Basler BE1-CDS220 Instruction Manual Download Page 8

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Introduction BE1-CDS220

Hardware

Version/Date Change

L/03-01

Changed clearance around Q3 on power supply to prevent shorts.

K/09-00

Improved Surge Withstand Capability.

J/09-00

Improved the RS-485 operation when driving long lines.

I/08-00

Added CE qualification, UL recognition, and CSA certification.

H/08-00

Changed escutcheon plate from mounting holes to mounting studs.

G/04-99 Initial

release.

Manual

Revision/Date Change

B/01-06

Added Section 14, BESTCOMS Software.

Re-organized Section 12, Installation.

Added Power System Application Figures 12-26 and 12-27.

A/09-00

Changed the manual organization from two volumes to one volume in a loose
leaf binder with tabs to separate the manual sections.

Added Revision History to the Introduction, and CE qualification, UL
recognition, CSA certification, and DNP 3.0 certification.

Added drawings and minor corrections to all sections.

−

/11-99

Initial release.

Summary of Contents for BE1-CDS220

Page 1: ...INSTRUCTION MANUAL FOR CURRENT DIFFERENTIAL SYSTEM BE1 CDS220 D2857 19 08 18 00 Publication 9313900990 Revision B 01 06...

Page 2: ......

Page 3: ...ocedures dimension drawings and connection diagrams Description of the front panel HMI and the ASCII command interface with write access security procedures A summary of setting metering reporting con...

Page 4: ...ability and design of all features and options are subject to modification without notice Should further information be required contact Basler Electric Company Highland Illinois BASLER ELECTRIC ROUTE...

Page 5: ...ed printout problem with long comments Added Settings Compare feature 2 00 01 10 02 Initial 32 bit release Improved the 87ND function block diagram Corrected tap calculation reporting errors Improved...

Page 6: ...o DNP 3 0 Level 2 protocol Added new Password Security parameters to Modbus protocol Modified display of Phase Angle information HMI and reports so that an asterisk appears in the angle position if th...

Page 7: ...elay front panel only latches when there are targets to be displayed on the HMI The pickup condition indicated by the Trip LED flashing is now a higher priority than latching to indicate that targets...

Page 8: ...holes to mounting studs G 04 99 Initial release Manual Revision Date Change B 01 06 Added Section 14 BESTCOMS Software Re organized Section 12 Installation Added Power System Application Figures 12 2...

Page 9: ...ECTION 7 BESTlogic Programmable Logic 7 1 SECTION 8 Application 8 1 SECTION 9 Security 9 1 SECTION 10 Human Machine Interface 10 1 SECTION 11 ASCII Command Interface 11 1 SECTION 12 Installation 12 1...

Page 10: ...viii Introduction BE1 CDS220 This page intentionally left blank...

Page 11: ...ement Errors 1 14 MODEL AND STYLE NUMBER DESCRIPTION 1 14 General 1 14 Sample Style Number 1 15 OPERATIONAL SPECIFICATIONS 1 15 Metered Current 1 15 Metered Frequency 1 15 Calculated Values and Accura...

Page 12: ...ses 1 8 Figure 1 4 Delta Wye Transformer Currents 1 10 Figure 1 5 Three Phase Connections Delta Wye Configuration CT Compensation 1 11 Figure 1 6 Three Phase Connections Delta Wye Configuration Intern...

Page 13: ...ly the available functions with complete flexibility and customize the system to meet the requirements of the protected power system Programmable I O extensive communications features and an optional...

Page 14: ...e setting group Differential Protection Three phase percentage restrained differential protection with harmonic restraint 87 Restricted earth fault ground differential protection with optional indepen...

Page 15: ...cluded with a capacitor backup that will keep time upon loss of power for 8 to 24 hours depending upon conditions A standard IRIG input Format B002 from IRIG Standard 200 98 is provided for receiving...

Page 16: ...the relay as well as all alarm conditions monitored by the relay Time stamps are to the nearest quarter cycle resolution I O and Alarm reports can be extracted from the records as well as reports of...

Page 17: ...e graphical LCD allows the relay to replace local indication and control functions such as panel metering alarm annunciation and control switches The HMI is set up in a menu tree with four scrolling b...

Page 18: ...r bus mains instead of dedicated bus differential circuit Applications where the capabilities of intelligent electronic devices IEDs are used to decrease relay and equipment maintenance costs DIFFEREN...

Page 19: ...rming CTs Finally Basler Electric addresses the source of false differential current at its roots Active CT technology used on the current inputs provides low burden to extend the linear range of powe...

Page 20: ...ap settings The setup parameters for each of the current input circuits are described in Section 3 Input and Output Functions Power System Measurement Functions The CT ratio is included to allow the c...

