ...Element Operation 171 Logic Connections 173 Operational Settings 173 Logic Timers 62 175 Element Operation 175 Logic Connections 178 Operational Settings 178 Lockout Functions 86 181 Element Operatio...

Page 8: ...7 Power Quality 239 Power Quality Settings 239 Retrieving Power Quality Data 239 Trip Circuit Monitor 52TCM 243 Element Operation 243 Logic Connections 248 Operational Settings 248 Fuse Loss 60FL 251...

Page 9: ...3 Port Access Setup 344 Access Control 345 Viewing the Security Log 346 Authenticity and Encryption 347 Timekeeping 351 Clock Setup 351 Setting the Time and Date 353 IRIG Port 353 Real Time Clock Spec...

Page 10: ...Report 403 Sync Check 25 Test 405 Functional Test Procedure 405 Functional Test Report 408 Phase Undervoltage 27P Test 411 Functional Test Procedure 411 Functional Test Report 413 Auxiliary Undervolta...

Page 11: ...on Impedance Based 40Z Test 523 Functional Test Procedure 523 Functional Test Report 525 Out of Step 78OOS Test 527 Functional Test Procedure 527 Functional Test Report 530 Synchronizer 25A Test 531 P...

Page 12: ...rvoltage 27 59 631 Overexcitation 24 635 RTD Module 639 Features 639 Functional Description 639 Mounting 639 Connections 640 RTD Module Communications Setup Procedure 644 RTD Module Plugin for BESTCOM...

Page 13: ...s Oscillography and sequential events records can be retrieved from a BE1 11g viewed and printed Front panel features include a large backlit alphanumeric display and LED indicators that display syste...

Page 14: ...ems in a J style case have pushbuttons for selecting and controlling the virtual control switches The LCD has automatic priority logic to govern which metering values are displayed on the screen so th...

Page 15: ...Fourier Transform DFT algorithm The voltage sensing circuits can be configured for single phase three phase three wire or four wire voltage transformer circuits Voltage sensing circuitry provides vol...

Page 16: ...luding user definable logic conditions using BESTlogicPlus Active alarms can be read and reset at the front panel or through the communication ports A historical sequence of events report with time st...

Page 17: ...and optionally if the three phase VT frequency is greater than the auxiliary VT frequency One voltage monitor output 25VM provides independent dead live voltage closing logic Undervoltage 27P and Over...

Page 18: ...E IAC curves four table curves a fixed time curve and a user programmable curve Phase inverse overcurrent elements can be voltage restrained or controlled for generator backup applications Negative se...

Page 19: ...ments provide over undertemperature protection in applications where a remote RTD module is connected to the BE1 11g via Ethernet or RS 485 cable For more information refer to the RTD Module chapter A...

Page 20: ...BE1 11g functionality to match the needs of your operation s practices and power system requirements Metering Functions Metering is provided for the following parameters Primary and secondary voltage...

Page 21: ...9424200994 Rev U 9 BE1 11g Introduction Figure 1 Style Chart...

Page 22: ...10 9424200994 Rev U Introduction BE1 11g...

Page 23: ...e maintenance consists of periodic replacement of the backup battery and periodically checking that the connections between the BE1 11g and the system are clean and tight The front cover should be rem...

Page 24: ...r Up and Activate the BE1 11 Plug In The BE1 11 plugin is a module that runs inside the BESTCOMSPlus shell The BE1 11 plugin contains specific operational and logic settings for only BE1 11 protection...

Page 25: ...supply values listed on the front panel label Wait until the boot sequence is complete Figure 3 PWR Rear Terminals J Type Case ETHERNET WARNING BE1 11 C12 C11 C10 C9 C8 C7 C6 C5 C4 C3 C2 C1 C13 C14 C...

Page 26: ...and this screen will be bypassed in the future Click OK to continue This screen can be accessed later by selecting Tools and Select Language from the menu bar Figure 5 BESTCOMSPlus Select Language Scr...

Page 27: ...6 BESTCOMSPlus Splash Screen Figure 7 Communication Pull Down Menu Figure 8 BE1 11 Connection Screen The BE1 11 plugin opens indicating that activation was successful You can now configure the BE1 11g...

Page 28: ...the BE1 11g is brought into BESTCOMSPlus by downloading settings and logic from the BE1 11g or by selecting application type G on the Style Number screen This gives the user the option of developing a...

Page 29: ...setting and mode the color is gray The Protection Summary screen is available by clicking Protection in the Settings Explorer as shown in Figure 11 Summary screens are also available for General Setti...

Page 30: ...n Step 7 In the Settings Explorer expand Protection Current and select the Instantaneous Overcurrent 50 3 screen See Figure 13 Step 8 Select the Mode 3 Phase and enter settings for Pickup 5 62 A and T...

Page 31: ...9424200994 Rev U 19 BE1 11g Quick Start Figure 13 Instantaneous Overcurrent 50 3 Screen Figure 14 BESTlogicPlus Logic Page 1...

Page 32: ...the 50 3 element is true the label of Output 4 is displayed in the fault report and or sequence of events report The label is named in Step 12 Click the Logic Page 1 tab and then click the I O tab at...

Page 33: ...lt report and or sequence of events report The label is named in Step 13 Click the Logic Page 1 tab and then click the Elements tab at the bottom Locate the User Alarm 1 element Click and drag USERALM...

Page 34: ...d Alarm Configuration User Programmable Alarms and name User Programmable Alarm 1 50 3 Pickup as shown in Figure 21 Step 15 Figure 22 shows the user defined labels of OUT4 and USERALM1 that were named...

Page 35: ...9424200994 Rev U 23 BE1 11g Quick Start Figure 21 User Programmable Alarms Screen Figure 22 OUT4 and USERALM1 with User Defined Labels...

Page 36: ...24 9424200994 Rev U Quick Start BE1 11g...

Page 37: ...hes LED light emitting diode indicator lamps and a multiple line alphanumeric LCD liquid crystal display Illustrations and Descriptions The HMI Human Machine Interface of a BE1 11g in a J type case is...

Page 38: ...er it has been selected using the Select Control Switch L Refer to the Virtual Control Switches 43 chapter for more information about the control switches J USB This universal serial bus port is used...

Page 39: ...iption of all BE1 11g failure alarm diagnostics D E Minor Alarm Major Alarm Indicators These red LEDs light to indicate that a programmable alarm has been set Each indicator can be programmed to annun...

Page 40: ...be to Basler Electric product email announcements Menu Navigation A menu tree with a Metering branch and a Settings branch can be accessed through the front panel controls and display A greater level...

Page 41: ...ttings group and element category scroll to the screen that displays the function to be edited 2 Press the Edit pushbutton to gain access If password security has been initiated for settings you will...

Page 42: ...function is dependent upon the screen that is presently being displayed For example pressing the Reset key when the Demand screen is displayed will reset the demands but it will not reset the alarms...

Page 43: ...HT navigation key to access the menu when targets and alarms are being displayed Figure 26 Front Panel Display Setup Screen Table 4 Settings for Front Panel Display Locator Setting Range Increment Uni...

Page 44: ...32 9424200994 Rev U Controls and Indicators BE1 11g...

Page 45: ...rammable so meaningful labels can be assigned to each input and the logic high and logic low states The BESTlogicPlus chapter provides more information about using contact inputs in your programmable...

Page 46: ...range Figure 27 illustrates the location of the contact sensing jumpers The jumpers are shown in the HIGH position 4 To select operation at the lower end of the control voltage range install the jumpe...

Page 47: ...prepare to place the drawout assembly back into the case 6 Align the drawout assembly with the case guides and slide the assembly into the case 7 Tighten the screws Figure 28 Contact Sensing Jumper Lo...

Page 48: ...act inputs are set using BESTCOMSPlus Each of the inputs has two settings and three labels The settings are Recognition Time and Debounce Time The labels include a label to describe the input a label...

Page 49: ...iseconds are compatible with ac wetting voltages Settings for contact inputs can also be entered through the front panel See the Terminals and Connectors chapter for an illustration of the programmabl...

Page 50: ...ns is monitored by the continuous self test diagnostics function of the relay trouble alarms A detailed list of relay trouble alarms is provided in Table 7 If any one of these points asserts the fails...

Page 51: ...y a hold timer 200 to 2 000 ms can be set with BESTCOMSPlus If the protection engineer desires seal in logic with feedback from the breaker position logic he she can provide this logic by modifying th...

Page 52: ...orer to open the Control Output Override screen Refer to Figure 35 Figure 35 Output Override Screen Enabling Logic Override Control By default logic override control is disabled Output logic override...

Page 53: ...verride State field for the contact output to be controlled Returning a Contact Output to Logic Control When the output logic has been overridden and the contact is held in an energized or de energize...

Page 54: ...42 9424200994 Rev U Contact Inputs and Outputs BE1 11g...

Page 55: ...osely approximates the heating characteristic of the protected equipment as overexcitation increases A linear reset characteristic provides for the decreasing cooling condition The overexcitation elem...

Page 56: ...logic and start the fault recorder logic element FAULTTRIG Assertion of the Pickup output initiates an inverse or definite timer that begins timing to a trip The duration of the timer is established b...

Page 57: ...ndary 0 01 V Hz 0 Alarm Time Delay 0 or 50 to 600 000 varies milliseconds 0 Element Blocking Fuse Loss The fuse loss 60FL element of the BE1 11g can be used to block 24 protection when fuse loss or lo...

Page 58: ...ettings screen Figure 37 in BESTCOMSPlus Setting ranges and defaults are summarized in Table 10 Figure 37 Overexcitation Settings Screen Table 10 Operational Settings Setting Range Increment Unit of M...

Page 59: ...ection Figure 38 and Figure 39 show examples of a transformer and generator limit curve along with the optimum composite protection characteristic Note Actual damage curves must be obtained from the e...

Page 60: ...setting 2 0 and a pickup multiple of 1 2 The total time to trip will be 50 seconds If this exists for 30 seconds before being corrected 60 elapsed time what would the total reset time be for a reset...

Page 61: ...9424200994 Rev U 49 BE1 11g Overexcitation 24 Protection Figure 40 Inverse Time Delay and Reset Time...

Page 62: ...50 9424200994 Rev U Overexcitation 24 Protection BE1 11g...

Page 63: ...tion Freq is the Aux connection 3 Voltage magnitude between sources is less than setting Note The voltage used by the BE1 11g for this feature is a voltage magnitude measurement not a voltage phasor m...

Page 64: ...ons including single phase VTP connections are possible with the Angle Compensation setting That is for a VTP selection of phase to phase and a VTX selection of phase to neutral a value of 30 should b...

Page 65: ...by the Live Voltage setting A dead condition for either phase voltage or auxiliary voltage is determined when the measured voltage on the respective input is equal to or below the dead voltage thresh...

Page 66: ...t logic connections are made on the BESTlogicPlus screen in BESTCOMSPlus The sync check element logic block is illustrated in Figure 42 Logic inputs and outputs are summarized in Table 12 Figure 42 Sy...

Page 67: ...nce 0 or 1 to 50 1 percent 0 Slip Angle 1 to 99 1 degrees 10 Slip Frequency 0 01 to 0 5 0 01 hertz 0 01 Source Freq Destination Freq Disabled or Enabled n a n a Disabled Angle Compensation 0 to 359 9...

Page 68: ...56 9424200994 Rev U Sync Check 25 Protection BE1 11g...

Page 69: ...ting The Two of Three mode activates protection when any two of the three phases of voltage decrease below the Pickup setting The Three of Three mode activates protection when all three phases of volt...

Page 70: ...es of tap TR Time to reset Relevant if 27P x function is set for integrating reset R Constant specific to selected curve Affects the speed of reset when integrating reset is selected Curve constants a...

Page 71: ...n and the element is rearmed for any other occurrences of undervoltage Trip The Trip output becomes true when an undervoltage pickup condition persists for the duration of the element Time Delay setti...

Page 72: ...ic 0 and resetting the element timer Connect the element Block input to the desired logic in BESTlogicPlus When the element is initially selected from the Elements view the default condition of the Bl...

Page 73: ...1 to 300 secondary 0 1 volts 0 Timing Mode Definite or Inverse n a n a Definite Time Delay Definite Timing 50 to 600 000 varies milliseconds 50 Time Dial Inverse Timing 0 to 9 9 0 1 units 0 Curve P T...

Page 74: ...62 9424200994 Rev U Phase Undervoltage 27P Protection BE1 11g...

Page 75: ...or phase unbalance Modes of Protection Five modes of protection are available 3V0 V1 V2 Vx Fundamental and Vx Third Harmonic 3V0 Mode 3V0 mode provides voltage unbalance protection in a three phase sy...

Page 76: ...haracteristic equation When curve P is selected the constants used in the equation are those defined by the user Characteristics for trip and reset programmable curves are defined by Equation 8 and Eq...

Page 77: ...he protection element However the table curve will not be enabled until T1 T2 T3 or T4 is selected as the curve for the protective element Figure 47 Time Undervoltage Characteristic Curves Pickup and...

Page 78: ...locking Fuse Loss The fuse loss 60FL element of the BE1 11g can be used to block 27X protection when fuse loss or loss of potential is detected in a three phase system If the 60FL element trip logic i...

Page 79: ...and defaults are summarized in Table 20 Figure 49 Auxiliary Undervoltage Settings Screen Table 20 Operational Settings Setting Range Increment Unit of Measure Default Mode Disabled 3V0 V1 V2 Vx Funda...

Page 80: ...ng or Instantaneous n a n a Instantaneous A Constant 0 to 600 0 00001 A Constant 1 00000 B Constant 0 to 25 0 00001 B Constant 0 00000 C Constant 1 to 3 0 00001 C Constant 1 00000 N Constant 0 5 to 2...

Page 81: ...on is used to sense power system imbalance This situation occurs when a large single phase load is switched onto the system or when transformer input fuses blow in only one or two phases Negative sequ...

Page 82: ...70 9424200994 Rev U Negative Sequence Voltage 47 Protection BE1 11g...

Page 83: ...of Three mode activates protection when any two of the three phases of voltage increases above the Pickup setting The Three of Three mode activates protection when all three phases of voltage increas...

Page 84: ...les of tap TR Time to reset Relevant if 59P x function is set for integrating reset R Constant specific to selected curve Affects the speed of reset when integrating reset is selected Curve constants...

Page 85: ...delay or calculated inverse time expires the timer and Pickup output are reset no corrective action is taken and the element is rearmed for any other occurrences of overvoltage Trip The Trip output be...

Page 86: ...he default condition of the Block input is a logic 0 Logic Connections Overvoltage element logic connections are made on the BESTlogicPlus screen in BESTCOMSPlus The overvoltage element logic block is...

Page 87: ...0 Timing Mode Definite or Inverse n a n a Definite Time Delay Definite Timing 50 to 600 000 varies milliseconds 50 Time Dial Inverse Timing 0 to 9 9 0 1 units 0 Curve P T1 T2 T3 or T4 n a n a P Reset...

Page 88: ...76 9424200994 Rev U Phase Overvoltage 59P Protection BE1 11g...

Page 89: ...r phase unbalance Modes of Protection Five modes of protection are available 3V0 V1 V2 Vx Fundamental and Vx Third Harmonic 3V0 Mode 3V0 mode provides voltage unbalance protection in a three phase sys...

Page 90: ...cteristic equation When curve P is selected the constants used in the equation are those defined by the user Characteristics for trip and reset programmable curves are defined by Equation 12 and Equat...

Page 91: ...he protection element However the table curve will not be enabled until T1 T2 T3 or T4 is selected as the curve for the protective element Figure 53 Time Overvoltage Characteristic Curves Pickup and T...

Page 92: ...n the 60FL function Protective elements blocked by 60FL should be set so that trip times are 60 milliseconds or greater to assure proper coordination of blocking Block Logic Input The Block input prov...

Page 93: ...or Inverse n a n a Definite Time Delay Definite Timing 50 to 600 000 varies milliseconds 50 Time Dial Inverse Timing 0 to 9 9 0 1 units 0 Curve P T1 T2 T3 or T4 n a n a P Reset Timing Integrating or I...

Page 94: ...82 9424200994 Rev U Auxiliary Overvoltage 59X Protection BE1 11g...

Page 95: ...s winding ground faults in approximately 85 of the winding Faults closer to the generator neutral do not result in high neutral voltage but are detected by the 27X element using third harmonic voltage...

Page 96: ...84 9424200994 Rev U Stator Ground 64G Protection BE1 11g...

Page 97: ...ections A sudden change in generator phase angle often occurs when the grid is lost This change of phase angle results in an earlier zero crossing of the generator voltage if the generator load decrea...

Page 98: ...in BESTlogicPlus When the element is initially selected from the Elements view the default condition of the Block input is a logic 0 Logic Connections Vector jump element logic connections are made o...

Page 99: ...tion Table 29 Operational Settings Setting Range Increment Unit of Measure Default Mode Disabled or Enabled n a n a Disabled Source Phase VT or Aux VT n a n a Phase VT Pickup 0 or 2 to 90 1 degrees 0...

Page 100: ...88 9424200994 Rev U Vector Jump 78V Protection BE1 11g...

Page 101: ...e A and B phase sensing voltage connections Power system frequency is also measured through the BE1 11g auxiliary voltage Vx sensing input Refer to the Typical Connections chapter for information on v...

Page 102: ...ng undervoltage conditions that may occur during equipment startup This setting is expressed in primary or secondary voltage depending on the Settings Display Mode selected on the General Settings Dis...