Page 21: ...aditionally this has been done by special connection of the CTs Figure 1 5 shows the transformer from Figure 1 4 with the CTs connected The wye side CTs can be connected in delta such that the differe...

Page 22: ...A Illustration B Illustration C Ib Low side phase B line current IBD Phase B delta winding current IA High side phase A line current Ia Low side phase A line current IB High side phase B line current...

Page 23: ...s to connect the ground to a lead connected to terminal B10 12 or 14 D2837 19 vsd 02 03 99 B2 B1 B12 B10 Figure 1 5 Three Phase Connections Delta Wye Configuration CT Compensation H2 H1 H3 C B A X2 X1...

Page 24: ...power transformer s delta connection the zero sequence currents are blocked from flowing to the differential protection and circulate in the CT delta just as they circulate in the delta of the power t...

Page 25: ...es a transformer excitation and energization inrush currents appear as differential current because they flow into the zone of protection and not back out again Normally transformer excitation losses...

Page 26: ...ncy Another problem that must be overcome with digital technology is the need to use anti aliasing filters prior to the sampling process to prevent harmonic components from affecting the measurement A...

Page 27: ...and Alarm LEDs Y With 6 button HMI with LCD Display 1 Amp Nominal Systems A W O Independent Gnd Input B 1 Amp Independent Gnd Input 5 Amp Nominal Systems D W O Independent Gnd Input E 5 Amp Independe...

Page 28: ...5 milliseconds 87 Differential Functions Restrained Differential 87RPU 87RT Pickup Accuracy 5 A Current Sensing 4 or 75 mA whichever is greater 1 A Current Sensing 4 or 25 mA whichever is greater Resp...

Page 29: ...1 from 10 0 to 20 0 1 Ampere CT Range 0 40 to 4 00 A Increment 0 01A Minimum Pickup 1 or 5 A Current Sensing Range 0 10 to 1 00 per unit Increment 0 01 Restraint Slope 1 or 5 A Current Sensing Range...

Page 30: ...0 to 16 0 1 A Current Sensing Range 0 10 to 3 20 A Increment 0 01 A Time Current Characteristic Curves Timing Accuracy All 51 Functions Within 5 or 1 cycles whichever is greater for time dial setting...

Page 31: ...s maximum for current 1 5 times pickup 5 cycles maximum for current 1 05 times the pickup setting Breaker Failure BF Current Detector Pickup Fixed at 0 5 A for 5 A unit 0 1 A for 1 A unit Current Dete...

Page 32: ...ilter Output 24 samples per cycle Frequency Tracking 40 to 63 Hz Power Supply Input Voltage Range Option L 24 Vdc 17 to 32 Vdc Option Y 48 125 Vac Vdc 35 to 150 Vdc or 55 to 135 Vac Option Z 125 250 V...

Page 33: ...lation 2 000 Vac at 50 60 Hz in accordance with IEEE C37 90 and IEC 255 5 Excludes communication ports Surge Withstand Capability Oscillatory Qualified to IEEE C37 90 1 1989 Standard Surge Withstand C...

Page 34: ...y POCC RU 0001 11ME05 DNP Certification DNP 3 0 IED certified Subset Level 2 06 20 00 by SUBNET Solutions Inc Environment Temperature Operating Range 40 C to 70 C 40 F to 158 F Storage Range 40 C to 7...

Page 35: ...INTERFACES 2 3 Front Panel HMI 2 3 ASCII Command Communications 2 4 BESTCOMS for BE1 CDS220 Graphical User Interface 2 5 GETTING STARTED 2 6 Connections 2 6 Entering Test Settings 2 6 Checking the St...

Page 36: ...ii Quick Start BE1 CDS220 This page intentionally left blank...

Page 37: ...include references to the following items Note that not all items are appropriate for each function HMI screens for setting the operational parameters ASCII commands for setting the operational parame...

Page 38: ...schemes for the protected circuit can be found in Section 7 BESTlogic Programmable Logic and Section 8 Application Characteristics of Protection and Control Elements As stated before each element fun...

Page 39: ...MI ASCII communications and the BESTCOMS for BE1 CDS220 software The front panel HMI provides access to a subset of the total functionality of the device ASCII communications provides access to all se...

Page 40: ...d to any of the three ports so that the user may send commands to the relay Alternatively a computer terminal or PC running a terminal emulation program such as Windows Terminal can be used in the sam...

Page 41: ...since reset demand registers You can enter RD PI for Report Demand Peak Current I and the relay will respond with the values and time stamps for A B C N and Q To reset all five of the peak since reset...

Page 42: ...t magnitudes directly from the three current sensing inputs The neutral and negative sequence magnitudes are calculated from the fundamental component of each of the three phase currents When evaluati...

Page 43: ...p screen because the screen stops changing when you press the Up scrolling pushbutton From this position press the Right scrolling pushbutton until you have reached the screen titled STATUS BE1 CDS220...

Page 44: ...itional information 8 Does the BE1 CDS220 trip output contact latch after a fault The answer to the question is Yes and No In general once the fault goes away the output contacts open The BE1 CDS220 d...

Page 45: ...e Exit command If access is gained but the session is not ended a 5 minute timeout will end the session and any changes that were not saved will be lost If you are using the BESTCOMS program the acces...

Page 46: ...Installation for additional information 19 How can I find out the version number of my BE1 CDS220 The application version can be found in three different ways 1 Use the HMI Screen 4 6 2 Use the ASCII...

Page 47: ...rol 3 12 Figures Figure 3 1 General Operation Screen Power System Tab 3 2 Figure 3 2 CT Connections 3 3 Figure 3 3 DAB Delta left and DAC Delta right 3 4 Figure 3 4 Internal Phase and Zero Sequence Co...

Page 48: ...ii Input And Output Functions BE1 CDS220 This page intentionally left blank...

Page 49: ...C phase input for CT circuit one When the current applied to phase C of CT circuit one is greater than 10 nominal the BE1 CDS220 relay measures the frequency and varies the sampling rate to maintain...

Page 50: ...a N a N a Ground Source gnd src Input 1 optional 0 No 1 Yes N a N a 0 CT Ratio ct ratio Input 2 1 50 000 1 Turns 1 CT Connection ct con Input 2 WYE DAB DAC N a N a WYE Transf Connection tx con Input 2...

Page 51: ...wo delta configurations as shown in Figure 3 2 As described in Section 1 General Information Differential Protection Application Considerations wye CT connections are recommended for most applications...

Page 52: ...an example of the same transformer with the phases reconnected to provide a DAC connection If there is no wye winding to use as reference as is the case with a delta delta transformer the definition o...

Page 53: ...WYE NONE WYE DAB DAB WYE NONE WYE DAC DAC WYE NONE DAB WYE WYE NONE DAB DAC WYE WYE NONE DAC DAB DAB WYE NONE WYE NONE DAC DAC WYE NONE WYE NONE WYE WYE WYE WYE DAB DAB WYE DAB DAB WYE NONE WYE DAC DA...

Page 54: ...DAB WYE WYE DAB WYE NONE DAB WYE WYE NONE WYE NONE 30 LEAD 30 LAG WYE DAC WYE WYE DAC WYE NONE DAC WYE WYE NONE WYE NONE 30 LAG 30 LEAD DAB DAB WYE WYE WYE NONE WYE NONE WYE DAB DAB WYE NONE WYE DAC D...

Page 55: ...d source NOTE The CT input circuit settings are used by the auto tap calculation function to calculate the correct tap adjustment factor for the differential functions When entering these settings via...

Page 56: ...C 0 No or 1 Yes IA IC 3 IB IA 3 IC IB 3 Figure 3 4 Internal Phase and Zero Sequence Compensation CT connection settings can be entered through BESTCOMS the optional HMI using screen 6 3 1 1 SETUP PWR_...

Page 57: ...to 200 V Digital Input Conditioning Function The relay scans the inputs for status 24 times per cycle When operating on a 60 hertz power system this results in the input status being sampled every 0 7...

Page 58: ...purpose output contacts OUT1 through OUT6 and one fail safe normally closed relay in de energized state alarm output contact OUTA Each output is isolated and rated for tripping duty Relays OUT1 and OU...

Page 59: ...ts internal alarm condition ALMREL See Section 6 Reporting and Alarm Functions Alarms Function for more details on this function This alarm condition disables the outputs and de energizes the OUTA rel...

Page 60: ...utput logic expression that normally controls the state of an output contact can be overridden and the contact pulsed held open or held closed This function is useful for testing purposes An alarm poi...

Page 61: ...necessary to return the contact to logic control manually Return to logic control can be accessed from the HMI using screen 2 4 CTRL OUT and entering an L for return to logic control in the field for...

Page 62: ...The status of the output logic can also be accessed from the ASCII command interface using the RG STAT report general status command or RG OUTCNTRL report general output control status command See Se...

Page 63: ...tatus from the Relay 4 24 51 Time Overcurrent Protection 4 24 BESTlogic Settings for Time Overcurrent 4 25 Operating Settings for Time Overcurrent 4 26 Retrieving Time Overcurrent Status from the Rela...

Page 64: ...nt Logic Block 4 24 Figure 4 22 BESTlogic Function Element Screen Phase 51P 4 25 Figure 4 23 Overcurrent Screen 51 Tab 4 27 Figure 4 25 Phase to Phase Fault Magnitude 4 29 Figure 4 26 Sequence Compone...