Page 103: ...f zero 0 makes the 81 element instantaneous with the exception of the pickup detection time If an ROC pickup condition persists for the duration of the element Time Delay setting the element Trip outp...

Page 104: ...p condition Pickup Output True when the 81 element is in a pickup condition Operational Settings Frequency element operational settings are configured on the Frequency settings screen Figure 59 in BES...

Page 105: ...0 1 volts 20 81ROC Over Frequency Inhibit 15 to 110 Hz 0 01 hertz 61 Under Frequency Inhibit 15 to 110 Hz 0 01 hertz 59 Negative Sequence Inhibit 0 to 99 1 percent 20 Phase to phase and phase to neut...

Page 106: ...94 9424200994 Rev U Frequency 81 Protection BE1 11g...

Page 107: ...ence mode the 50 and 51 elements can provide similar increased sensitivity to phase to phase faults because a balanced load has no negative sequence I2 current component Pickup Settings A typical sett...

Page 108: ...p value by the multiplier for phase to ground faults see Table 32 Table 32 Fault Type Multipliers Fault Type Multiplier Ph Ph m 1 732 Ph Ph G m 1 732 Ph G m 3 three phase m infinity For example a down...

Page 109: ...ance Modes of Protection Nine modes of protection are available IA IB IC Three Phase 3I0 I1 I2 IG and Unbalance IA IB or IC Mode The instantaneous overcurrent protection elements include three indepen...

Page 110: ...s to annunciate the condition control other elements in logic and start the fault recorder logic element FAULTTRIG Assertion of the Pickup output initiates a timer that begins timing to a trip The dur...

Page 111: ...n true Trip Output True when the 50 element is in a trip condition Pickup Output True when the 50 element is in a pickup condition Operational Settings Instantaneous overcurrent element operational se...

Page 112: ...r 0 1 to 30 1A CTs secondary 0 or 0 01 to 7 5 SEF secondary varies amps 0 2 to 100 Unbalance mode 1 percent Time Delay 0 to 60 000 varies milliseconds 0 Reset Delay 0 to 60 000 1 milliseconds 0 Direct...

Page 113: ...ignaling that the breaker has failed to open A control timer specifies the duration the breaker can remain closed before a Breaker Fail alarm will occur In both methods above a Breaker Fail Retrip BFR...

Page 114: ...been interrupted without having to wait for the fault current samples to clear the one cycle filter time used by the normal current measurement function This function has less than one cycle dropout...

Page 115: ...Logic Inputs and Outputs Name Logic Function Purpose Block Input Disables the 50BF function when true 50BFI Input Starts the 50BF timer when true 52BFI Input Starts the 50BF timer when true Trip Outpu...

Page 116: ...n a n a Disabled Source CT Circuit1 or CT Circuit 2 n a n a CT Circuit 1 Pickup Phase Ground 0 or 0 25 to 10 00 5A CTs secondary 0 or 0 05 to 2 00 1A CTs secondary 0 or 0 01 to 0 5 SEF secondary varie...

Page 117: ...Settings Explorer Protection Current Inverse Overcurrent 51 HMI Navigation Path Settings Explorer Protection Settings Group x where x 0 to 3 Current Protection Inverse Overcurrent 51 Element Operatio...

Page 118: ...he following paragraphs describe the available timing curves The user can select integrating reset timing to make the protective element use integrated reset and emulate an electromechanical induction...

Page 119: ...reset when integrating reset is selected Curve coefficients are entered on the Inverse Overcurrent 51 settings screen in BESTCOMSPlus Programmable curve coefficients can be entered only when the P cu...

Page 120: ...t pickup condition persists for the duration of the calculated inverse time In BESTlogicPlus the Trip output can be connected to other logic elements and to a physical relay output to annunciate the c...

Page 121: ...straint Pickup Level Phase VT Configuration The 51 27R function can be set to monitor either Vpp or Vpn depending upon the Phase VT Connection settings See the Configuration chapter for details on how...

Page 122: ...See the Fuse Loss 60FL chapter for more information Protective elements blocked by 60FL should be set so that trip times are 60 milliseconds or greater to assure proper coordination of blocking Block...

Page 123: ...A IB IC 3 Phase 3I0 I1 I2 IG or Unbalance n a n a Disabled Source CT Circuit 1 or CT Circuit 2 n a n a CT Circuit 1 Pickup 0 or 0 5 to 16 5A CTs secondary 0 or 0 1 to 3 2 1A CTs secondary 0 or 0 01 to...

Page 124: ...efficient 0 to 600 0 00001 A Coefficient 0 26630 B Coefficient 0 to 25 0 00001 B Coefficient 0 03393 C Coefficient 0 to 1 0 00001 C Coefficient 1 00000 N Coefficient 0 5 to 2 5 0 00001 N Coefficient 1...

Page 125: ...m the phase voltages or VX from a broken delta VT and two forms of zero sequence current available to it calculated I0 from the phase currents or IG from the protection system s IG1 or IG2 input This...

Page 126: ...s as follows Phase mode Positive Sequence Negative Sequence Negative Sequence mode Negative Sequence Neutral mode Negative Sequence Zero Sequence Volt Zero Sequence Current The neutral overcurrent ele...

Page 127: ...ause some applications require a polarizing MTA different from the distance to fault line impedance angle Each MTA can be set over the range of 0 to 90 degrees I lag E in 1 degree steps These paramete...

Page 128: ...nce per half cycle Under sudden current reversal conditions depending on the change in magnitude of the forward current to reverse current the DFT Discrete Fourier Transform could require one cycle to...

Page 129: ...show V0 and V2 at either source V0 and V2 will still be negligible in normal operation and show up only during fault conditions with their maximum value being at the fault location with current flowin...

Page 130: ...1 11g Figure 71 Directional Overcurrent Relaying For more theory and mathematics of using sequence components for sensing direction to fault see the paper Directional Overcurrent Relaying in the DG En...

Page 131: ...olate the protected zone This action limits equipment damage and minimizes impact on the power system Functional Description Figure 72 shows a detailed functional diagram of one phase of the phase dif...

Page 132: ...120 9424200994 Rev U Phase Current Differential 87 Protection BE1 11g Figure 72 87 Phase Differential Protection Functional Block Diagram...

Page 133: ...ut Pickup The phase current differential element asserts the Pickup output in a different manner for each mode Percent Differential Mode The Pickup output becomes true when the ratio of operating curr...

Page 134: ...ove the threshold the percentage restrained output is blocked from setting the Restrained Trip logic output If the second or fifth harmonic inhibit comparators are picked up for any of the three phase...

Page 135: ...Disables the 87 function when true Trip Output True when the 87 element is in a trip condition Pickup Output True when the 87 element is in a pickup condition Unrestrained Trip Output True when the 87...

Page 136: ...ples of tap If the ideal taps calculated by Equation 21 fell within the acceptable range the sensitivity settings will be in Per Unit on the MVA Base used in the equation For example a 100 MVA 115 kV...

Page 137: ...figured on the Phase Current Differential 87 settings screen Figure 75 in BESTCOMSPlus A legend for the chart Figure 76 is shown by clicking the Help button on this screen Setting ranges and defaults...

Page 138: ...en n a n a n a CT Circuit 2 Tap Set on the System Parameters Transformers Setup screen n a n a n a 2nd Slope Pickup 0 or 0 1 to 20 0 01 n a 0 Restraint Slope 2 15 to 140 1 percent 45 Flux Balance Sour...

Page 139: ...t differential element to monitor the ground CT in either CT circuit 1 or CT circuit 2 CT circuit 1 ground terminals are designated D7 and D8 and CT circuit 2 terminals are designated F7 and F8 For an...

Page 140: ...on subsides before the element delay expires the timer and Pickup output are reset no corrective action is taken and the element is rearmed for any other fault occurrences Trip The Trip output becomes...

Page 141: ...lus screen in BESTCOMSPlus The neutral current differential element logic block is illustrated in Figure 78 Logic inputs and outputs are summarized in Table 46 Figure 78 Neutral Current Differential E...

Page 142: ...rized in Table 47 Figure 79 Neutral Current Differential Settings Screen Table 47 Operational Settings Setting Range Increment Unit of Measure Default Mode Disabled or Enabled n a n a Disabled Iop Min...

Page 143: ...IC as the mode of protection for each element relative to each winding or phase to be protected To set the 50 and or 51 elements for three phase operation the three phase mode should be selected Furt...

Page 144: ...option style G6xxxxJxPxxxxx or G6xxxxJxTxxxxx an alternate method can be used to configure self balancing protection In the Phase Differential 87 window of BESTCOMSPlus set the mode to Flux Balance In...

Page 145: ...ad has been connected to a system Overload has been placed on a distribution system Overspeeding is a prime concern An open breaker creates an overload on a local generation facility Mode Four modes o...

Page 146: ...olarity of Voltage and Current Connections Establishing Forward and Reverse Pickup Values Three phase power pickup settings for the power elements are always positive regardless of the directional set...

Page 147: ...increases above or decreases below the threshold established by the Pickup setting In BESTlogicPlus the Pickup output can be connected to other logic elements to annunciate the condition control othe...

Page 148: ...outputs are summarized in Table 48 Figure 84 Power Element Logic Block Table 48 Logic Inputs and Outputs Name Logic Function Purpose Block Input Disables the 32 function when true Trip Output True wh...

Page 149: ...9424200994 Rev U 137 BE1 11g Power 32 Protection Setting Range Increment Unit of Measure Default Direction Forward or Reverse n a n a Forward Over Under Over or Under n a n a Over...

Page 150: ...138 9424200994 Rev U Power 32 Protection BE1 11g...

Page 151: ...ties of vars The 40Q element acts on the principal that if a generator begins to absorb vars outside of its steady state capability curve it has likely lost its normal excitation supply The element is...

Page 152: ...oss of excitation pickup condition exists for the duration of the element Time Delay In BESTlogicPlus the Trip output can be connected to other logic elements and to a physical relay output to annunci...

Page 153: ...ed 40Q settings screen Figure 88 in BESTCOMSPlus Setting ranges and defaults are summarized in Table 51 Figure 88 Loss of Excitation Reverse var Based Settings Screen Table 51 Operational Settings Set...

Page 154: ...142 9424200994 Rev U Loss of Excitation Reverse Var Based 40Q Protection BE1 11g...

Page 155: ...n the generator is not included in the protection system s zone of protection but system backup protection is provided Bus CT Configuration On protection systems equipped with two sets of CTs the 21 e...

Page 156: ...are 60 milliseconds or greater to assure proper coordination of blocking Block Logic Input The Block input provides logic supervision control of the element When true the Block input disables the elem...

Page 157: ...ting Range Increment Unit of Measure Default Select Delta Wye Compensation None DAB 30 or DAC 30 n a n a Disabled Mode Disabled or Enabled n a n a Disabled Diameter 0 to 500 secondary varies ohms 0 Ti...

Page 158: ...146 9424200994 Rev U Distance 21 Protection BE1 11g...

Page 159: ...crosses the R axis The size of the mho circles is defined by their diameter Modes of Protection Three modes of protection are available Non Voltage Control Voltage Control or Both Directional Supervis...

Page 160: ...elements or a physical relay output to annunciate the condition and initiate corrective action If a target is enabled for the element the BE1 11g will record a target when the VC Trip output becomes...

Page 161: ...40Z element is in a trip condition Pickup Output True when the 40Z element is in a pickup condition VC Trip Output Voltage Control pickup VC Pickup Output Voltage Control trip Operational Settings Los...

Page 162: ...o 180 secondary 1 volts 0 Voltage Time Delay 1 2 0 to 300 000 varies milliseconds 0 Typical Application Settings and measurements are used to determine if the measured system impedance is within the t...

Page 163: ...synchronous generator can begin to accelerate due to differences in the mechanical power into the generator and the electrical power at the generator terminals If the power system fault is not cleare...

Page 164: ...established by the Trip Delay setting A Trip Delay of zero 0 makes the 78OOS element instantaneous with no intentional time delay If the pickup condition subsides before the element delay expires the...

Page 165: ...element is in a pickup condition mho Pickup Output Z1 impedance is inside mho circle Blinder A Pickup Output Z1 impedance is to the right of blinder BA and inside mho circle Blinder B Pickup Output Z1...

Page 166: ...0 secondary varies ohms 4 Forward Reach 0 to 500 secondary varies ohms 8 5 Blinder A Offset 0 to 500 secondary varies ohms 2 5 Blinder B Offset 0 to 500 secondary varies ohms 2 5 Blinder Angle 1 to 90...

Page 167: ...e temperature of the RTD is below the Under Pickup setting the element will pick up In Over Under mode if the temperature of the RTD is above the Over Pickup setting or below the Under Pickup setting...

Page 168: ...ic 0 and resetting the element timer Connect the element Block input to the desired logic in BESTlogicPlus When the element is initially selected from the Elements view the default condition of the Bl...

Page 169: ...0 to 250 degrees C Calculated F 1 C degrees 32 Under Pickup 32 to 482 degrees F or 0 to 250 degrees C Calculated F 1 C degrees 32 Time Delay 0 to 600 000 varies milliseconds 0 Voting 1 to 24 1 units...

Page 170: ...158 9424200994 Rev U Resistance Temperature Detector 49RTD Protection BE1 11g...

Page 171: ...to the RTD Module chapter for more information Pickup and Trip The Pickup output occurs first followed by the Trip output Pickup The Pickup output becomes true when the measured remote analog input va...

Page 172: ...ble 60 Figure 99 Remote Analog Input Element Logic Block Table 60 Logic Inputs and Outputs Name Function Purpose Block Input Disables the analog input element when true Trip Output True when the analo...

Page 173: ...Metering Analog input metering values are obtained through BESTCOMSPlus by using the Metering Explorer to open the Analog Metering Analog Inputs tree branch BESTCOMSPlus must be online with the BE1 1...

Page 174: ...162 9424200994 Rev U Analog Input Protection BE1 11g...

Page 175: ...een in BESTCOMSPlus Refer to the Configuration chapter for more information on this setting For clarification on single phase VTP connections refer to the Typical Connections chapter The single phase...

Page 176: ...0 AB ACB AN 69 3 69 3 30 Mode Two operating modes are available Phase Lock Loop and Anticipatory In both modes the BE1 11g adjusts the frequency and voltage of the generator to match that of the bus m...

Page 177: ...angle equals the advance angle Voltage Correction Generator voltage correction is defined by the Voltage Difference setting This setting is expressed as a percentage difference between the generator n...

Page 178: ...tions Protective elements blocked by 60FL should be set so that trip times are 60 milliseconds or greater to assure proper coordination of blocking Block Logic Input The Block input provides logic sup...

Page 179: ...or frequency greater than bus frequency is allowed Voltage magnitude between sources is less than Voltage Difference setting Note The voltage used by the BE1 11g for this feature is a voltage magnitud...

Page 180: ...teria are met Initiated Output True when the 25A has been initiated Close Breaker Output Signals the breaker to close True after the Status output becomes true Volt Monitor Output True when the voltag...

Page 181: ...m slip frequency and breaker closing time Slip Synced Output True when the frequency error between sources is less than the Slip Frequency setting If the Freq Source Freq Dest setting is enabled the g...

Page 182: ...Source Freq Dest Disabled or Enabled n a n a Disabled Voltage Output Mode Continuous or Proportional n a n a Proportional Volt Pulse Width 0 or 0 1 to 5 0 1 seconds 0 5 Volt Pulse Interval 0 or 0 2 to...

Page 183: ...emote operator s console Mode Three operating modes are available Switch Pulse Switch and Pulse Because switch status information is saved in nonvolatile memory the BE1 11g powers up with the switches...

Page 184: ...tch has two tagging modes Informational and Blocking When in Informational mode the switch is still operational when tagged When in the Blocking mode the switch is not operational when tagged Tagging...

Page 185: ...output to true Reset Input Sets the state of the output to false Pulse Input Momentarily changes state of the output Informational Tag Input Sets an informational tag on the 43 element Informational...

Page 186: ...hes Settings Screen Table 66 Operational Settings Setting Range Increment Unit of Measure Default Mode Disabled Switch Pulse Switch or Pulse n a n a Disabled Name Label 64 characters maximum n a n a 4...

Page 187: ...the operator of a condition If a target is enabled for the element the BE1 11g will record a target when the output becomes true See the Fault Reporting chapter for more information about target repor...

Page 188: ...ecomes true Figure 110 One Shot Retriggerable Mode Oscillator Mode In this mode the Initiate input is ignored See Figure 111 If the Block input is false the output oscillates with an ON time T1 and an...

Page 189: ...me action when current is above a certain level for a certain period An instantaneous overcurrent 50 element could be used to monitor the current level Thus if the current level is near the threshold...

Page 190: ...Figure 114 Logic inputs and outputs are summarized in Table 67 Figure 114 Logic Timer Element Logic Block Table 67 Logic Inputs and Outputs Name Logic Function Purpose Initiate Input Starts the 62 ti...

Page 191: ...erational Settings Setting Range Increment Unit of Measure Default Mode Disabled Pickup Dropout One Shot Non Retriggerable One Shot Retriggerable Oscillator Integrating Timer or Latched n a n a Disabl...

Page 192: ...180 9424200994 Rev U Logic Timers 62 BE1 11g...

Page 193: ...breaker opens When the Reset input is asserted the output becomes false breaker closes If both inputs are asserted at the same time the Set input will have priority and drive the output to true The st...