Page 65: ...ettings for Breaker Failure 4 33 Table 4 19 BESTlogic Settings for General Purpose Logic Timers 4 37 Table 4 20 Operating Settings for General Purpose Logic Timers 4 38 Table 4 21 BESTlogic Settings f...

Page 66: ...iv Protection and Control BE1 CDS220 This page intentionally left blank...

Page 67: ...ion pickup setting to zero S 150TQ 0 or set 150TQ to zero using the Overcurrent Screen in BESTCOMS More information on each individual function for item 1 is provided in this section More information...

Page 68: ...ctions are reset and initialized with the new operating parameters The setting change occurs instantaneously so at no time is the relay off line The active setting group is saved in nonvolatile memory...

Page 69: ...expression Meaning is dependent upon the Mode setting 0 Automatic Logic Expression When TRUE automatic control is enabled and when FALSE logic control is enabled 0 Example 1 Make the following settin...

Page 70: ...4 2 Setting Group Binary Codes Binary Code D1 D0 Decimal Equivalent Setting Group 0 0 0 SG0 0 1 1 SG1 1 0 2 SG2 1 1 3 SG3 When using control Mode 2 the active setting group is controlled by a binary s...

Page 71: ...enu Alternately settings may be made using the SP GROUP ASCII command Figure 4 5 Setting Group Selection Screen At the top center of the screen is a pull down menu labeled Logic This menu allows viewi...

Page 72: ...to threshold and time delay a return threshold and time delay and a monitored element The switch to and return thresholds are a percentage of the SG0 pickup setting for the monitored element The moni...

Page 73: ...at a TRUE 1 logic state in order to allow the automatic logic to operate When the breaker opens the load current falls to zero at time 15 minutes After 10 minutes Setting Group 1 becomes active and t...

Page 74: ...ing group can be activated using the CO GROUP command during a 30 second window Use the CO GROUP command to activate the setting group already selected The setting group activated with the CO GROUP co...

Page 75: ...CDS220 relays provide three phase percentage restrained differential protection with high speed unrestrained instantaneous differential protection The differential protection includes harmonic restra...

Page 76: ...to restraint current The slope setting should be set above the maximum mismatch caused by excitation losses tap mismatch and load tap changers The minimum pickup setting determines the minimum sensiti...

Page 77: ...87 restrained trip logic output If the second or fifth harmonic inhibit comparators are picked up for any of the three phases the 2NDHAR and 5THHAR logic outputs respectively are set In many cases the...

Page 78: ...tion Element Screen Phase 87 At the top center of the BESTlogic Function Element screen is a pull down menu labeled Logic This menu allows viewing of the BESTlogic settings for each preprogrammed logi...

Page 79: ...in KV for each CT input circuit CTRn CT ratio for CT input n Actual ratio not effective ratio COMPn Phase compensation adjustment factor for CT input n 3 if CTs are connected in Delta CTcon DAB or DAC...

Page 80: ...o tap calculation settings or the manual tap settings can be entered for each setting group with BESSTCOMS or from the ASCII command interface using the S g TAP87 command Figure 4 12 Percentage Differ...

Page 81: ...rotective elements should be adjusted as well Equation 4 2 gives the adjustment factor The definitions for the variables in Equation 4 2 are the same as those for Equation 4 1 For example the ideal ta...

Page 82: ...A1COMP RA Equation 4 4 Calculate Restraint Current for Phase A Retrieving Phase Differential Status from the Relay The status of each logic variable can be determined from the ASCII command interface...

Page 83: ...djusted to eliminate magnitude mismatch The Restraint Current function determines the magnitude of the restraint current as the maximum of the compensated currents in multiples of tap The Operating Cu...

Page 84: ...on the target reporting function BESTlogic Settings for Neutral Differential BESTlogic settings are made from the BESTlogic Function Element screen in BESTCOMS Figure 4 16 illustrates the BESTCOMS scr...

Page 85: ...TAPn or TAPG The tap factors calculated by the auto tap calculation feature can be determined in several ways They are displayed on the optional HMI using Screen 5 2 1 PROT SG 87ND 87ND Alternatively...

Page 86: ...II command interface Time delays entered in cycles are converted to milliseconds or seconds Increment precision after conversion is limited to that appropriate for each of those units of measure The 8...

Page 87: ...nstantaneous overcurrent function has a pickup and a time delay setting When the measured current is above the pickup threshold the pickup logic output 50TPPU for example TRUE and the timer is started...

Page 88: ...utton for the corresponding input in the BESTlogic Function Element screen The BESTlogic Expression Builder screen will open Select the expression type to be used Then select the BESTlogic variable or...

Page 89: ...of measure The unit of measure for the Time setting that represents the element s time delay defaults to milliseconds It is also selectable for seconds minutes and cycles If time delay settings are ma...

Page 90: ...be determined from the ASCII command interface using the RG STAT command See Section 6 Reporting and Alarm Functions General Status Reporting for more information 51 Time Overcurrent Protection There...

Page 91: ...rcurrent protective functions use the highest of the three measured phase currents If the current is above the pickup setting for any one phase the pickup logic output is asserted If the trip conditio...

Page 92: ...BESTCOMS screen used to select operational settings for the Time Overcurrent element To open the screen select Overcurrent from the Screens pull down menu and select either the 51 151 or 251 tab Alte...

Page 93: ...ed through the ASCII command interface using the RG STAT report general status command See Section 6 Reporting and Alarm Functions General Status Reporting for more information Programmable Curves Tim...

Page 94: ...me to reset Relevant if 51 function is set for integrating reset R Coefficient specific to selected curve Affects the speed of reset when integrating reset is selected Setting Programmable Curves Curv...

Page 95: ...he negative sequence elements might be one half the phase pickup setting in order to achieve equal sensitivity to phase to phase faults as three phase faults This number comes from the fact that the m...

Page 96: ...protection for faults on the wye side For faults not involving ground this is not a problem since the phase relays will see 1 0 per unit fault current for three phase faults and 2 3 1 15 per unit faul...

Page 97: ...al relays to initiate the breaker failure timer it may be desirable to include fault detector supervision of the initiate signal using an instantaneous overcurrent function in BESTlogic For example if...

Page 98: ...ession Builder screen will open Select the expression type to be used Then select the BESTlogic variable or series of variables to be connected to the input Select Save when finished to return to the...

Page 99: ...ry amps The unit of measure for the Time setting that represents the element s time delay defaults to milliseconds It is also selectable for seconds minutes and cycles Table 4 18 summarizes the operat...

Page 100: ...ck logic input is provided to block operation of the timer When this expression is TRUE the function is disabled Each timer has a T1 time setting and a T2 time setting The functioning of these setting...

Page 101: ...SE if the BLOCK input becomes TRUE D2843 09 10 23 03 Figure 4 32 Mode 2 One Shot Nonretriggerable Timer Mode 3 One Shot Retriggerable Timer This mode of operation is similar to the one shot nonretrigg...

Page 102: ...entire duration of time T1 At that point the output of the timer is toggled to TRUE Then later the initiate expression becomes FALSE and stays FALSE for the duration of RESET time T2 At that point the...

Page 103: ...Enable the Logic Timer function by selecting its mode of operation from the Mode pull down menu To connect the element s inputs select the button for the corresponding input in the BESTlogic Function...

Page 104: ...n menu labeled Logic This menu allows viewing of the BESTlogic settings for each preprogrammed logic scheme User or custom logic must be selected on this menu in order to allow changes to be made to t...

Page 105: ...through the HMI and remotely from a substation computer or through a modem connection to a remote operator s console The state of the switches can be controlled from the optional HMI or ASCII command...

Page 106: ...ade using SL x43 ASCII command where x blank 1 2 3 4 5 6 or 7 At the top center of the BESTlogic Function Element screen is a pull down menu labeled Logic This menu allows viewing of the BESTlogic set...

Page 107: ...mments x no entry for 43 or 1 for 143 Action 0 to open the switch 1 to close the switch P to pulse the switch to the opposite state for 200 milliseconds and then automatically return to starting state...

Page 108: ...a typical breaker control switch with a momentary close spring return trip contact output 101T a momentary close spring return close contact output 101C and a slip contact output 101SC The slip contac...

Page 109: ...the Virtual Breaker Control Switch The state of the virtual breaker control switch can be controlled at the optional HMI through Screens 2 2 CTRL BKR Control is also possible through the ASCII comman...

Page 110: ...r Control Switch Status from the Relay The state of the virtual breaker control switch after trip or after close can be determined through the ASCII command interface by using the RG STAT reports gene...

Page 111: ...ERING 5 1 BESTCOMS Metering Screen 5 2 ASCII Command and HMI Screen Cross Reference 5 2 Current 5 3 Frequency 5 3 Figures Figure 5 1 Polar Graph for Phase Angle Reporting Reference 5 1 Figure 5 2 BEST...

Page 112: ...ii Metering BE1 CDS220 This page intentionally left blank...

Page 113: ...outside of the circle which is 5 0 amperes Phase B current is at an angle of 240 degrees and is shown on the polar graph at 240 degrees which is lagging phase A by 120 degrees Phase B current magnitu...

Page 114: ...reens used for metering Table 5 1 ASCII Command and HMI Metering Cross Reference Metering Function ASCII Command HMI Screen All metered values M METER Frequency M FREQ METER CRNT Current all values M...