Page 194: ...from the BE1 11g Lockout status can be viewed through BESTCOMSPlus the front panel display and the web page interface To view 86 lockout status using BESTCOMSPlus use the Metering Explorer to open the...

Page 195: ...omentary close spring return trip contact output Trip a momentary close spring return close contact output Close a trip slip contact output TSC and a close slip contact output CSC The trip slip contac...

Page 196: ...h BESTCOMSPlus Use the Metering Explorer in BESTCOMSPlus to open the Control Breaker Control Switch tree branch Click on the Set button for Informational Tag Blocking Tag or both If tagging is success...

Page 197: ...ocking Untag Input Removes the blocking tag from the 101 element Trip Output True if the 101 element is in the Trip state TSC Output True after the Trip output momentarily closes Close Output True if...

Page 198: ...186 9424200994 Rev U Breaker Control Switch 101 BE1 11g...

Page 199: ...e is asserted when each setting group is active These logic variables can be used in programmable logic to modify the logic based upon which setting group is active The SGCACTIVE logic output is asser...

Page 200: ...ot cause a setting group change to SG3 because the AUTOMATIC input is active Figure 123 Input Control Discrete Inputs Binary Inputs When the setting group selection function block is enabled for Binar...

Page 201: ...ctive group then this signal could be monitored to verify that the operation occurred The SGC Active alarm output ON time is user programmable and should be set greater than the SCADA scan rate This c...

Page 202: ...reshold and Switch Time a Return Threshold and Return Time and a Monitor Setting The Switch and Return thresholds are set in amps If you wish to switch settings based upon loading you could set the Mo...

Page 203: ...ed D0 D1 D2 D3 Inputs Meaning depends upon the Mode setting SG0 SG1 SG2 SG3 Outputs True for the active setting group SGCACTIVE Output True when Setting Group Control is Active SGCLOVRD Output True wh...

Page 204: ...that must be exceeded for a setting group change to occur Set in increments of 0 01A secondary amps 0 Switch Time 0 Disabled 1 to 60 minutes Time in minutes that determines when a setting change occur...

Page 205: ...time the alarm is on 5 For protection systems equipped with two sets of CTs Logic Override of the Setting Group Selection Function Setting group control can be overridden to allow manual setting group...

Page 206: ...194 9424200994 Rev U Setting Groups BE1 11g...

Page 207: ...ers in this manual for information on status reports demand power quality and control Metering values can be exported to a csv comma separated values file The Metering Explorer has a docking feature a...

Page 208: ...wing paragraphs For information on power VA and var calculations refer to the Configuration chapter Auto Ranging The BE1 11g automatically scales metered values Table 77 illustrates the ranges for eac...

Page 209: ...ent metering data is found in BESTCOMSPlus Figure 130 and on the Metering Analog Metering Current screen of the front panel display A phasor diagram is also provided in BESTCOMSPlus Figure 130 Analog...

Page 210: ...voltamperes Phases A B C and total phase are included Power Factor Power factor is metered over a range of maximum lagging 0 00 to unity 1 00 to maximum leading 0 00 for phases A B and C and for total...

Page 211: ...Slope Mode Maximum then IOP A 1 2 where ICOMPA1 IA1 TAP1 and ICOMPA2 IA2 TAP2 Equation 27 IOP A Calculation when 87 Mode Phase Differential If 87 Mode Flux Balance then IOP A IA Equation 28 IOP A Cal...

Page 212: ...y Data Equation Watt and var values are updated every 250 milliseconds and watthour and varhour values are logged once every minute Energy registers are stored in nonvolatile memory at 15 minute inter...

Page 213: ...Device A username and password are required to upload data Click Close when finished Figure 136 Meter Energy Editor Screen Analog Inputs and Outputs The following screens are used when an optional RT...

Page 214: ...4 Rev U Metering BE1 11g Figure 138 Analog Metering Analog Outputs Screen RTD Meter Figure 139 illustrates the RTD Meter screen Temperatures are displayed from the optional RTD modules Figure 139 RTD...

Page 215: ...ion lines of the sequence of events records Refer to the BESTCOMSPlus Software chapter for information on BE1 11g identification settings For user programmable logic variables contact sensing inputs c...

Page 216: ...connection to a BE1 11g is present the sequence of events will automatically download Using the Options button you can copy print or save the Sequence of Events The Refresh button is used to refresh u...

Page 217: ...p LED will turn on and remain on as long as the trip expression is true The Trip LED will remain on or sealed in after the trip expression becomes false if targets are associated with the trip The bre...

Page 218: ...ercurrent Independent Ground 50 Pos SEQ Instantaneous Overcurrent Positive Sequence 50 Neg SEQ Instantaneous Overcurrent Negative Sequence 50 Unbalance Instantaneous Overcurrent Unbalance 50 67 A B C...

Page 219: ...Analog In Remote Analog Input Target logging for a protective function can be disabled if the function is used in a supervisory or monitoring capacity The following paragraphs describe how the BE1 11...

Page 220: ...splay in the fault report and in the sequence of events report Figure 144 User Programmable Targets Screen Grouped Targets A grouped target is annunciated when any target in the group is active The gr...

Page 221: ...e BE1 11g provides target information from the most recent trip event Target information is specific to an event it is not cumulative Targets for previous events are recorded in the fault summary repo...

Page 222: ...ew fault summary report is generated the BE1 11g discards the oldest of the 255 events and replaces it with a new one Each fault summary report is assigned a sequential number from 1 to 255 by the BE1...

Page 223: ...ont Panel Display Fault report data for the last 10 faults can be viewed through the front panel display by navigating to Metering Reports Fault Reports Fault Summary Report Items A fault summary repo...

Page 224: ...he pickup expression and the BE1 11g tripped to clear the fault 2 Pickup A fault was detected as defined by the pickup expression but the BE1 11g never tripped indicating that the fault was cleared by...

Page 225: ...s prior to the end of the fault Refer to Figure 150 and Table 83 call out F V0 V1 V2 These lines report the three phase residual positive sequence and negative sequence voltage magnitudes and angles m...

Page 226: ...cle or 512 cycles of data at 32 samples per cycle Refer to Table 81 for Oscillographic Records Settings All channels are recorded IA IA Circuit 2 IB IB Circuit 2 IC IC Circuit 2 IG IG Circuit 2 VA VB...

Page 227: ...describes the power line parameters for which distance is to be computed over The parameters should be entered in units per line length with line length being the actual length of the power line Line...

Page 228: ...fault data along with the line parameters are applied using the Takagi algorithm to determine the impedance of the faulted line The impedance is divided by the impedance per unit length to determine...

Page 229: ...B Targets logged C Fault clearing time calculated D Breaker operate time Oscillographic Record 4 cycle pre trigger Post trigger recording Default 15 cycle record pre trigger 11 cycle post trigger Post...

Page 230: ...aptured two cycles after the trip output goes true This two cycle delay allows the line transients to settle to provide data that is more accurate The post fault current vectors are compared to pre fa...

Page 231: ...ors chapter for more information on the automatic display priority logic A detailed list of alarms is provided in Table 84 Table 84 Available Alarms Name Description 101 Blocking Tag Status 101 breake...

Page 232: ...ide One or more output contacts have logic output override condition Power Loss Alarm Operating power lost Programmable Alarm 1 Programmable alarm 1 is true Programmable Alarm 10 Programmable alarm 10...

Page 233: ...imum exceeded Watt Reverse Demand Reverse watt demand maximum exceeded Alarm Settings BESTCOMSPlus Navigation Path Settings Explorer Alarm Configuration Alarms HMI Navigation Path Not available throug...

Page 234: ...he front panel display navigate to Metering Status Alarms All active alarms will be shown on this screen The front panel navigation keys can be used to scroll through the list of active alarms To view...

Page 235: ...reset through the web page interface Pressing the front panel Reset key clears the alarms and the Major Alarm or Minor Alarm LED Depending on device security setup a username and password may be requi...

Page 236: ...224 9424200994 Rev U Alarms BE1 11g...

Page 237: ...en a new report is generated the BE1 11g discards the old report and replaces it with the new one To view differential reports using BESTCOMSPlus use the Metering Explorer to open the Reports Differen...

Page 238: ...226 9424200994 Rev U Differential Reporting BE1 11g...

Page 239: ...status is programmed using BESTCOMSPlus Use the Settings Explorer to open the BESTlogicPlus Programmable Logic tree branch and select the Breaker Status logic block from the list of Elements Use the d...

Page 240: ...f the two sets of duty registers are reported and monitored when setting up the breaker duty monitor Even though duty register values are calculated and stored in primary amperes or primary amperes sq...

Page 241: ...ogged C Fault clearing time calculated D Breaker operate time Oscillographic Record 4 cycle pre trigger Post trigger recording Default 15 cycle record pre trigger 11 cycle post trigger Post trigger 1...

Page 242: ...protective pickup to perform distance calculations If the Trip expression does not become true the fault was cleared by a down stream device For these pickup only events fault current voltage angle a...

Page 243: ...Purpose Default Mode Disabled or Enabled Disabled Source Select CT Circuit 1 or CT Circuit 2 CT Circuit 1 Exponent 1 to 3 in increments of 0 01 0 Max Duty 0 to 42 000 000 in increments of 1 The Max Du...

Page 244: ...itoring functions Each alarm point can be programmed to monitor any of the three breaker monitoring functions operations counter interruption duty or clearing time An alarm threshold can be programmed...

Page 245: ...nformation on enabling alarms refer to the Alarms chapter Current Demand values are continuously calculated for phase currents IA Circuit 1 IA Circuit 2 IB Circuit 1 IB Circuit 2 IC Circuit 1 IC Circu...

Page 246: ...nd Reverse Var A setting for apparent power threshold is also provided The demand power interval is defined by the Phase Interval setting Enter the appropriate demand power reporting settings Refer to...

Page 247: ...rent Power The Demand Reactive Power and Demand Apparent Power screens are similar Figure 163 Demand Current Screen Figure 164 Demand Power Screen Refer to the BESTnet Plus chapter for information on...

Page 248: ...236 9424200994 Rev U Demands BE1 11g...

Page 249: ...ake approximately 15 minutes for the load step change to reach 90 of the final level Setting the Load Profile Recording Function BESTCOMSPlus Navigation Path Settings Explorer Metering Configuration L...

Page 250: ...238 9424200994 Rev U Load Profile BE1 11g...

Page 251: ...Explorer to open the Metering Configuration Power Quality tree branch The Power Quality screen is illustrated in Figure 166 Figure 166 Metering Configuration Power Quality Screen Table 92 summarizes...

Page 252: ...01 cycles 9 998 s 10 Second Frequency 501 9 998 50 1100 Hz Distortion The voltage during a dip is often distorted This distortion may be important for understanding the effect of the dip on the system...

Page 253: ...creen Harmonics Figure 170 illustrates the Power Quality Harmonic Voltage screen The Harmonic Current screen is similar Figure 170 Power Quality Harmonic Voltage Screen Refer to the BESTnetPlus chapte...

Page 254: ...242 9424200994 Rev U Power Quality BE1 11g...

Page 255: ...eaker Status logic block Refer to the Breaker Monitoring chapter for more information Programmable Alarm A 52 Trip Coil Monitor alarm occurs when the breaker status reporting function detects a closed...

Page 256: ...t Draw for each Power Supply Voltage Rating J Type Case Power Supply Voltage Rating Resistor R Total Optical Isolator Off 25 V On 80 V 24 Vdc R1 R7 2 2 k 15 4 k 6 0 V 0 390 mA 19 2 V 1 25 mA 48 125 Vd...

Page 257: ...e Table 94 Current Draw for each Power Supply Voltage Rating H or P Type Case Power Supply Voltage Rating R1 R2 R Total Optical Isolator Off 25 V On 80 V 24 Vdc 8 2 k 16 4 k 6 0 V 0 36 ma 19 2 V 1 18...

Page 258: ...or advice on this application The circuit monitor sensing element has the same rating as the power supply voltage If the trip circuit voltage is significantly greater than the power supply voltage for...

Page 259: ...the rear terminal block Observe all electrostatic discharge ESD precautions when handling the BE1 11g 2 Locate the jumper terminal block that is mounted on the left side of the circuit board The termi...

Page 260: ...c block is illustrated in Figure 176 The logic output is summarized in Table 95 Figure 176 Trip Circuit Monitor Element Logic Block Table 95 Logic Output Name Logic Function Purpose Alarm Output True...

Page 261: ...9424200994 Rev U 249 BE1 11g Trip Circuit Monitor 52TCM Figure 177 Trip Circuit Monitor Settings Screen Table 96 Operational Settings Setting Range Default Mode Disabled or Enabled Disabled...

Page 262: ...250 9424200994 Rev U Trip Circuit Monitor 52TCM BE1 11g...

Page 263: ...Configuration Fuse Loss 60FL HMI Navigation Path Settings Explorer Alarm Configuration Fuse Loss 60FL Element Operation The 60FL element detects fuse loss and loss of potential by using voltage and c...

Page 264: ...selectable block settings determine how the 51 27 24 25 25A 27 59 78V 27X 59X 32 40Z and 67 protection functions operate when a fuse loss condition exists The Block Voltage Control 51 27 setting assum...

Page 265: ...true Operational Settings Fuse loss element operational settings are configured on the Fuse Loss 60FL settings screen Figure 180 in BESTCOMSPlus Settings are summarized in Table 99 Figure 180 Fuse Los...

Page 266: ...locked when the 60FL logic is true 27X 59X V2 mode Block Power Power Factor Elements All functions that use the power measurements are blocked when the 60FL logic is true 32 Block Impedance Elements A...

Page 267: ...ay Using a web browser enter the IP Address of your BE1 11g in the address bar The protection system s IP address is found on the front panel display under Settings Communication Ethernet Figure 181 s...

Page 268: ...256 9424200994 Rev U BESTnet Plus BE1 11g Figure 183 Real Time Data Page Demand Data Figure 184 illustrates the Demand Data page Present and peak demand values are shown on this page...

Page 269: ...257 BE1 11g BESTnet Plus Figure 184 Demand Data Page Faults Fault Summary Figure 185 illustrates the Fault Summary page To view fault details and download oscillography files click on a fault in the f...

Page 270: ...424200994 Rev U BESTnet Plus BE1 11g Figure 185 Fault Summary Page Fault Details Figure 186 illustrates the Fault Details page Use the buttons to download oscillography files Figure 186 Fault Details...

Page 271: ...the sequence of events is shown on this screen The view can be customized by clicking on View New View Protection View Alarms or View Targets A selected subset of event data can be downloaded as a cs...

Page 272: ...260 9424200994 Rev U BESTnet Plus BE1 11g Figure 188 Power Quality Page...

Page 273: ...le or double case mounting Adapter plates are sold separately A BE1 11g can be mounted at any convenient angle J Type Case Cutouts and Dimensions Front dimensions are shown in Figure 189 and side dime...

Page 274: ...262 9424200994 Rev U Mounting BE1 11g Figure 190 J Type Case Side Dimensions...

Page 275: ...are shown in Figure 191 Figure 191 J Type Case Cutout and Drilling Dimensions 3 03 77 0 6 06 154 0 0 25 6 35 diameter 4 places C L Cut Out 8 63 219 1 0 245 6 2 5 69 144 5 Outer Edge of Cover 0 655 16...

Page 276: ...424200994 Rev U Mounting BE1 11g An adapter plate to mount a J case in a GE S2 or ABB FT 21 cutout is shown in Figure 192 Order Basler part number 9108551021 Figure 192 Adapter Plate Basler P N 910855...

Page 277: ...4200994 Rev U 265 BE1 11g Mounting An adapter plate to mount a J case in a ABB FT 31 FT 32 cutout is shown in Figure 193 Order Basler part number 9108551022 Figure 193 Adapter Plate Basler P N 9108551...

Page 278: ...0994 Rev U Mounting BE1 11g An adapter plate to mount a J case in a GE M1 M2 cutout or Basler M1 cutout is shown in Figure 194 Order Basler part number 9108551029 Figure 194 Adapter Plate Basler P N 9...

Page 279: ...E1 11g Mounting A J case retrofit mounting plate for the Multilin 489 consists of two parts See Figure 195 and Figure 196 Order Basler part number 9424200073 Figure 195 Retrofit Mounting Plate Basler...

Page 280: ...268 9424200994 Rev U Mounting BE1 11g Figure 196 Retrofit Mounting Plate Basler P N 9424200073 Part 2...

Page 281: ...onnections by allowing the BE1 11g to swing left or right Order Basler part number 9424226101 Figure 197 Pivoting Projection Mounting Kit Basler P N 9424226101 H or P Type Case Cutouts and Dimensions...

Page 282: ...270 9424200994 Rev U Mounting BE1 11g Figure 198 H1 Rack Mount Case Dimensions...

Page 283: ...9424200994 Rev U 271 BE1 11g Mounting Figure 199 H1 Panel Mount Case Dimensions...

Page 284: ...n a 19 inch rack see Figure 200 A second adapter bracket 9289929100 performs the same function but includes a cutout for an ABB FT switch see Figure 201 Figure 200 Adapter Bracket for Mounting a Singl...

Page 285: ...Figure 202 should be used If a single H1 BE1 11g P style case is to be panel mounted the cutout and drilling dimensions of Figure 203 should be used Figure 202 Single H1 BE1 11g H Style Case Cutout a...

Page 286: ...0994 Rev U Mounting BE1 11g Mounting plate cutout and drilling dimensions for two dovetailed H1 protection systems are shown in Figure 204 Figure 204 Dovetailed H1 BE1 11g Escutcheon Plate and Cutout...