Page 115: ...Comp C phase MD IC2COMP METER DIFF COMP IC 2 nd Harmonics as a of Iop C phase MD IC2ND METER DIFF HARM 5 th Harmonics as a of Iop C phase MD IC5TH METER DIFF HARM Ground Differential Current values MD...

Page 116: ...5 4 Metering BE1 CDS220 This page intentionally left blank...

Page 117: ...EAKER MONITORING 6 19 Breaker Status Reporting 6 19 Breaker Duty Monitoring 6 21 Breaker Alarms 6 26 TRIP CIRCUIT MONITOR 6 27 FAULT REPORTING 6 28 Fault Reporting Expressions and Settings 6 28 Target...

Page 118: ...fication Tab 6 46 Figure 6 29 General Operation Screen General Info Tab 6 46 Tables Table 6 1 Circuit Identification Settings 6 1 Table 6 2 SG CLK Command Settings 6 3 Table 6 3 Logic Variable Status...

Page 119: ...quence of Events Recorder SER Reports Each of these four ID fields may be up to 30 alpha numeric characters long Figure 6 1 illustrates the BESTCOMS screen used to change these settings Alternately se...

Page 120: ...point monitors for IRIG signal loss once a valid signal is detected at the IRIG port The IRIG input is fully isolated and accepts a demodulated dc level shifted signal The input signal must be 3 5 vol...

Page 121: ...xample 1 Enter the date for July 1 2005 RG DATE 07 01 05 or RG DATE 07 01 05 RG TIME Command Purpose Report Set Time Syntax RG TIME hr mn sc or RG TIME hr mn f sc Comments If P or A is not used time i...

Page 122: ...ides more information about output logic override control CO 43 to CO 743 Virtual switch function status is reported on this line This information is also available at HMI Screen 1 4 3 STAT OPER x43 w...

Page 123: ...ALARMS or using the ASCII command RA See Section 10 Human Machine Interface and the paragraphs on Alarms Function later in this section for more information about the diagnostic and alarm functions O...

Page 124: ...ay s Peak and Today s Peak Programmable alarm points can be set to alarm if thresholds are exceeded for overload and unbalanced loading conditions Demand Calculation and Reporting Function Thermal Dem...

Page 125: ...registers to these values after the abnormal loading condition has passed Setting the Demand Reporting Function For the demand reporting function to calculate demand it is necessary to specify the dem...

Page 126: ...it key changing the preset value using the scrolling pushbutton keys exiting and then saving the settings Write access to the Reports functional area is required to do this from the HMI The values and...

Page 127: ...and negative sequence demand thresholds for unbalanced loading alarms Each time that the current demand register is updated the value is compared to the appropriate demand alarm threshold If the thre...

Page 128: ...ute it would take approximately fifteen minutes for the load step change to reach 90 percent of the final level See the previous paragraphs in this section on Demand Calculation and Reporting Function...

Page 129: ...ust use the RA DIFF TRIG command to obtain a record of the actual operating conditions The following differential check record example was developed from a simulated substation and shows that there ar...

Page 130: ...must be above the alarm level setting times the minimum pickup setting Two the slope ratio must be above the alarm level setting times the slope setting For example our settings are minimum pickup 0...

Page 131: ...ed a 60 degree error The connection should be DAC Example 2 RA DIFF CDS 220 DIFFERENTIAL CHECK RECORD REPORT DATE 11 10 98 REPORT TIME 10 12 42 701 STATION ID SIMULATED SUBST RELAY ID BANK T1 USER1 ID...

Page 132: ...ull down the Screens menu and select Differential Protection Select the Diff Alarm tab Alternately settings can be made using ASCII command SA DIFF setting alarm differential This setting is not avail...

Page 133: ...igure 6 6 Percentage Differential Screen Diff Alarm Tab TRANSFORMER MONITORING FUNCTIONS The transformer monitoring functions provide monitoring and alarms for the transformer to help manage equipment...

Page 134: ...rs the function adds the maximum measured current in primary ampere seconds In the accumulated I2 t Duty registers the function adds the maximum measured current squared in primary ampere seconds The...

Page 135: ...2 Ckt 2 1 Block Logic Logic expression that blocks transformer duty accumulation when TRUE This parameter cannot be set through the HMI 0 ST DUTY Command Purpose Read Set Transformer Duty where mode...

Page 136: ...se alarm points can be programmed to monitor either of the two transformer monitoring functions through fault counter or through fault duty That is you may program an alarm threshold limit to monitor...

Page 137: ...Alarms Function in this section for more information on the use of programmable alarms Breaker Status Reporting The breaker status monitoring function monitors the position of the breaker for reporti...

Page 138: ...nd Example Example 1 Set the relay to monitor input 3 so that when the input is false the breaker is closed 52b contact is wired to Input 3 and change breaker label to BREAKER_1 SB LOGIC IN3 BREAKER_1...

Page 139: ...in primary amperes In the Accumulated I2 Duty registers the function adds the measured current squared in primary amperes The user selects which of the two sets of duty registers are reported and moni...

Page 140: ...monitoring is blocked logic expression equals 1 breaker duty is not accumulated Protective element picks up Protective element trips Breaker auxiliary contact changes state Protective element drops o...

Page 141: ...cles prior to the end of the fault record This is also the case if the fault record was triggered through the ASCII command interface by the RF TRIG command G During the time that the SG TRIGGER picku...

Page 142: ...select the BLOCK input button The BESTlogic Expression Builder screen will open Select the expression type to be used Then select the BESTlogic variable or series of variables to be connected to the i...

Page 143: ...rt breaker duty command It should be noted that when reading and writing to these registers only the set of registers selected to be monitored by the mode setting Accumulated I or I2 and the CT settin...

Page 144: ...operations counter interruption duty or clearing time An alarm threshold can be programmed to monitor each function Alternately three different thresholds can be programmed to monitor one of the monit...

Page 145: ...to TRUE Figure 6 14 shows a typical connection diagram for the circuit monitor Also see Section 8 Application Application Tips for instructions on how to program a close circuit monitoring function i...

Page 146: ...nd Logic trigger Figure 6 9 and Table 6 11 illustrate how each of these logic expressions is used by the various relay functions Note that even though BESTlogic expressions are used to define these co...

Page 147: ...d Then select the BESTlogic variable or series of variables to be connected to the input Select Save when finished to return to the BESTlogic Function Element screen For more details on the BESTlogic...

Page 148: ...251P Phase Inverse Time Overcurrent Enabled 51N 151N 251N Neutral Inverse Time Overcurrent Enabled 51Q 151Q 251Q Negative Sequence Inverse Time Overcurrent Enabled 50TP 150TP 250TP Phase Instantaneou...

Page 149: ...HMI Screen 4 1 1 REPRT FAULT M_REC and 4 1 2 REPRT FAULT PREV Targets for previous events are recorded in the fault summary reports which are described in detail later in this section When the relay...

Page 150: ...possible targets that may be displayed on the Metering screen Table 6 17 Targets as Displayed IEEE Device Number Definition 50 150 250 ABC N Q Instantaneous Overcurrents 51 151 251 ABC N Q Time Overc...

Page 151: ...ry Report To view fault reports using BESTCOMS select Oscillography Download from the Reports pull down menu A screen such as the one shown in Figure 6 20 will appear Figure 6 20 View Download Relay F...

Page 152: ...t became TRUE to trigger the recording of the event Event Type This line reports the type of event that occurred There are five fault event categories Trip A fault was detected as defined by the picku...

Page 153: ...report can be accessed by using the RF command RF Command Purpose Read Reset Fault Report Data Syntax RF n NEW 0 TRIG where n record or NEW new records RF Command Example Example 1 Fault Directory Rep...

Page 154: ...cycles of the end of the first record then there is no gap in data between the two records If the second record begins after five cycles there will be a gap some data not recorded between the records...

Page 155: ...he rest of the filenames will respond by changing to match the base filename Select OK to save the file Figure 6 22 Browse for Folder Screen Figure 6 23 Fault Record Filenames Only one oscillographic...

Page 156: ...g specific SER Reports SER Directory Report A directory report lists the number of events currently in memory and the time span that the events cover Directory reports are accessed using the RS report...

Page 157: ...nds at 60 hertz RS Command Examples Example 1 Read the directory report of records RS BE1 CDS SEQUENCE OF EVENTS DIRECTORY REPORT DATE 04 26 04 REPORT TIME 16 43 36 STATION ID SUBSTATION_1 RELAY ID BE...

Page 158: ...rogrammed to be held closed For example to open OUT5 for indication of relay trouble set the VO5 logic expression at 0 SL VO5 0 A not zero setting is equal to logic 1 When the relay is fully functiona...

Page 159: ...ALARM 2 Breaker Alarm 2 threshold SA BKR2 setting exceeded 7 BREAKER ALARM 3 Breaker Alarm 3 threshold SA BKR2 setting exceeded 8 P DEMAND ALARM Phase demand alarm 9 N DEMAND ALARM Neutral demand alar...

Page 160: ...mplete command descriptions Figure 6 24 Reporting and Alarms Screen Alarms Tab Table 6 22 summarizes major minor and logic programmable alarm settings Table 6 22 Programmable Alarm Settings Setting Ra...

Page 161: ...es advantage of this to allow the front panel Reset key to be used in the programmable logic scheme when Alarm Screen 1 2 STAT ALARMS is active An example of the use of this logic variable is to break...