Page 287: ...panel mount two dovetailed protection systems Figure 205 gives the cutout and drilling dimensions for panel mounting two dovetailed cases without an escutcheon plate Figure 205 Mounting Dimensions fo...

Page 288: ...emove the two screws attaching Terminal Strip A to the rear panel Remove the terminal strip and set it aside Remove the remaining Phillips screw from the rear panel and set the rear panel aside Step 5...

Page 289: ...9424200994 Rev U 277 BE1 11g Mounting Figure 206 Dovetailing Procedure...

Page 290: ...278 9424200994 Rev U Mounting BE1 11g...

Page 291: ...e correct input power for the specified power supply Incorrect wiring may result in damage to the BE1 11g Note Connections to the BE1 11g voltage inputs contact inputs power supply inputs and contact...

Page 292: ...6 A8 A7 A6 A5 A4 A3 A2 A1 IRIG PWR C A B RS 485 GND B8 B7 B6 B5 B4 B3 B2 B1 IN1 IN2 IN3 IN4 D1 D3 D5 D7 IA1 IB1 IC1 IG1 IA1 D2 D4 D6 D8 IB1 IC1 IG1 IA2 F2 F4 F6 F8 IB2 IC2 IG2 F1 F3 F5 F7 IA2 IB2 IC2...

Page 293: ...A6 A5 A4 A3 A2 A1 IRIG PWR C A B RS 485 GND B8 B7 B6 B5 B4 B3 B2 B1 IN1 IN2 IN3 IN4 D1 D3 D5 D7 IA1 IB1 IC1 IG1 IA1 D2 D4 D6 D8 IB1 IC1 IG1 IA2 F2 F4 F6 F8 IB2 IC2 IG2 F1 F3 F5 F7 IA2 IB2 IC2 IG2 ETHE...

Page 294: ...al screws should not exceed 15 inch pounds 1 69 N m Each terminal block screw accommodates a lug no wider than 0 344 inches 8 6 millimeters All other terminal blocks use 6 32 screws The torque applied...

Page 295: ...ation of the BE1 11g The following provides fundamental information on CT polarity and protection systems By ANSI convention current transformer polarity will face away from the protected winding of a...

Page 296: ...284 9424200994 Rev U Terminals and Connectors BE1 11g Figure 213 Standard CT Polarity Figure 214 Current Transformer Action...

Page 297: ...9424200994 Rev U 285 BE1 11g Terminals and Connectors Figure 215 Example of Reversed CT Polarity...

Page 298: ...286 9424200994 Rev U Terminals and Connectors BE1 11g...

Page 299: ...9424200994 Rev U 287 BE1 11g Typical Connections Typical Connections Typical external dc connections for the BE1 11g are shown in Figure 216 Figure 216 Typical External DC Connections...

Page 300: ...8 9424200994 Rev U Typical Connections BE1 11g Typical external ac connections generator differential for the BE1 11g are shown in Figure 217 Figure 217 Typical AC Connections for Generator Differenti...

Page 301: ...9424200994 Rev U 289 BE1 11g Typical Connections Typical external ac connections overall differential for the BE1 11g are shown in Figure 218 Figure 218 Typical AC Connections for Overall Differential...

Page 302: ...290 9424200994 Rev U Typical Connections BE1 11g Three phase voltage sensing alternate VT inputs are shown in Figure 219 Figure 219 Three Phase Voltage Sensing Alternate VTP Inputs...

Page 303: ...al Connections Single phase current sensing connections are shown in Figure 220 Figure 220 Single Phase Current Sensing Connections Note Some elements may not function properly in certain modes when u...

Page 304: ...292 9424200994 Rev U Typical Connections BE1 11g...

Page 305: ...e applications can be used in concert with other Basler numeric systems such as the BE1 851 Overcurrent Protection System the BE1 11f Feeder Protection System or any other member of the BE1 11 family...

Page 306: ...294 9424200994 Rev U Power System Applications BE1 11g Figure 222 One Line Diagram of High Impedance Grounded Generator Protection with Sequential Trip...

Page 307: ...9424200994 Rev U 295 BE1 11g Power System Applications Figure 223 One Line Diagram of Low Impedance Grounded Generator Protection with Sequential Trip...

Page 308: ...296 9424200994 Rev U Power System Applications BE1 11g Figure 224 One Line Diagram of Basic High Impedance Grounded Generator Protection...

Page 309: ...9424200994 Rev U 297 BE1 11g Power System Applications Figure 225 One Line Diagram of Basic Low Impedance Grounded Generator Protection...

Page 310: ...298 9424200994 Rev U Power System Applications BE1 11g Figure 226 One Line Diagram of High Impedance Grounded Generator Protection with Differential and Sequential Trip...

Page 311: ...or activated manually by requesting an activation key from Basler Electric The BE1 11 plugin opens inside the BESTCOMSPlus main shell The same default logic scheme that is shipped with the BE1 11g is...

Page 312: ...ROM drive 2 When the BE1 11 Product CD menu appears click the installation button for BESTCOMSPlus The setup utility installs BESTCOMSPlus the NET Framework if not already installed the USB driver an...

Page 313: ...the following folder C Program Files Basler Electric USB Device Drivers If the USB driver does not install properly refer to the Troubleshooting chapter Start BESTCOMSPlus and Activate BE1 11 Plugin A...

Page 314: ...was successful You can now configure the BE1 11g communication ports and other BE1 11g settings Manual Activation of the BE1 11 Plugin Manual activation of the BE1 11 plugin is required only if your...

Page 315: ...e 233 Activate Device Plugin Entering an Activation Key Select BE1 11 from the Device pull down menu Enter your Email Address and Activation Key provided by Basler Electric If you received an email co...

Page 316: ...munication Communication between BESTCOMSPlus and the BE1 11g is established by clicking on the Connect button on the BE1 11 Connection screen see Figure 231 or by clicking on the Connect button on th...

Page 317: ...rity files and compare settings files The lower menu bar consists of clickable icons The lower menu bar is used to change BESTCOMSPlus views open a settings file connect disconnect preview metering pr...

Page 318: ...he device Reset to Factory Defaults Reset factory defaults in the BE1 11g Available only when the device does not contain default settings Administrator access level is required Upload Settings Logic...

Page 319: ...reen where a preview of the Metering printout is shown Click on the printer button to send to a printer Enables all metering values to be exported into a csv comma separated values file A pull down me...

Page 320: ...e that you want to open Select the file and choose Open You can also open a file by clicking on the Open File button on the lower menu bar If connected to a device you will be asked to upload the sett...

Page 321: ...les BESTCOMSPlus has the ability to compare two settings files To compare files pull down the Tools menu and select Compare Settings Files The BESTCOMSPlus Settings Compare Setup dialog box appears Fi...

Page 322: ...export metering function automatically exports metering data over a user defined period The user specifies the Number of Exports and the Interval between each export Enter a filename for the metering...

Page 323: ...hat CD ROM will also contain the corresponding version of BESTCOMSPlus software You can download the latest version of BESTCOMSPlus by visiting www basler com BESTCOMSPlus automatically checks for upd...

Page 324: ...312 9424200994 Rev U BESTCOMSPlus Software BE1 11g...

Page 325: ...tion and control functions Operating settings and logic settings are interdependent but separately programmed functions Changing logic settings is similar to rewiring a panel and is separate and disti...

Page 326: ...the objects in the I O group Table 103 I O Group Names and Descriptions Name Description Symbol Input Objects Logic 0 Always false Low Double click or right click on the object to change the fixed sta...

Page 327: ...an be found on Selecting the page will take you to that page Alarms Logic Alarm True when the Logic Alarm is true Refer to the Alarms chapter for more information Major Alarm True when the Major Alarm...

Page 328: ...and Dropout Timers Double click or right click on the logic timer to select from timers 1 through 16 Drop Out Timer A drop out timer produces a true output when the elapsed time is greater than or eq...

Page 329: ...to true transition occurs on the Count Down input Double click or right click on the logic counter to select from counters 1 through 8 Other Logic Comment Block The logic comment block is used to plac...

Page 330: ...on chapter 27X x Auxiliary Undervoltage Protection Refer to the Auxiliary Undervoltage 27X Protection chapter 32 x Power Protection Refer to the Power 32 Protection chapter 40Q Loss of Excitation Reve...

Page 331: ...taneous Overcurrent Protection Refer to the Instantaneous Overcurrent 50 Protection chapter 50BF Breaker Fail Protection Refer to the Breaker Fail 50BF Protection chapter 51 x Inverse Overcurrent Prot...

Page 332: ...78V Vector Jump Protection Refer to the Vector Jump 78V Protection chapter 81 x Frequency Protection Refer to the Frequency 81 Protection chapter 87 Current Differential Protection Refer to the Curren...

Page 333: ...ol ANALOG x Analog Input 1 through 8 Refer to the RTD Module chapter Control 25A Synchronizer Refer to the Synchronizer 25A chapter 43 x Virtual Control Switches Refer to the Virtual Control Switches...

Page 334: ...er Control Switch 101 chapter SETTINGGROUP Setting Group Control Refer to the Setting Groups chapter Reporting and Alarms 52TCM Trip Circuit Monitor Refer to the Trip Circuit Monitor 52TCM chapter 60F...

Page 335: ...set The Reset input is positive edge triggered Refer to the Alarms chapter LOGICLABELx Logic Label 1 through 12 The logic label is displayed in the sequence of events when the Trigger input is true To...

Page 336: ...ial system substation A detailed description of the default scheme is also provided The default logic scheme is designed to accommodate most common distribution or sub transmission radial system overc...

Page 337: ...overcurrent conditions All contact sensing inputs are unassigned Operation Setting Group Selection A setting group can be selected automatically or by using the communication ports or the front panel...

Page 338: ...2 On Off OUT3 Timed Phase OC Auxiliary Contact Contact closes when inverse overcurrent 51 1 trip occurs Output 3 On Off OUT4 Instantaneous Neutral and Negative Sequence OC Contact closes when instanta...

Page 339: ...c Scheme from the BE1 11g To retrieve settings from the BE1 11g the BE1 11g must be connected to a computer through a communications port Once the necessary connections are made settings can be downlo...

Page 340: ...ing area and selecting Rename Logic Tabs The following must be met before BESTCOMSPlus will allow logic to be uploaded to the BE1 11g A minimum of two inputs and a maximum of 32 inputs on any multi po...

Page 341: ...to save the logic to memory Changes to the logic other than changing the state are disabled when the simulator is enabled Colors are selected by clicking the Options button on the BESTlogicPlus toolb...

Page 342: ...ESTlogic Plus File Objects in a logic diagram can be locked so that when the logic document is protected these objects cannot be changed Locking and protecting is useful when sending logic files to ot...

Page 343: ...tton to clear the on screen logic diagram on all logic pages and start over BESTlogic Plus Examples Example 1 OR Gate Connections Figure 248 illustrates a typical OR gate connection In this example OU...

Page 344: ...332 9424200994 Rev U BESTlogic Plus BE1 11g...

Page 345: ...ront panel B type USB connector provides local communication with a PC operating BESTCOMSPlus software Ethernet Connection BE1 11g protection systems with style numbers xxxxx1xxxxxxxx xxxxx2xxxxxxxx x...

Page 346: ...he Enable Web Pages box must be checked to enable viewing of BE1 11g web pages Refer to the BESTnet Plus chapter for more information on viewing web pages Figure 251 Ethernet Screen Ethernet Port Conf...

Page 347: ...ss Internet Protocol Address to be used by the BE1 11g Default Gateway Default host to send data destined for a host not on the network subnet Subnet Mask Mask used to determine the range of the curre...

Page 348: ...e verified by selecting Download Settings and Logic from Device from the Communication pull down menu Active settings will be downloaded from the BE1 11g Verify that the downloaded settings match the...

Page 349: ...gure 255 Figure 255 RS485 Setup Screen DNP Setup Settings for DNP are made by using the Settings Explorer to open the Communications DNP tree branch Settings can be made for DNP Analog Points Mapping...

Page 350: ...DNP communication is RS 485 Figure 256 DNP Settings Miscellaneous Settings Screen Unsolicited Response Support The Unsolicited Response Support screen Figure 257 configures BE1 11g unsolicited respon...

Page 351: ...p or Move Down buttons above the analog user map list to arrange the analog user maps 4 Click on the orange Save button to save the settings to BESTCOMSPlus memory This button changes to white indicat...

Page 352: ...ecting Communication from the top pull down menu and then Upload Settings to Device Figure 260 DNP Binary Points Mapping Screen DNP Analog Input and Output Scaling Individual BE1 11g analog inputs and...

Page 353: ...to 247 1 n a 1 Auto Save Disabled or Enabled n a n a Enabled Modbus Mapping Source registers can be mapped to any of 125 available poll block registers ranging from 9875 to 9999 Use the Settings Expl...

Page 354: ...342 9424200994 Rev U Communication BE1 11g Figure 263 Modbus Mapping Screen...

Page 355: ...ng the functional areas that can be accessed through a particular communication port For example security can be configured so that front panel access is permitted at a lower access level than BESTCOM...

Page 356: ...user 7 Re enter the password to verify it 8 Using Table 112 as a reference enter the maximum access level allowed for the user 9 Enter the number of days to expiration of the password or leave at defa...

Page 357: ...eturned to Basler Electric for repair 5 Click the Save Port button to save to the settings to BESTCOMSPlus memory 6 Pull down the Communication menu and select Upload Security to Device The Login dial...

Page 358: ...is A and the default password is A BESTCOMSPlus notifies you when the upload is successful Viewing the Security Log BESTCOMSPlus Navigation Path Metering Explorer Reports Security Log HMI Navigation P...

Page 359: ...rm It is recommended that certificates be uploaded over a trusted connection or through the USB port Generate a Certificate BESTCOMSPlus is used to generate a self signed X 509 certificate for use in...

Page 360: ...ad a Certificate to the Device To upload a security certificate click on the Communication drop down menu in BESTCOMSPlus and select Certificate Upload Certificate to Device Then select the certificat...

Page 361: ...thod a built in Windows mechanism verifies that the certificate chain is signed by a trusted root certificate authority If you upload a certificate chain to the BE1 11g with a root trusted by Windows...

Page 362: ...lock symbol in the lower status bar of BESTCOMSPlus means the connection is secure Remove Accepted Device To remove a previously accepted device click on the Tools drop down menu in BESTCOMSPlus and...

Page 363: ...al Time The Time Zone Offset is required if NTP or IRIG B is used for time synchronization or when the Start End Time Reference is set to UTC Coordinated Universal Time The Start End Time Reference is...

Page 364: ...Offset 59 to 59 1 minutes 0 Time Format 12 Hour or 24 Hour n a n a 24 Hour Date Format YYYY MM DD MM DD YYYY DD MM YYYY n a n a YYYY MM DD DST Configuration Floating Dates or Fixed Dates n a n a Floa...

Page 365: ...ored after an outage and the clock is re synchronized the current year is restored When the clock rolls over to a new year the year is automatically incremented in nonvolatile memory An alarm bit is i...

Page 366: ...ly by qualified personnel Do not short circuit the battery reverse battery polarity or attempt to recharge the battery Observe polarity markings on the battery socket when inserting a new battery The...

Page 367: ...9424200994 Rev U 355 BE1 11g Timekeeping Figure 275 Front Panel Circuit Board Backup Battery Location...

Page 368: ...it from the case Step 3 Remove the old battery Consult your local ordinance for proper battery disposal Step 4 Insert the new battery with the side facing up Step 5 Insert the unit back into the case...

Page 369: ...9424200994 Rev U 357 BE1 11g Timekeeping Figure 277 Digital Circuit Board Backup Battery Location Backup Battery Side Up Front...

Page 370: ...358 9424200994 Rev U Timekeeping BE1 11g...

Page 371: ...in a specific device and appears on labels located on the front panel and inside the case The style number of the BE1 11g is displayed on the BESTCOMSPlus Style Number screen after downloading settin...

Page 372: ...Device Info screen is illustrated in Figure 279 Settings are listed in Table 116 Figure 279 Device Info Screen Table 116 Settings for Device Info Setting Range Default Device ID Up to 64 characters lo...

Page 373: ...front panel is lit and Defaults Loaded is displayed on the Relay Alarms screen To reset the alarm use the Metering Explorer in BESTCOMSPlus to navigate to the Status Alarms screen Figure 281 and click...

Page 374: ...362 9424200994 Rev U Device Information BE1 11g...

Page 375: ...ltage signal and then filtered by an analog low pass anti aliasing filter Current Measurement Functions Input waveforms are sampled by an analog to digital converter ADC at 32 samples per cycle The BE...

Page 376: ...is calibrated to the phase to neutral base Positive sequence measurements can accommodate either ABC or ACB phase sequence Frequency Measurement Power system frequency is monitored on the A phase vol...

Page 377: ...N voltages can be determined by scaling and rotating the measured voltage as follows ABC Rotation AN Sensing 120 1 V V AN BN 120 1 V V AN CN BN Sensing 120 1 V V BN AN 120 1 V V BN CN CN Sensing 120 1...

Page 378: ...oltage as defined by the Aux VT Connection setting on the Sensing Transformers screen in BESTCOMSPlus Current The nominal Secondary Phase Current Inom setting is used by the 60FL function directional...

Page 379: ...ing Range Increment Unit Default Nominal Frequency 25 50 60 or 100 n a hertz 60 Nominal Phase Voltage 50 to 300 0 01 volts 69 3 Nominal Phase Current 0 5 to 15 5A CTs 0 1 to 3 1A CTs varies amps 5 5A...

Page 380: ...I MINp whichever is greater I MIN where MIN or 1 whichever is less MAXp maximum of all three phases MINp minimum of all three phases Connection This setting defines how the sensing CTs are connected f...

Page 381: ...e 118 Figure 283 Sensing Transformers Settings Screen Table 118 Sensing Transformers Settings Setting Range Increment Unit Default Phase Ground CT Ratio 1 to 50 000 0 01 turns ratio 1 Unbalanced Calcu...

Page 382: ...Manual or Automatic n a n a Manual MVA Rating 0 5 to 10 000 0 1 n a 0 5 kV Rating 0 01 to 1 000 n a n a n a Tap 2 to 20 5A CTs or 0 4 to 4 1A CTs 0 01 n a 2 00 CT Connection Set on the Sensing Transf...

Page 383: ...ase with a delta delta transformer the definition of the delta configuration is not important Figure 285 DAB Delta Figure 286 DAC Delta With the appropriate CT and transformer connection information t...

Page 384: ...rameters Transformer Setup screen Settings for the current measurement functions are provided in the following tables These tables indicate the transformer circuit CT settings and type of phase compen...

Page 385: ...E All WYE WYE WYE WYE NONE Special case where all transformer windings and all CTs are connected in wye Table 121 CT Input Circuit Settings 1 for Delta Wye Circuit Applications Transformer Connection...

Page 386: ...ed TX CT Phase Rotation WYE WYE WYE WYE DAB NONE WYE DAB WYE DAB WYE NONE WYE DAC WYE DAC WYE R2 DAB WYE DAB WYE WYE NONE DAC WYE DAC WYE WYE R2 ZAB WYE ZAB WYE WYE NONE ZAC WYE ZAC WYE WYE R2 Table 1...

Page 387: ...T Input Connection BE1 11g Settings Compensation Applied TX CT Phase Rotation WYE DAB WYE DAB DAB NONE WYE DAC WYE DAC DAB R2 DAB WYE DAB WYE DAB NONE DAB DAB DAB DAB WYE NONE DAB DAC DAB DAC WYE R2 D...

Page 388: ...Transformer Connection CT Input Connection BE1 11g Settings Compensation Applied TX CT Phase Rotation ZAB WYE ZAB WYE DAB NONE ZAB DAB ZAB DAB WYE NONE ZAB DAC ZAB DAC WYE R2 ZAC WYE ZAC WYE DAB R2 ZA...

Page 389: ...If there is a ground source within the protected zone the user can apply a numerical zero sequence trap to remove the zero sequence components from the current to prevent misoperation on external gro...

Page 390: ...hase shifting In transformer standards such as IEEE C57 12 00 and IEC 60076 1 there will be many variations on the nomenclature and figures used to show how the phases are identified in a three phase...

Page 391: ...288 IEC Transformer Setup Screen Display Units The Display Units screen is shown in Figure 289 System Units This setting configures the BE1 11g to display and report temperature in English or metric...

Page 392: ...380 9424200994 Rev U Configuration BE1 11g...

Page 393: ...eived system value Acceptance Testing Acceptance testing confirms that a particular BE1 11g delivered to a customer meets published specifications Because this is a numerical device whose characterist...

Page 394: ...propriate detail to satisfy application testing requirements Basler Electric performs a thorough and comprehensive functional test of all protection systems before shipping This ensures that this devi...

Page 395: ...1g functions to determine if the device operated while testing You can simply use an ohmmeter or continuity tester to monitor the output contact status The following is a summary of where target and e...

Page 396: ...384 9424200994 Rev U Introduction to Testing BE1 11g...

Page 397: ...125 Vac dc Gxx2xxxxxxxxxx 125 250 Vac dc Gxx3xxxxxxxxxx 24 Vdc Step 2 Verify that the Power LED is ON and that characters are displayed on the front panel Upon power up the BE1 11g will perform a brie...

Page 398: ...ting contact sensing input jumpers refer to the Contact Inputs and Outputs chapter Step 3 To verify that all inputs have been detected use the Metering Explorer in BESTCOMSPlus to open the Status Inpu...

Page 399: ...0 A 15 amps 14 85 A 15 15 A 20 amps 19 80 A 20 20 A 1 A 0 25 amps 0 2475 A 0 2525 A 1 amps 0 99 A 1 01 A 2 amps 1 98 A 2 02 A 3 amps 2 97 A 3 03 A 4 amps 3 96 A 4 04 A Step 3 To verify IA1 IB1 IC1 and...

Page 400: ...rify voltage measurements Step 2 Connect an ac voltage source at nominal frequency between BE1 11g Terminals C14 B phase and C16 Neutral Terminal Apply 100 volts and verify voltage measuring accuracy...

Page 401: ...ent power should be 1 5 kVA 1 0 at unity power factor The Metering Analog Metering Power VA PF screen of the front panel display can also be monitored to verify apparent power Step 3 Reverse the curre...

Page 402: ...nt panel display can also be monitored to verify voltage measurements Accuracy is 0 5 Table 129 Aux Voltage Circuit Verification VX VX 3rd Values Applied Voltage Measured Voltage Lower Limit Upper Lim...

Page 403: ...ings Explorer in BESTCOMSPlus to open the Programmable Inputs Contact Inputs screen and verify the Input 1 through Input 4 user defined name recognition time debounce time energized state label and de...

Page 404: ...edure described in the Virtual Control Switches 43 chapter Step 4 Verify each switch position change on the Control Virtual Switches screen of BESTCOMSPlus or on the front panel display Step 5 Return...

Page 405: ...allows the user to review only those operations recorded since the sequence of events was last cleared Refer to the Sequence of Events chapter for more detail It may be necessary to disable protection...

Page 406: ...Relay Alarms on the front panel display and press the front panel Reset button Refer to the Alarms chapter for setting details Major Minor Programmable Alarms BESTCOMSPlus Navigation Path Metering Exp...

Page 407: ...er completing the previous steps use the Metering Explorer in BESTCOMSPlus to open the Status tree branch Capture and save the information for Inputs Outputs Alarms Targets and Digital Points This rep...

Page 408: ...396 9424200994 Rev U Commissioning Testing BE1 11g...

Page 409: ...at the digital I O connection and label verification under commissioning tests Monitor SER status and fault reports for proper sensing of digital signals and proper output tripping during normal opera...

Page 410: ...d ensure that the two devices use similar measurement algorithms For example the measurements of a fundamental sensing relay cannot be compared with the measurements of an rms sensing device Functiona...

Page 411: ...perational settings can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings button on the toolbar The actual operating time of an outp...

Page 412: ...Definite Timer 2 Pickup 0 Disables Definite Timer 2 Pickup Alarm Pickup 2 05 Sets Alarm at 102 5 of nominal 2 05 V Hz Step 4 Prepare to monitor the operation of the 24 Alarm and Trip functions Alarm...

Page 413: ...the A phase voltage until OUT2 opens and record the dropout Step 16 Optional Repeat steps 12 through 15 for higher and lower pickup settings Step 17 Optional Repeat steps 12 through 16 for frequencie...

Page 414: ...sables Definite Timer 2 Pickup Alarm Pickup 0 Disables Alarm Pickup Step 2 Connect and apply 120 Vac three phase 60 hertz voltage source to Terminals C13 A phase C14 B phase C15 C phase and C16 neutra...

Page 415: ...s 1 through 5 for settings group 1 2 and 3 Step 7 Optional Set Definite Timer 1 Pickup to 0 and Definite Timer 2 Pickup to 2 36 V Hz and repeat steps 1 through 6 for Definite Timer 2 Functional Test R...

Page 416: ...V 2 945 sec 3 255 sec P F 4 1 0 110 132 V 95 sec 105 sec P F 4 1 0 120 144 V 23 75 sec 26 25 sec P F 4 1 0 140 168 V 5 985 sec 6 615 sec P F 4 2 0 110 132 V 190 sec 210 sec P F 4 2 0 120 144 V 47 5 s...

Page 417: ...pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings button on the toolbar The actual operating...

Page 418: ...as shown in Figure 292 Enable Dead Phase Dead Aux Dead Phase Live Aux Live Phase Dead Aux Figure 292 BESTCOMSPlus Sync Check Screen 25 Voltage Monitor Logic Step 4 Prepare to monitor the 25VM functio...

Page 419: ...olts Measure the time delay and verify the accuracy of the Live dropout delay setting Record the result Step 6 Repeat steps 5 and 6 for the middle and upper time delay settings of Table 139 Step 7 Rem...

Page 420: ...ltage source 1 and 2 until the OUT1 opens Slowly decrease the angle until OUT1 closes Pickup should occur on the leading and lagging side of 0 degrees Dropout should occur on the leading and lagging s...

Page 421: ...5 032 ms P F Sync Check Verification 25 Voltage Difference Accuracy 2 or 1 V whichever is greater Step Voltage Difference Setting Low Actual Pickup High Actual Dropout Pass Fail 5 VTX Voltage Differe...

Page 422: ...410 9424200994 Rev U Sync Check 25 Test BE1 11g...

Page 423: ...ogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down men...

Page 424: ...wly decrease the A phase voltage until OUT2 closes and record the pickup Verify that there is a 27P 1 A target on the front panel display Slowly increase the A phase voltage until OUT2 opens and recor...

Page 425: ...sted Step 7 Optional Repeat steps 1 through 6 through 6 for settings group 1 2 and 3 Step 8 Optional Repeat steps 1 through 7 for 27P 2 27P 3 27P 4 and 27P 5 Functional Test Report Pickup Verification...

Page 426: ...414 9424200994 Rev U Phase Undervoltage 27P Test BE1 11g...

Page 427: ...gs can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings button on the toolbar The actual operating time of an output contact is equ...

Page 428: ...27X 1 function operation Operation can be verified by monitoring OUT2 see Figure 294 Step 5 Connect and apply a 120 Vac a single phase voltage source to terminals C13 A phase and C16 Neutral Reset the...

Page 429: ...the BE1 11g Reset all targets Table 147 Operational Settings V1 Mode Setting Value BESTCOMSPlus Screen Description Phase VT Ratio 1 System Parameters Sensing Transformers Sets phase VT ratio to 1 Pha...

Page 430: ...ntil OUT2 opens and record the reset Reset the target Step 7 Verify the pickup and reset accuracy at 120 Vac for a pickup setting of 38 V 114 Vac on test set and 70 Vac for a pickup setting of 22 V 66...

Page 431: ...9 Mode PN System Parameters Sensing Transformers Sets 27 59 mode to phase neutral Element Mode V2 Protection Voltage Undervoltage 27X 1 Enables 27X 1 function for V2 mode Inhibit Level 10 V Protection...

Page 432: ...or 27X 2 27X 3 and 27X 4 Timing Verification V2 Mode Step 1 Use BESTCOMSPlus to open the Protection Voltage Undervoltage 27X 1 screen and send the first row of test settings in Table 152 to the BE1 11...

Page 433: ...50 ms Step 4 Prepare to monitor the 27X 1 function operation Operation can be verified by monitoring OUT2 see Figure 297 Step 5 Connect and apply a 120 Vac single phase voltage source to the Vx input...

Page 434: ...ication Vx Third Harmonic Mode Step 1 Use BESTCOMSPlus to send the operational settings in Table 156 to the BE1 11g Reset all targets Table 156 Operational Settings Vx Third Harmonic Mode Setting Valu...

Page 435: ...he pickup and reset accuracy at 70 Vac for a pickup setting of 65 V and 25 Vac for a pickup setting of 25 V as listed in Table 157 Record the results Step 8 Optional Repeat steps 1 through 7 for the B...

Page 436: ...ge is calculated from the pickup setting and may need adjusted based on actual pickup Timing Verification 3V0 Mode Time Delay Range 50 to 600 000 ms Timing Accuracy 0 5 or 2 cycles whichever is greate...

Page 437: ...9 1 117 3 P F 7 22 0 66 0 21 0 63 0 23 0 69 0 22 2 66 6 22 6 67 8 P F Reset range is calculated from the pickup setting and may need adjusted based on actual pickup Timing Verification V2 Mode Time De...

Page 438: ...or 1 V whichever is greater Reset Pickup Ratio 102 1 Step Pickup Setting Low Actual Pickup High Low Actual Reset High Pass Fail 6 115 0 V 112 7 V 117 3 V 116 1 V 118 4 V P F 7 65 0 V 63 7 V 66 3 V 65...

Page 439: ...lbar to compile BESTlogicPlus Upload BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to D...

Page 440: ...owly increase the A phase voltage until OUT2 closes and record the pickup Verify that there is a 59P 1 A target on the front panel display Slowly decrease the A phase voltage until OUT2 opens and reco...

Page 441: ...being tested Step 7 Optional Repeat steps 1 through 6 for settings group 1 2 and 3 Step 8 Optional Repeat steps 1 through 7 for 59P 2 59P 3 and 59P 4 Functional Test Report Pickup Verification Pickup...

Page 442: ...430 9424200994 Rev U Phase Overvoltage 59P Test BE1 11g...

Page 443: ...lbar to compile BESTlogicPlus Upload BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to D...

Page 444: ...C phase and C16 neutral Step 6 Slowly increase the A phase voltage until OUT2 closes around 265 volts 150 Vac nominal 115 V 3V0 pickup setting and record the pickup Verify the 59X 1 3V0 target on the...

Page 445: ...ll targets Table 165 Operational Settings V1 Mode Setting Value BESTCOMSPlus Screen Description Phase VT Ratio 1 System Parameters Sensing Transformers Sets phase VT ratio to 1 Phase VT Connection 4W...

Page 446: ...test set as listed in Table 166 Record the results Step 8 Optional Repeat steps 1 through 7 for the B phase and C phase voltage inputs Step 9 Optional Repeat steps 1 through 8 for settings group 1 2 a...

Page 447: ...302 BESTlogicPlus Settings V2 Mode Step 3 Use BESTCOMSPlus to open the Protection Voltage Overvoltage 59X 1 screen and send the first row of test settings in Table 169 to the BE1 11g Table 169 Pickup...

Page 448: ...C16 neutral Step 4 Step the voltage up to 130 volts Measure the time delay and record the result Step 5 Repeat step 4 for the 5 000 ms and 10 000 ms time delay settings of Table 170 Record the result...

Page 449: ...he pickup and dropout accuracy at 70 Vac for a pickup setting of 75 V and 25 Vac for a pickup setting of 30 V as listed in Table 172 Record the results Step 8 Optional Repeat steps 1 through 7 for the...

Page 450: ...Element Mode Vx Third Harmonic Protection Voltage Overvoltage 59X 1 Enables 59X 1 function for Vx Third Harmonic mode Timing Mode Definite Protection Voltage Overvoltage 59X 1 Selects definite timing...

Page 451: ...Vx Third Harmonic Mode Pickup Setting Time Delay 125 V 2 000 ms 125 V 5 000 ms 125 V 10 000 ms Step 2 Prepare to monitor the 59X 1 timings Timing accuracy is verified by measuring the elapsed time be...

Page 452: ...26 0 78 0 25 2 75 6 25 7 77 1 P F Dropout range is calculated from the pickup setting and may need adjusted based on actual pickup Timing Verification V1 Mode Time Delay Range 50 to 600 000 ms Timing...

Page 453: ...ange 50 to 600 000 ms Timing Accuracy 0 5 or 2 cycles whichever is greater Step Time Delay Setting Low Actual Timing High Pass Fail 4 2 000 ms 1 968 ms 2 032 ms P F 5 5 000 ms 4 968 ms 5 032 ms P F 5...

Page 454: ...442 9424200994 Rev U Auxiliary Overvoltage 59X Test BE1 11g...

Page 455: ...BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull do...

Page 456: ...re 305 Step 5 Connect and apply a three phase 120 V phase phase voltage source to terminals C13 A phase and C16 Neutral Step 6 Apply a 20 degree step change to the A phase voltage angle Verify OUT1 cl...

Page 457: ...9424200994 Rev U 445 BE1 11g Vector Jump 78V Test Timing Verification Timing Accuracy 150 ms or less Step Time Delay Actual Timing Pass Fail 6 150 ms P F 7 150 ms P F...

Page 458: ...446 9424200994 Rev U Vector Jump 78V Test BE1 11g...

Page 459: ...selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the...

Page 460: ...f the applied voltage until OUT2 closes and record the pickup Verify that there is an 81 1 Over target on the front panel display Slowly decrease the frequency until OUT2 opens and record the dropout...

Page 461: ...decrease the frequency of the applied voltage until OUT2 closes and record the pickup Verify that there is an 81 1 Under target on the front panel display Slowly increase the frequency until OUT2 ope...

Page 462: ...tion Element Mode Rate of Change Protection Frequency 81 1 Enables 81 1 function for Rate of Change mode Source Phase VT Protection Frequency 81 1 Sets source to Phase VT Pickup 10 Hz sec Protection F...

Page 463: ...peat steps 1 through 11 for settings group 1 2 and 3 Step 13 Optional Repeat steps 1 through 12 for 81 2 81 3 81 4 81 5 81 6 81 7 and 81 8 Time Delay Verification ROC Frequency Time delay verification...

Page 464: ...il OUT2 does not operate Inhibit should occur at 24 volts negative sequence Record the result Step 5 Set the Negative Sequence Inhibit setting to 0 Step 6 To test the frequency limit inhibit function...

Page 465: ...ted from the pickup setting and may need adjusted based on actual pickup Time Delay Verification Time Delay Range 0 to 600 000 ms Timing Accuracy 0 5 or 1 cycle whichever is greater 3 cycles recogniti...

Page 466: ...454 9424200994 Rev U Frequency 81 Test BE1 11g...

Page 467: ...icPlus Upload BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communic...

Page 468: ...until OUT2 opens and record the dropout Step 7 Repeat step 6 for the middle and high range pickup settings for your sensing input type Record the results Step 8 Optional Repeat steps 1 through 7 for...

Page 469: ...ttings in Table 189 to the BE1 11g Reset all targets Table 189 Operational Settings 3I0 Mode Setting Value BESTCOMSPlus Screen Description Phase CT Ratio 1 System Parameters Sensing Transformers Sets...

Page 470: ...sets of CTs In step 5 replace D1 with F1 D2 with F2 etc Timing Verification 3I0 Mode Step 1 Use BESTCOMSPlus to open the Protection Current Instantaneous Overcurrent 50 1 screen and send the first ro...

Page 471: ...cPlus Settings I2 Mode Step 3 Use BESTCOMSPlus to open the Protection Current Instantaneous Overcurrent 50 1 screen and send the low range test settings minimum pickup setting to the BE1 11g for your...

Page 472: ...als D1 and D2 A phase For a single phase input test I2 Ia 3 Therefore the BE1 11g should pick up at a value of three times the setting value when applying only a single phase input For example to dete...

Page 473: ...n can be verified by monitoring OUT2 see Figure 313 Step 5 Connect a current source to terminals D7 and D8 IG Step 6 Slowly increase the ground current until OUT2 closes and record the pickup Verify t...

Page 474: ...1 D2 with F2 etc Functional Test Report Pickup Verification Phase Mode Pickup Setting Range 0 5 to 150 A for 5A sensing 0 1 to 30 A for 1A sensing Pickup Accuracy 2 or 50 mA whichever is greater for 5...

Page 475: ...r cycle whichever is greater 3 cycles max for currents 1 5 x pickup Step Time Delay Setting Low Actual Timing High Pass Fail 4 2 000 ms 1 942 ms 2 058 ms P F 5 5 000 ms 4 927 ms 5 073 ms P F 5 10 000...

Page 476: ...p value Step Pickup Setting Low Actual Pickup High Low Actual Dropout High Pass Fail 6 0 5 A 5A CT 0 45 A 0 55 A 0 465 A 0 495 A P F 7 5 0 A 5A CT 4 9 A 5 1 A 4 65 A 4 95 A P F 7 20 0 A 5A CT 20 6 A 2...

Page 477: ...ting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings button on the toolbar The actual operating time of an output contact is equal to the recognition t...

Page 478: ...tting voltage to IN1 and repeat step 4 There should be no operation Step 6 Repeat step 3 with the delay timer set at 200 ms and 300 ms Record the results The following tests are for Current Supervised...

Page 479: ...F time delay by applying pickup current above 2 A to phase A for at least 100 ms A 50BF Trip should occur Use BESTCOMSPlus to retrieve an SER report and verify that a 50BF Trip was logged 100 millisec...

Page 480: ...peat steps 1 through 12 for the B and C phase elements Note Set 50 1 mode to IB for B phase and IC for C phase Step 14 Optional Repeat steps 7 through 13 with CT Circuit 2 as the source for protection...

Page 481: ...icPlus Upload BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communic...

Page 482: ...ickup Verify that there is a 51 1 A target on the front panel display Slowly decrease the applied current until OUT2 opens and record the dropout Step 7 Repeat step 6 for the middle and high range pic...

Page 483: ...eps 1 through 6 for settings group 1 2 and 3 Step 8 Optional Repeat steps 1 through 7 for 51 2 51 3 51 4 51 5 51 6 and 51 7 Step 9 Optional Repeat steps 1 through 8 with CT Circuit 2 as the source for...

Page 484: ...sing Input Type Range Pickup Setting Time Dial 5 A Low 0 5 A 0 Middle 5 0 A 0 High 16 0 A 0 1 A Low 0 1 A 0 Middle 1 0 A 0 High 3 2 A 0 Step 4 Prepare to monitor the 51 1 function operation Operation...

Page 485: ...e time between the application of current and the closure of OUT1 Record the results Step 5 Repeat step 4 for all of the current and time dial settings for your current sensing type Step 6 Optional Re...

Page 486: ...Settings I2 Mode Step 3 Use BESTCOMSPlus to open the Protection Current Inverse Overcurrent 51 1 screen and send the low range test settings minimum pickup setting to the BE1 11g for your sensing inp...

Page 487: ...test settings in Table 211 to the BE1 11g for settings group 0 Table 211 Timing Test Settings I2 Mode Pickup Setting Time Curve 0 5 A 5 A sensing 0 1 A 1 A sensing I2 Step 2 Prepare to monitor the 51...

Page 488: ...logicPlus programmable logic shown in Figure 319 Blocking is disabled OUT1 closes for 51 1 Trip OUT2 closes for 51 1 Pickup Fault recording is enabled Figure 319 BESTlogicPlus Settings IG Mode Step 3...

Page 489: ...s IG Mode Pickup Setting Time Curve 0 5 A 5 A sensing 0 1 A 1 A sensing I2 Step 2 Prepare to monitor the 51 1 timings Timing accuracy is verified by measuring the elapsed time between a sensing curren...

Page 490: ...A 12 50 A 1 A 0 5 0 20 A 0 50 A 2 50 A 5 0 0 20 A 0 50 A 2 50 A 9 9 0 20 A 0 50 A 2 50 A SEF 0 5 0 20 A 0 50 A 0 80 A 5 0 0 20 A 0 50 A 0 80 A 9 9 0 20 A 0 50 A 0 80 A Functional Test Report Pickup Ve...

Page 491: ...240 sec P F 4 0 5 I2 12 50 A 0 100 sec 0 150 sec P F 4 5 0 I2 1 00 A 4 204 sec 4 647 sec P F 4 5 0 I2 2 50 A 1 798 sec 1 988 sec P F 4 5 0 I2 12 50 A 0 944 sec 1 044 sec P F 4 9 9 I2 1 00 A 8 300 sec...

Page 492: ...0 sec 0 240 sec P F 4 0 5 I2 12 50 A 0 100 sec 0 150 sec P F 4 5 0 I2 1 00 A 4 204 sec 4 647 sec P F 4 5 0 I2 2 50 A 1 798 sec 1 988 sec P F 4 5 0 I2 12 50 A 0 944 sec 1 044 sec P F 4 9 9 I2 1 00 A 8...

Page 493: ...ver is greater Step Time Dial Time Curve Applied Current Low Actual Timing High Pass Fail 4 0 5 I2 3 00 A 0 444 sec 0 491 sec P F 4 0 5 I2 7 50 A 0 190 sec 0 240 sec P F 4 0 5 I2 27 00 A 0 094 sec 0 1...

Page 494: ...A 0 465 A 0 495 A P F 7 0 8 A SEF sensing 0 63 A 0 97 A 0 074 A 0 792 A P F Dropout range is calculated from the pickup setting and may need adjusted based on actual pickup Timing Verification IG Mod...

Page 495: ...nge 0 0 to 9 9 Timing Accuracy 5 or 1 cycles whichever is greater Step Time Dial Time Curve Applied Current Low Actual Timing High Pass Fail 4 0 5 I2 0 20 A 0 444 sec 0 491 sec P F 4 0 5 I2 0 50 A 0 1...

Page 496: ...484 9424200994 Rev U Inverse Overcurrent 51 Test BE1 11g...

Page 497: ...evice from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings button on the...

Page 498: ...rection for 50 2 Directional Source 67 1 Protection Current Instantaneous Overcurrent 50 2 Selects the directional source for the 50 2 Element Mode I2 Protection Current Instantaneous Overcurrent 50 3...

Page 499: ...nt Instantaneous Overcurrent 50 3 Sets 50 3 pickup to 0 amps Positive Sequence Voltage Polarizing Phase Overcurrent Elements Step 4 Connect and apply a 120 Vac three phase voltage source at nominal fr...

Page 500: ...current Elements Step 11 Using Table 219 as a guide send the settings to the BE1 11g Table 219 Directional Negative Sequence Operational Settings Setting Value BESTCOMSPlus Screen Description Pickup 0...

Page 501: ...ence Voltage Polarizing Ground Overcurrent Elements Step 19 Using Table 221 as a guide send the settings to the BE1 11g Table 221 Directional Negative Sequence Polarizing Neutral Operational Settings...

Page 502: ...ground current IG while still being polarized by V0IN To verify connect A phase current in series with IG current That is polarity current should go in D1 out D2 in D7 out D8 Repeat steps 24 through...

Page 503: ...r 180 degrees away from the Positive and Negative Sequence torque angle both at 80 degrees or 260 degrees I lags E in our example Verify that the output contacts remain closed from 170 through 260 to...

Page 504: ...180 to 270 degrees lagging defined as reverse trip direction Step 5 Optional Repeat steps 1 through 5 for 50 4 50 5 and 50 6 Setup commands in Table 217 and operational settings in Table 223 must be...

Page 505: ...ice from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings button on the t...

Page 506: ...ansformer Setup Configures the secondary side for a WYE connection Circuit 2 Ground Compensation No System Parameters Transformer Setup Disables the secondary winding zero sequence trap Optional Circu...

Page 507: ...ion Current Phase Differential 87 Sets the second harmonic restraint threshold to 12 of the fundamental Optional 5th Harmonic 35 Protection Current Phase Differential 87 Sets the fifth harmonic restra...

Page 508: ...d occur at 2 40 A 0 05 A Verify that there is an 87A target on the front panel display Step 14 To test the Restraint Slope 2 setting connect two balanced three phase current sources to the BE1 11g in...

Page 509: ...ling purposes only Circuit 1 Polarity Normal System Parameters Transformer Setup Sets the phase rotation of circuit 1 for ABC Circuit 1 Phase Relationship A System Parameters Transformer Setup Sets A...

Page 510: ...ent Phase Differential 87 Enables the unrestrained element Optional Unrestrained Tripping Pickup 2 Protection Current Phase Differential 87 Sets the operate current pickup for unrestrained tripping to...

Page 511: ...e 2 setting connect two balanced three phase current sources to the BE1 11g in ABC rotation 6 5 0 6 5 120 6 5 120 amps to terminals D1 through D6 and 6 5 180 6 5 60 6 5 60 amps to terminals F1 through...

Page 512: ...t Verification Independent Step 1 Use BESTCOMSPlus to send the operational settings in Table 224 and verify the logic in Figure 321 Reset all targets Step 2 Connect in parallel an A phase current sour...

Page 513: ...z source OUT2 should close immediately and OUT1 after the programmed time delay of 100 ms Verify that there is an 87A target on the front panel display Step 4 Increase the fifth harmonic current sourc...

Page 514: ...w Actual Pickup High Low Actual Dropout High Pass Fail 5 6 MRPU 0 70 A 0 65 A 0 75 A 0 59 A 0 68 A P F 8 9 MRPU 0 30 A 0 25 A 0 35 A 0 28 A 0 39 A P F 11 Slope 1 3 67 A 3 59 A 3 74 A N A N A N A P F 1...

Page 515: ...Accuracy 2 or 0 05A whichever is greater Step Pickup Setting Low Actual Pickup High Pass Fail 5 3 x 0 08 A 3x 0 06 A 3 x 0 10 A P F 5th Harmonic Restraint Verification Independent Pickup Accuracy 2 or...

Page 516: ...504 9424200994 Rev U Phase Current Differential 87 Test BE1 11g...

Page 517: ...BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull dow...

Page 518: ...for pickup to 2 A Time Delay ms 100 Protection Current Neutral Differential 87N 1 Sets the time to trip after a pickup to 100 ms Overcorrection Coefficient 1 30 Protection Current Neutral Differential...

Page 519: ...nal Repeat steps 1 through 10 for CT input 2 and IG2 Step 12 Optional Repeat steps 1 through 11 for settings group 1 2 and 3 Timing Verification Step 1 Use BESTCOMSPlus to verify the operational setti...

Page 520: ...508 9424200994 Rev U Neutral Current Differential 87N Test BE1 11g...

Page 521: ...u or by clicking the Send Settings button on the toolbar The actual operating time of an output contact is equal to the recognition time plus the time delay setting accuracy plus 6 milliseconds Output...

Page 522: ...neutral Connect a variable ac current source to terminals D1 A phase polarity and D2 A phase non polarity Step 3 Set A phase current in phase with the voltage and slowly increase the current from 0 am...

Page 523: ...d C phase currents Consult the Power 32 Protection chapter for operating details Step 6 Optional Repeat Steps 1 through 5 using 32 2 in place of 32 1 Step 7 Optional Repeat Steps 1 through 6 for setti...

Page 524: ...he voltage by 180 degrees noting that OUT2 drops out Slowly decrease the current until OUT2 closes 1 3 of the three phase setting and record the pickup Verify that there is a 32 1 A Under target on th...

Page 525: ...on actual pickup Forward Tripping Direction Underpower Pickup Setting Range 1 to 6 000 Watts for 5A sensing 1 to 1 200 Watts for 1A sensing Pickup Accuracy 3 or 2 W whichever is greater Reset should o...

Page 526: ...514 9424200994 Rev U Power 32 Test BE1 11g...

Page 527: ...d on the toolbar to compile BESTlogicPlus Upload BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload S...

Page 528: ...ty and D2 A phase non polarity Step 5 Set A phase current to lead the voltage by 90 degrees and slowly increase the current from 0 amps until OUT2 closes and record the pickup Verify the 40Q target on...

Page 529: ...6 Optional Repeat steps 1 through 5 for settings group 1 2 and 3 Functional Test Report Pickup Verification Pickup Setting Range 1 to 6 000 var for 5A sensing 1 to 1 200 var for 1A sensing Pickup Acc...

Page 530: ...518 9424200994 Rev U Loss of Excitation Reverse Var Based 40Q Test BE1 11g...

Page 531: ...ication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings button on the toolbar The actual o...

Page 532: ...kup This should occur at 45 282 V 1 569 V Gradually increase the voltage until OUT2 opens and record the reset This should occur at approximately 47 V Reset the target Step 7 Verify the pickup and res...

Page 533: ...meter Setting Range 0 500 secondary Pickup Accuracy 2 or 0 1 whichever is greater Reset Hysteresis 105 of the diameter setting Reset Accuracy 2 or 0 1 whichever is greater Step Pickup Setting Low Actu...

Page 534: ...522 9424200994 Rev U Distance 21 Test BE1 11g...

Page 535: ...located on the toolbar to compile BESTlogicPlus Upload BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting U...

Page 536: ...ation Impedance Based 40Z Sets the supervisory voltage inhibit to 10V mho Characteristic 1 Voltage Time Delay ms 1 000 Protection Impedance Loss of Excitation Impedance Based 40Z Sets the voltage cont...

Page 537: ...balanced three phase 2 0 90 A 2 0 330 A 2 0 210 A to terminals D1 through D6 and a balanced three phase 11 0 0 V 11 0 240 V 11 0 120 V phase neutral voltage source to terminals C13 A phase C14 B phas...

Page 538: ...Fail 5 10 0 V 5 9 70 V 10 3 V P F 6 8 00 V 7 92 V 8 08 V P F Timing Verification mho Characteristic 1 Time Delay Range 0 to 300 000 ms Timing Accuracy 0 5 or 2 cycles whichever is greater Step Time De...

Page 539: ...Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings but...

Page 540: ...nce current required for trip to 5 I2 I1 Ratio 200 Protection Impedance Out of Step 78OOS A trip will not occur if there is twice as much or greater I2 as I1 Step 2 Use BESTCOMSPlus to configure the B...

Page 541: ...by measuring the elapsed time between OUT5 Blinder B pickup closing and OUT2 78OOS pickup closing Timing accuracy for the Trip Delay setting can be verified by measuring the elapsed time between OUT4...

Page 542: ...7 A phase 34 64 V 33 95 V 35 33 V 35 64 V 37 10 V P F 8 9 A phase 73 22 73 57 72 88 73 40 72 70 P F 10 A phase 106 8 107 1 106 4 N A N A N A P F 11 A phase 34 64 V 33 95 V 35 33 V N A N A N A P F Dro...

Page 543: ...Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down menu or by clicking the Send Settings bu...

Page 544: ...ronizer 25A Requires voltage at the phase terminals to be greater than the voltage at the Vx terminals by 0 5 Voltage Output Mode Continuous Control Synchronizer 25A Sets the voltage control output mo...

Page 545: ...1g Step 7 Decrease the voltage until the 25A Volt Diff digital point turns on 69 28 V Record the result Step 8 Slowly decrease the line voltage until the 25A Volt Diff digital point turns off This sho...

Page 546: ...ould occur at 20 1 1 Record the result Step 6 Optional Repeat steps 2 through 5 for settings group 1 2 and 3 Voltage Source Voltage Destination Verification Step 1 Use BESTCOMSPlus to monitor the stat...

Page 547: ...0 Table 240 Sync Fail Settings PLL 25A Setting Value BESTCOMSPlus Screen Description Breaker Close Attempts 3 Control Synchronizer 25A Sets the maximum number of allowable breaker close attempts to 3...

Page 548: ...Hz Min Max Slip Accuracy 0 01Hz Breaker Close Angle Accuracy 1 Test Setting Low Actual High Pass Fail V Increasing 15 79 67 V 78 67 V 80 67 V P F V Decreasing 15 58 89 V 57 89 V 59 89 V P F Slip Freq...

Page 549: ...lement Mode Anticipatory Control Synchronizer 25A Enables 25A function for PLL operation Voltage Difference 15 0 Control Synchronizer 25A Sets the voltage difference requirement to 15 of the nominal s...

Page 550: ...re 329 Blocking is disabled 25A is initiated OUT1 closes for 25A Close Breaker OUT2 closes for Lower Freq OUT3 closes for Raise Freq OUT4 closes for Lower Voltage OUT5 closes for Raise Voltage OUT6 cl...

Page 551: ...hrough 5 for Settings Group 1 2 and 3 Voltage Source Voltage Destination Verification Step 1 Use BESTCOMSPlus to monitor the status of OUT6 Step 2 Connect a balanced three phase voltage source of 69 2...

Page 552: ...60 4 Hz Step 4 Pulse width should be verified by measuring the elapsed time between when the contact closes and when it opens The measured length should be 10 s 50 ms Step 5 Pulse interval should be...

Page 553: ...P F Freq Pulse Width Increasing 10 0 s 9 950 10 050 s P F Freq Pulse Width Decreasing 10 0 s 9 950 s 10 050 s P F Freq Pulse Interval Increasing 5 0 s 4 977 s 5 033 s P F Freq Pulse Interval Decreasi...

Page 554: ...e Logic shown in Figure 331 Blocking is disabled 25A is initiated OUT7 closes for voltage monitor criteria met Event recording is enabled Figure 331 BESTlogicPlus Settings 3 25A Step 3 Use BESTCOMSPlu...

Page 555: ...en and send the first row of test settings in Table 244 to the BE1 11g Table 244 Live Dead Dropout Time Test Settings 25A VM 25A VM Live Voltage 25A VM Dead Voltage 25A VM Drop Out Delay 25A VM Logic...

Page 556: ...Dead Voltage Pickup Test 25A Voltage Monitor Accuracy 2 Step Setting Low Actual High Pass Fail 6 VTP Dead V Dropout 55 0 V 53 9 V 56 1 V P F 7 VTP Live V Pickup 90 0 V 89 2 V 91 8 V P F 9 VTX Dead V D...

Page 557: ...BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull dow...

Page 558: ...and the 43 1 button will have to be selected again Step 6 Click on the 43 1 button a second time to operate it After clicking Yes the On or Off indicator previous state will stop flashing and the On o...

Page 559: ...contact opens and remains open Step 9 Optional Repeat steps 1 through 8 for 43 2 43 3 43 4 and 43 5 Step 10 Optional Repeat steps 1 through 9 for settings group 1 2 and 3 Pulse Mode Step 1 Use BESTCO...

Page 560: ...548 9424200994 Rev U Virtual Control Switches 43 Test BE1 11g...

Page 561: ...logicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting Upload Settings to Device from the Communication pull down me...

Page 562: ...ll stop flashing and the 43 1 button will have to be selected again Step 6 Click on the 43 1 button a second time to operate it After clicking Yes the On or Off indicator previous state will stop flas...

Page 563: ...OFF state to an ON state and then back to an OFF state You can view the state changes of the 43 1 switch at the Metering Control Virtual Switches screen on the front panel display Step 3 Close commun...

Page 564: ...on Targets screen Enables 62 1 target Step 2 Step 4 supplies the 62 1 timer with a momentary initiate input by pulsing the 43 1 switch from an OFF state to an ON state and then back to an OFF state Yo...

Page 565: ...for general use no testing procedure is available Information about Oscillator mode is available in the Logic Timers 62 chapter Integrating Timer Mode Step 1 Use BESTCOMSPlus to send the operational s...

Page 566: ...revious state will stop flashing and the On or Off indicator current new state will light Step 6 Wait no longer than 10 seconds to interrupt time delay 1 Step 7 Repeat steps 4 and 5 to change the stat...

Page 567: ...s 43 Sets 43 1 to Pulse mode 43 2 Mode Pulse Control Virtual Control Switches 43 Sets 43 2 to Pulse mode 62 1 Target Enabled Target Configuration Targets screen Enables 62 1 target Step 2 Use BESTCOMS...

Page 568: ...0 seconds total elapsed time before beginning step 8 Step 8 Using the front panel display navigate to Metering Control Virtual Switches Highlight the second switch 43 2 and press the Right key on the...

Page 569: ...e 342 Latched Mode Functional Test Report Function Pass Fail Pickup Dropout Mode P F One Shot Non Retriggerable Mode P F One Shot Retriggerable Mode P F Oscillator Mode P F Integrating Timer Mode P F...

Page 570: ...558 9424200994 Rev U Logic Timers 62 Test BE1 11g...

Page 571: ...located on the toolbar to compile BESTlogicPlus Upload BESTlogicPlus settings by selecting Upload Logic to Device from the Communication pull down menu Operational settings can be sent by selecting U...

Page 572: ...the 86 1 position is stored in non volatile memory Remove voltage from IN1 Step 7 Connect power supply to IN2 terminals Step 8 Apply voltage to IN2 Verify that OUT1 opens and remains open Step 9 Apply...

Page 573: ...cation pull down menu or by clicking the Send Settings button on the toolbar The actual operating time of an output contact is equal to the recognition time plus the time delay setting accuracy plus 6...

Page 574: ...required The green selection LED will begin to flash Within 25 seconds click on the CLOSE button a second time to operate it The green selection LED will stop flashing and the close status LED will li...

Page 575: ...sure that the contact will stay closed for at least 200 milliseconds See the Contact Inputs and Outputs chapter for additional information on that function Also a Set Priority Latch in BESTlogic Plus...

Page 576: ...tus home page of the web page interface Four on the Metering Explorer Device Info screen of BESTCOMSPlus Features How many overcurrent elements does the BE1 11g have available The BE1 11g has six inst...

Page 577: ...eration of equipment main or auxiliary Proper alarming to SCADA and or targeting If you do not get the results that you expect from the BE1 11g first check the programmable settings for the appropriat...

Page 578: ...stallation Step 2 Open the Windows Device Manger as shown in Figure 347 Right click on BE1 11 or Unknown Device under Other Devices and select Properties Figure 347 Device Manager Step 3 In the Proper...

Page 579: ...BE1 11 Properties Step 4 Select Browse My Computer for Driver Software as shown in Figure 349 Figure 349 Update Driver Software BE1 11 Step 5 Click Browse and navigate to C Program Files Basler Elect...

Page 580: ...ooting BE1 11g Figure 350 Update Driver Software BE1 11 Step 6 If a Windows Security window Figure 351 appears click Install Figure 351 Windows Security Step 7 The window in Figure 352 appears if driv...

Page 581: ...uld be terminated To close front panel access immediately press the Reset button while any menu screen is displayed The BE1 11g should flash Read Only on the LCD screen to indicate access through the...

Page 582: ...is correct Step 4 Verify that the current sensing transformers are correct and properly installed Incorrect Display of Voltage Step 1 Verify that all wiring is properly connected Refer to the Typical...

Page 583: ...teadily when neither expression is true but latched targets exist When resetting a target the Trip LED will not turn off if the fault is still present The truth table of Table 253 serves as an aid to...

Page 584: ...572 9424200994 Rev U Troubleshooting BE1 11g...

Page 585: ...displayed Metered Voltage Values and Accuracy 3 wire Range 50 to 250 Vac 4 wire Range 50 to 250 Vac Auxiliary Range 25 to 125 Vac Phase Auxiliary Accuracy 0 5 of reading or 0 1 of full range whicheve...

Page 586: ...300 000 ms Accuracy 0 5 or 2 cycles whichever is greater Torque Angle Setting Range 0 to 90 degrees Accuracy 1 degree Offset Setting Range 500 to 500 5 Ampere CT Accuracy 3 or 0 2 whichever is greate...

Page 587: ...cy 0 01 Hz Sensing Angle Compensation Setting Range 0 to 359 9 Voltage Monitoring Live Dead Voltage Setting Range 0 to 90 Accuracy 2 Drop Out Delay Setting Range 50 to 60 000 ms Accuracy 0 5 or 2 cycl...

Page 588: ...o 359 9 Voltage Monitoring Live Dead Voltage Setting Range 0 to 90 Accuracy 2 Drop Out Delay Setting Range 50 to 60 000 ms Accuracy 1 or 3 cycles whichever is greater 27P Phase Undervoltage Protection...

Page 589: ...ropout 95 to 99 of the actual pickup value Time Delay Setting Range 50 to 600 000 ms Accuracy 0 5 or 2 cycles whichever is greater 40Q Loss of Excitation Protection Reverse var Based Pickup 5 Ampere C...

Page 590: ...ence current protection is available when a 50 or 51 element is configured in I2 mode Refer to Instantaneous Overcurrent or Inverse Overcurrent for operational specifications 47 Negative Sequence Volt...

Page 591: ...time for instantaneous response 0 0 setting Residual 0 5 or cycle whichever is greater plus trip time for instantaneous response 0 0 setting Trip Time for 0 0 Delay Setting 1 cycles maximum for curre...

Page 592: ...5 A CT units or 30 A for 1 A CT units Refer to the Time Curve Characteristics chapter for information on available timing curves Voltage Restraint Control Restraint Range 30 to 250 V Accuracy 2 or 1 V...

Page 593: ...ured Ground Current VXIN Measured 3V0 VX Input compared to Calculated Zero Sequence Current VXIG Measured 3V0 VX Input compared to Measured Ground Current 78OOS Out of Step Protection Reverse Forward...

Page 594: ...uracy 0 01 Hz Negative Sequence Inhibit Setting Range 0 to 99 of nominal voltage Accuracy 0 5 or 1 V whichever is greater Time Delay Setting Range 0 to 600 000 ms Accuracy 0 5 or 1 cycle whichever is...

Page 595: ...eater 1 Ampere CT Setting Range 0 02 to 1 A Accuracy 5 A CT 3 or 15 mA whichever Overcorrection Coefficient Setting Range 1 to 1 3 Time Delay Setting Range 0 to 60 000 ms Accuracy 0 5 or cycle whichev...

Page 596: ...ng formula I K t where t time in seconds K 6 400 Begins to Clip Saturate 30 A Burden 10 m SEF Continuous Rating 4 A One Second Rating 80 A Begins to Clip Saturate 7 5 A Burden 22 m Terminals CT1 IA1 D...

Page 597: ...ith all outputs energized J Type Case 12 W continuous 14 W maximum with all outputs energized Output Contacts Make and Carry for Tripping Duty 30 A 250 Vdc for 0 2 seconds per IEEE Std C37 90 2005 IEE...

Page 598: ...tage Burden Jumper Installed Low Position Jumper Not Installed High Position Gxx1xxxxxxxxxx 48 Vdc or 125 Vac dc 22 k 53 k Gxx2xxxxxxxxxx 125 250 Vac dc 66 k 123 k Gxx3xxxxxxxxxx 24 Vdc n a 6 k Recogn...

Page 599: ...for the real time clock should be performed only by qualified personnel Observe polarity markings on the battery socket while inserting a new battery The battery polarity must be correct in order to...

Page 600: ...ting Procedures Part 2 Tests Test Ad Cold Type Test IEC 60068 2 2 Basic Environmental Testing Procedures Part 2 Tests Test Bd Dry Heat Type Test IEC 60068 2 28 Environmental Testing Part 2 Testing Gui...

Page 601: ...s may impair suitability for Class 1 Division 2 Do not engage USB unless power has been switched off or the area is known to be non hazardous CSA Certification This product was tested and has met the...

Page 602: ...2 by Advanced Control Systems Inc IEC 61850 Certification KEMA certified per IEC 61850 Certificate Level A Physical IP Class IP50 Case Size Refer to the Mounting chapter Weight H1 Rack Mount H Type C...

Page 603: ...es and Accuracy 3 wire Range 50 to 250 Vac 4 wire Range 50 to 250 Vac Auxiliary Range 25 to 125 Vac Phase Auxiliary Accuracy 1 of reading or 0 2 of full range whichever is greater at 77 F 25 C V1 V2 V...

Page 604: ...nge 0 to 300 000 ms Accuracy 1 5 or 4 cycles whichever is greater Torque Angle Setting Range 0 to 90 degrees Accuracy 1 degree Offset Setting Range 500 to 500 5 Ampere CT Accuracy 5 or 0 4 whichever i...

Page 605: ...z Accuracy 0 01 Hz Sensing Angle Compensation Setting Range 0 to 359 9 Voltage Monitoring Live Dead Voltage Setting Range 0 to 90 Accuracy 2 Drop Out Delay Setting Range 50 to 60 000 ms Accuracy 1 5 o...

Page 606: ...ange 0 to 359 9 Voltage Monitoring Live Dead Voltage Setting Range 0 to 90 Accuracy 2 Drop Out Delay Setting Range 50 to 60 000 ms Accuracy 1 5 or 4 cycles whichever is greater 27P Phase Undervoltage...

Page 607: ...dingly Dropout 95 to 99 of the actual pickup value Time Delay Setting Range 50 to 600 000 ms Accuracy 1 5 or 4 cycles whichever is greater 40Q Loss of Excitation Protection Reverse var Based Pickup 5...

Page 608: ...ive sequence current protection is available when a 50 or 51 element is configured in I2 mode Refer to Instantaneous Overcurrent or Inverse Overcurrent for operational specifications 47 Negative Seque...

Page 609: ...es whichever is greater plus trip time for instantaneous response 0 0 setting Residual 2 or 3 cycles whichever is greater plus trip time for instantaneous response 0 0 setting Trip Time for 0 0 Delay...

Page 610: ...units Refer to the Time Curve Characteristics chapter for information on available timing curves Voltage Restraint Control Restraint Range 30 to 250 V Accuracy 2 or 1 V whichever is greater 59P Phase...

Page 611: ...to Measured Ground Current VXIN Measured 3V0 VX Input compared to Calculated Zero Sequence Current VXIG Measured 3V0 VX Input compared to Measured Ground Current 78OOS Out of Step Protection Reverse...

Page 612: ...1 Hz Accuracy 0 01 Hz Negative Sequence Inhibit Setting Range 0 to 99 of nominal voltage Accuracy 0 5 or 1 V whichever is greater Time Delay Setting Range 0 to 600 000 ms Accuracy 0 5 or 1 cycle which...

Page 613: ...hever is greater 1 Ampere CT Setting Range 0 02 to 1 A Accuracy 3 or 15 mA whichever Overcorrection Coefficient Setting Range 1 to 1 3 Time Delay Setting Range 0 to 60 000 ms Accuracy 1 or 1 cycle whi...

Page 614: ...602 9424200994 Rev U Specifications 25 Hz Operation BE1 11g BESTlogic Plus Update Rate cycle...

Page 615: ...ble Curve functions can be selected Characteristic curves for the inverse and definite time functions are defined by the following equations and comply with IEEE Std C37 112 1996 IEEE Standard Inverse...

Page 616: ...2 0 028 100 P User Programmable 0 to 600 0 to 25 0 to 1 0 5 to 2 5 0 028 0 to 30 T1 User Table 1 n a n a n a n a n a n a T2 User Table 2 n a n a n a n a n a n a T3 User Table 3 n a n a n a n a n a n a...

Page 617: ...11g time dial settings of Basler Electric protection systems are not identical to the settings of electromechanical induction disk overcurrent relays Table 258 helps you convert the time dial setting...

Page 618: ...3 3 3 4 2 5 0 6 0 7 0 7 8 8 8 9 9 L2 GE IAC 66 0 4 0 9 1 8 2 7 3 9 4 9 6 3 7 2 8 5 9 7 n a n a V1 ABB CO 9 0 3 0 7 1 4 2 1 3 0 3 9 4 8 5 7 6 7 7 8 8 7 9 6 V2 GE IAC 53 0 4 0 8 1 6 2 4 3 4 4 3 5 1 6 3...

Page 619: ...e dial range of 0 1 to 9 9 for all the other curves The user should enter the K factor of the generator into the time dial field BE1 11g Equation When the 46 function is used the BE1 11g uses the K fa...

Page 620: ...608 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 355 Time Characteristic Curve S1 Short Inverse Similar to ABB CO 2...

Page 621: ...9424200994 Rev U 609 BE1 11g Time Curve Characteristics Figure 356 Time Characteristic Curve S2 Short Inverse Similar To GE IAC 55...

Page 622: ...610 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 357 Time Characteristic Curve A Standard Inverse BS 142...

Page 623: ...9424200994 Rev U 611 BE1 11g Time Curve Characteristics Figure 358 Time Characteristic Curve A1 Inverse IEC 60255 151 Ed 1...

Page 624: ...612 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 359 Time Characteristic Curve I1 Inverse Time Similar to ABB CO 8...

Page 625: ...9424200994 Rev U 613 BE1 11g Time Curve Characteristics Figure 360 Time Characteristic Curve I2 Inverse Time Similar to GE IAC 51...

Page 626: ...614 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 361 Time Characteristic Curve M Moderately Inverse Similar to ABB CO 7...

Page 627: ...aracteristics Figure 362 Time Characteristic Curve D1 Moderately Inverse IEC 60255 151 Ed 1 0 01 0 10 1 00 10 00 100 00 1000 00 1 10 100 MULTIPLES OF PICKUP TIME IN SECONDS 9 9 9 0 8 0 7 0 6 0 5 0 4 0...

Page 628: ...616 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 363 Time Characteristic Curve L1 Long Inverse Similar to ABB CO 5...

Page 629: ...9424200994 Rev U 617 BE1 11g Time Curve Characteristics Figure 364 Time Characteristic Curve L2 Long Inverse Similar To GE IAC 66...

Page 630: ...618 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 365 Time Characteristic Curve G Long Time Inverse BS 142...

Page 631: ...9424200994 Rev U 619 BE1 11g Time Curve Characteristics Figure 366 Time Characteristic Curve V1 Very Inverse Similar to ABB CO 9...

Page 632: ...620 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 367 Time Characteristic Curve V2 Very Inverse Similar to GE IAC 53...

Page 633: ...9424200994 Rev U 621 BE1 11g Time Curve Characteristics Figure 368 Time Characteristic Curve B Very Inverse BS 142...

Page 634: ...622 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 369 Time Characteristic Curve B1 Very Inverse IEC 60255 151 Ed 1...

Page 635: ...Characteristics Figure 370 Time Characteristic Curve E3 Very Inverse IEC 60255 151 Ed 1 0 01 0 10 1 00 10 00 100 00 1000 00 1 10 100 MULTIPLES OF PICKUP TIME IN SECONDS 9 9 9 0 8 0 7 0 6 0 5 0 4 0 3...

Page 636: ...624 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 371 Time Characteristic Curve E1 Extremely Inverse Similar to ABB CO 11...

Page 637: ...9424200994 Rev U 625 BE1 11g Time Curve Characteristics Figure 372 Time Characteristic Curve E2 Extremely Inverse Similar to GE IAC 77...

Page 638: ...626 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 373 Time Characteristic Curve C Extremely Inverse BS 142...

Page 639: ...9424200994 Rev U 627 BE1 11g Time Curve Characteristics Figure 374 Time Characteristic Curve C1 Extremely Inverse IEC 60255 151 Ed 1...

Page 640: ...istics BE1 11g Figure 375 Time Characteristic Curve F1 Extremely Inverse IEC 60255 151 Ed 1 0 01 0 10 1 00 10 00 100 00 1000 00 1 10 100 MULTIPLES OF PICKUP TIME IN SECONDS 9 9 9 0 8 0 7 0 6 0 5 0 4 0...

Page 641: ...9424200994 Rev U 629 BE1 11g Time Curve Characteristics Figure 376 Time Characteristic Curve D Definite Time Similar To ABB CO 6...

Page 642: ...tic Curve NOTE Curves are shown as extending farther to the left than they will in practice Curves stop at pickup level For example if the user selects 5A FLC and a pickup setting of 0 5A the per unit...

Page 643: ...The undervoltage inverse time curve is defined by Equation 42 The undervoltage inverse time curve with default constants is shown in Figure 378 Equation 42 2 1 Equation 43 TT Time to trip when M 1 TR...

Page 644: ...9424200994 Rev U Time Curve Characteristics BE1 11g Figure 378 Undervoltage 27 Inverse Time Curve Default Constants 0 10 1 00 10 00 100 00 0 1 TIME IN SECONDS MULTIPLES OF PICKUP 9 9 9 8 7 6 5 4 3 2 1...

Page 645: ...e inverse time curve with default constants is shown in Figure 379 Equation 44 2 1 Equation 45 TT Time to trip when M 1 TR Time to reset if BE1 11g is set for integrating reset when M 1 Otherwise rese...

Page 646: ...ime Curve Characteristics BE1 11g Figure 379 Overvoltage 59 Inverse Time Curve Default Constants 0 10 1 00 10 00 100 00 1 1 1 1 2 1 3 1 4 1 5 1 6 1 7 1 8 1 9 2 TIME IN SECONDS MULTIPLES OF PICKUP 9 9...

Page 647: ...onds minimum TT DT V Hz Measured V Hz Nominal 1 n Equation 46 Time to Trip TR DR ET FST 100 Equation 47 Time to Reset where TT Time to trip TR Time to reset DT Time dial trip DR Time dial reset ET Ela...

Page 648: ...636 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 380 V Hz Characteristic M 1 0 5 Time on Vertical Axis Figure 381 V Hz Characteristic M 1 0 5 Time on Horizontal Axis...

Page 649: ...9424200994 Rev U 637 BE1 11g Time Curve Characteristics Figure 382 V Hz Characteristic M 1 1 Time on Vertical Axis Figure 383 V Hz Characteristic M 1 1 Time on Horizontal Axis...

Page 650: ...638 9424200994 Rev U Time Curve Characteristics BE1 11g Figure 384 V Hz Characteristic M 1 2 Time on Vertical Axis Figure 385 V Hz Characteristic M 1 2 Time on Horizontal Axis...

Page 651: ...uts for monitoring system temperatures Each RTD input can be configured to protect against high or low temperature conditions The label text of each RTD input is customizable Analog Outputs The RTD mo...

Page 652: ...ation Incorrect wiring may result in damage to the module Note Be sure that the RTD module is hard wired to earth ground with no smaller than 12 AWG 3 31 mm2 copper wire attached to the chassis ground...

Page 653: ...ower inputs are not polarity sensitive Operating power terminals are listed in Table 259 Table 259 Operating Power Terminals Terminal Description TB1 1 Operating power input TB1 2 Operating power inpu...

Page 654: ...shown in Figure 389 When using the current input AIN V and AIN I must be tied together 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 48 47 46 45 44 43 42 41 4...

Page 655: ...Connections External 2 wire RTD input connections are shown in Figure 390 Figure 391 shows external 3 wire RTD input connections Figure 390 External Two Wire RTD Input Connections AIN I AIN AIN V RTD...

Page 656: ...e of the following procedures to set up the RTD module It is assumed that the BE1 11g is already connected to the PC or network Procedure 1 The PC and BE1 11g are connected through a network or the PC...

Page 657: ...ettings file for the RTD module click the Ethernet button under Device Discovery to scan for connected devices 17 After scanning for connected devices the Device Discovery screen appears 18 Use the co...

Page 658: ...dule to send a broadcast request for configuration information The DHCP server receives the request and responds with configuration information DHCP is disabled by default To enable check the DHCP box...

Page 659: ...11 plugin in BESTCOMSPlus and connect to the BE1 11g 21 Use the Settings Explorer to open the Remote Module Communications screen under System Parameters 22 Set the Status to Enabled Set Communicatio...

Page 660: ...Splash Screen The BESTCOMSPlus platform window opens Select New Connection from the Communication pull down menu and select RTD Module See Figure 396 The RTD Module plugin is activated automatically a...

Page 661: ...n Figure 399 appears Use the computer mouse to highlight the desired RTD module and click the Connect button or proceed to configure communications as explained in the next paragraph The RTD Module pl...

Page 662: ...ears You must contact Basler Electric for an activation key before you can activate the RTD Module plugin You can request an activation key through email or the Basler Electric website Click either th...

Page 663: ...s this unique ID to communicate with the connected RTD module To obtain metering values in BESTCOMSPlus or through the BE1 11g front panel display the same ID must be entered on the Remote Module Comm...

Page 664: ...nalog inputs easier a user assigned name can be given to each input Protection settings for remote analog inputs are described in the Analog Input Protection chapter Configuration Settings BESTCOMSPlu...

Page 665: ...s at once Configuration Settings BESTCOMSPlus Navigation Path Settings Explorer Programmable Outputs Remote Analog Outputs HMI Navigation Path Settings Explorer Analog Outputs Configuration settings a...

Page 666: ...rd Harmonic V secondary IA Circuit 1 IB Circuit 1 IC Circuit 1 3I0 Circuit 1 I1 Circuit 1 I2 Circuit 1 IG Circuit 1 A secondary IA Circuit 2 IB Circuit 2 IC Circuit 2 3I0 Circuit 2 I1 Circuit 2 I2 Cir...

Page 667: ...cted range for a properly functioning RTD Exceeding the range indicates that the RTD may be shorted or open and cannot be relied on to provide thermal detection Table 265 defines the resistance and eq...

Page 668: ...ts can be set for RTD Group 1 2 3 4 5 6 or 7 Refer to the Resistance Temperature Detector 49RTD Protection chapter for information on setting 49RTD protection elements Figure 409 RTD Configuration Blo...

Page 669: ...An RTD module with part number 9444100100 is equipped with only a copper Ethernet connection Copper Type RJ45 Connector Version 10BASE T 100BASE TX Maximum Length One Network Segment 328 ft 100 m Fibe...

Page 670: ...2014 35 EU EMC 2014 30 EU Harmonized Standards used for evaluation EN 50178 1997 Electronic Equipment for use in Power Installations EN 61000 6 4 2001 Electromagnetic Compatibility EMC Generic Standar...

Page 671: ...ir procedures be attempted by anyone other than Basler Electric personnel Before returning the RTD module for repair contact the Basler Electric Technical Services Department at 618 654 2341 for a ret...

Page 672: ...660 9424200994 Rev U RTD Module BE1 11g...

Page 673: ...571 25A Block 1564 25A Close Breaker 1573 25A Freq Lower 1569 25A Freq Raise 1568 25A Initiate 1575 25A Lowering Freq 1580 25A Lowering Volts 1578 25A Protection Initiated 1583 25A Raising Freq 1579 2...

Page 674: ...mation Tag Status 542 Name Number 43 2 Pulse 532 43 2 Reset 533 43 2 Set 534 43 2 Tag Block 537 43 2 Tag Information 538 43 2 Untag Block 539 43 2 Untag Information 540 43 3 546 43 3 Blocking Tag Stat...

Page 675: ...TD 2 9 1951 49RTD 11 Trip 1930 49RTD 12 Block 1955 49RTD 12 Pickup 1956 49RTD 12 RTD 1 1 1958 49RTD 12 RTD 1 10 1967 Name Number 49RTD 12 RTD 1 11 1968 49RTD 12 RTD 1 12 1969 49RTD 12 RTD 1 2 1959 49R...

Page 676: ...01 49RTD 3 RTD 1 8 1102 49RTD 3 RTD 1 9 1103 49RTD 3 RTD 2 1 1107 49RTD 3 RTD 2 10 1116 49RTD 3 RTD 2 11 1117 49RTD 3 RTD 2 12 1118 Name Number 49RTD 3 RTD 2 2 1108 49RTD 3 RTD 2 3 1109 49RTD 3 RTD 2...

Page 677: ...TD 2 9 1843 49RTD 7 Trip 1822 49RTD 8 Block 1847 49RTD 8 Pickup 1848 49RTD 8 RTD 1 1 1850 49RTD 8 RTD 1 10 1859 49RTD 8 RTD 1 11 1860 Name Number 49RTD 8 RTD 1 12 1861 49RTD 8 RTD 1 2 1851 49RTD 8 RTD...

Page 678: ...uence 243 50 4 67 Residual 240 50 4 67 Unbalance 245 50 4 A 230 50 4 B 231 50 4 Block 227 50 4 C 232 50 4 Independent Ground 235 Name Number 50 4 Negative Sequence 233 50 4 Pickup 228 50 4 Positive Se...

Page 679: ...Unbalance 365 51 4 67T A 356 51 4 67T B 357 51 4 67T C 358 51 4 67T Independent Ground 361 51 4 67T Negative Sequence 359 Name Number 51 4 67T Positive Sequence 363 51 4 67T Residual 360 51 4 A 350 51...

Page 680: ...9X 2 Trip 132 59X 2 V1 137 59X 2 V2 134 59X 3 3rd Harmonic 144 59X 3 3V0 141 59X 3 Aux 143 59X 3 Block 138 59X 3 Pickup 139 59X 3 Trip 140 Name Number 59X 3 V1 145 59X 3 V2 142 59X 4 3rd Harmonic 152...

Page 681: ...81 4 ROC 496 81 4 Trip 493 81 4 Under 495 81 5 Block 497 81 5 Over 500 81 5 Pickup 498 81 5 ROC 502 81 5 Trip 499 81 5 Under 501 81 6 Block 503 Name Number 81 6 Over 506 81 6 Pickup 504 81 6 ROC 508 8...

Page 682: ...uit 2 I2 Demand 842 CT Circuit 2 IG Demand 843 CT Circuit 2 IP Demand 841 CT Circuit 2 Unbalance Block 847 CTLGGIO1 SPCSO1 1584 CTLGGIO1 SPCSO1 Alarm 1586 CTLGGIO1 SPCSO1 Default 1585 CTLGGIO1 SPCSO10...

Page 683: ...IO3 SPCSO2 Default 1684 CTLGGIO3 SPCSO3 1686 CTLGGIO3 SPCSO3 Alarm 1688 CTLGGIO3 SPCSO3 Default 1687 CTLGGIO3 SPCSO4 1689 Name Number CTLGGIO3 SPCSO4 Alarm 1691 CTLGGIO3 SPCSO4 Default 1690 CTLGGIO3 S...

Page 684: ...iled 2097 Ethernet Excess Traffic 766 Ethernet Link Lost 735 Fault Report Timeout 749 Firmware Change 733 Flash Error 723 Name Number Frequency Out Of Range 734 Front Panel Indicator 1 1529 Front Pane...

Page 685: ...tate 669 Input 5 State 878 Input 6 State 879 Input 7 State 880 Input 8 State 881 Input 9 State 882 Input Contact 52 TCM 670 IRIG Sync Lost 737 Logic Alarms Alarm Output 1814 Logic Alarms Alarm Reset 1...

Page 686: ...Programmable Alarm 8 757 Programmable Alarm 9 758 Protection Control File Defaults Loaded 2146 Protection Control File No User Set Alarm 2145 Protection Control File Nonvolatile Memory Drive Error 215...

Page 687: ...Data HMI Target Reset 715 System Data Logic 0 707 System Data Logic 1 708 Name Number System Data Logic Trigger 713 System Data Pickup Logic 711 System Data Power Up 709 System Data Rotation Reversal...

Page 688: ...er User Programmable Target 6 2060 User Programmable Target 7 2061 User Programmable Target 8 2062 User Programmable Target 9 2063 VA Demand 657 Name Number var Negative Demand 654 var Positive Demand...

Page 689: ...nd BESTCOMSPlus are listed in Table 267 Table 267 System Recommendations for BESTCOMSPlus and the NET Framework System Type Component Recommendation 32 64 bit Processor 2 0 GHz 32 64 bit RAM 1 GB mini...

Page 690: ...ns product specific options for the default behavior of the BESTCOMSPlus Settings Loader Tool These settings are described in the following paragraphs Loader Grid One entry or row in the Loader Grid c...

Page 691: ...the Loader Grid select the entry and click the Delete button A prompt appears providing the option to confirm or cancel the deletion Uploading an Entry Select an entry and click Upload A dialog appea...

Page 692: ...e security settings stored in the settings file are uploaded to the device Credentials will be requested if not already specified Figure 412 illustrates the Setting Files tab Figure 412 Configuration...

Page 693: ...odes 1 Power on the device which will receive the new settings Ensure proper communication connections have been made between the device and the PC running BESTCOMSPlus Settings Loader Tool 2 Run BEST...

Page 694: ...682 9424200994 Rev U BESTCOMSPlus Settings Loader Tool BE1 11g...

Page 695: ...Nov 11 Released BESTCOMSPlus version 2 11 01 and BE1 11g firmware version 2 05 00 O This revision letter not used P Sep 12 Improved keyboard Q This revision letter not used R Oct 12 Released BESTCOMSP...

Page 696: ...of hold attribute on contact outputs Improved three wire power metering 1 03 01 May 10 Improved low voltage metering Improved 81R rate of change of frequency function Improved resolution of values on...

Page 697: ...h bad user names Improved reporting of breaker operate time Added logic nodes and made minor improvements to IEC 61850 protocol 2 08 00 Apr 14 Added a Language Selection setting to choose language for...

Page 698: ...00 Nov 15 Added a second Directional element 67 2 Added ability to use complex passwords Added Disabled parameter selection for remote analog outputs Added saving of differential reports to non volat...

Page 699: ...Added contact output Hold Time setting range Added Calculation Type setting for the 50 element Added variable inverse voltage curves for the 27P 27X 59P and 59X elements Added Logic Alarms Status and...

Page 700: ...firmware dependent Added Logic Labels to BESTLogicPlus firmware dependent Added Auto Export Metering function Added P case option on Style Number screen Implemented IEC 61850 protocol option 2 08 01 O...

Page 701: ...ll open views Changed to hide security settings for the RTD module when opening a settings file Changed to allow the middle mouse button to close the security view Changed to make BESTlogicPlus status...

Page 702: ...ted USB driver installer for improved Windows 10 compatibility Corrected issue with settings printout Table 271 Instruction Manual Revision History Manual Revision and Date Change Jun 09 Initial relea...

Page 703: ...n in the Power Quality chapter Added Figure 206 Single Phase Current Sensing Connections in the Typical Connections chapter Added Specifications 25 Hz Operation chapter Added Digital Points chapter K...

Page 704: ...owing primary and secondary values Added Units of Selectable Parameters table in the RTD Module chapter Added BESTCOMSPlus Settings Loader Tool chapter Minor text edits Q This revision letter not used...

Page 705: ......

Page 706: ...basler com No 59 Heshun Road Loufeng District N Suzhou Industrial Park 215122 Suzhou P R CHINA Tel 86 512 8227 2888 Fax 86 512 8227 2887 email chinainfo basler com 111 North Bridge Road 15 06 Peninsul...

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