Page 162: ...ondition that is used for an alarm exists the label will be reported in the alarm reporting function Programmable Alarms Reset Programmable alarms can be reset by any one of three methods The programm...

Page 163: ...l number information is contained on the label on the front panel Embedded software information can be obtained at HMI Screen 4 6 REPRT VERSION The information of Screen 4 6 is also displayed briefly...

Page 164: ...6 46 Reporting and Alarm Functions BE1 CDS220 Figure 6 28 General Operation Screen Identification Tab Figure 6 29 General Operation Screen General Info Tab...

Page 165: ...c Schemes 7 8 Creating or Customizing a Logic Scheme 7 8 Sending and Retrieving Relay Settings 7 8 Debugging the Logic Scheme 7 8 USER INPUT AND OUTPUT LOGIC VARIABLE NAMES 7 9 BESTLOGIC APPLICATION T...

Page 166: ...ii BESTlogic Programmable Logic BE1 CDS220 This page intentionally left blank...

Page 167: ...tputs and hardware outputs A group of logic equations defining the function of the multifunction relay is called a logic scheme One preprogrammed relay logic scheme is stored embedded in the relays me...

Page 168: ...ble 1 ctckt 1 2 ctckt 2 PHASE IOC 50TP BLK 50TQT 50TQPU Mode 0 disable 1 ctckt 1 2 ctckt 2 NEG SEQ IOC 50TQ BLK BFT BFPU INI Mode 0 disable 1 ctckt 1 2 ctckt 2 BREAKER FAILURE BF ALARMS ALMMI N ALMMAJ...

Page 169: ...n P pulse 43 Mode 0 disable 1 on off pulse 2 on off 3 off momentary on 43 AUX SWITCH 143 Mode 143 AUX SWITCH CO 143 243 Mode 243 AUX SWITCH CO 243 343 Mode 343 AUX SWITCH CO 343 443 Mode 443 AUX SWITC...

Page 170: ...Sequence Picked Up 243 243 Output 150TPT 150T Phase Tripped 343 343 Output 150TPPU 150T Phase Picked Up 443 443 Output 150TNT 150T Neutral Tripped 543 543 Output 150TNPU 150T Neutral Picked Up 643 643...

Page 171: ...in EEPROM and are restored to the last state prior to loss of power These variables include 43 143 243 343 443 543 643 743 101SC and SG0 through SG3 All control commands including logic override contr...

Page 172: ...on will reset the expression to its original state when the BESTlogic Expression Builder was first opened The Cancel button resets the expression to its original state when the BESTlogic Expression Bu...

Page 173: ...ection 8 Application can be copied to the active logic and customized or used as is To copy a logic scheme into active logic select the scheme from the BESTCOMS logic library and upload it to the rela...

Page 174: ...f customizing or creating a logic scheme Step 1 Copy the preprogrammed scheme Step 2 Rename the scheme with a unique non preprogrammed name Step 3 Using BESTCOMS enable or disable the desired relay fu...

Page 175: ...ed OUT6 is Form C and has one normally open and one normally closed contact Normally open contacts can be used as normally closed outputs by inverting the logic expressions that drive them Inverting a...

Page 176: ...7 10 BESTlogic Programmable Logic BE1 CDS220 This page intentionally left blank...

Page 177: ...OL LOGIC SCHEME 8 14 Protection Elements 8 17 Integration of Protection Control and I O Elements 8 17 Alarms 8 18 TRANSFORMER WITH BACKUP SCHEME 8 21 Protection Elements 8 22 Integration of Protection...

Page 178: ...9 Station One Line Drawing 8 54 Figure 8 20 Latching a Tripping Contact Example 8 54 Tables Table 8 1 BASIC 87 Logic Settings and Equations 8 4 Table 8 2 BASIC 87 Contact Input Logic 8 7 Table 8 3 BAS...

Page 179: ...that is equivalent to the discrete component counterpart Virtual Switches Virtual switches are logic switches that emulate traditional protection and control panel switches such as the breaker contro...

Page 180: ...se include the differential functions with harmonic restraint as well as 51 phase neutral and negative sequence backup protection as seen from the transformer high side Also included is a separate 51N...

Page 181: ...e continuous reliable and secure protection of the user s facilities Regardless of the product manufacturer common mode failure is a possibility that the protection engineer must consider in his desig...

Page 182: ...lements that are enabled set to logic 1 for the BASIC 87 application and see how the elements are logically wired together equations If the user should decide to build on this scheme all elements requ...

Page 183: ...Out4 Out2 51P Out1 BE1 CDS220 D2843 22 vsd 08 02 00 CT Input 1 87 51N 51Q 86G G 41 Field T r i p 52 Bus Main T r i p Out3 CT Input 1 Out1 Out2 87 Out4 BE1 CDS220 CT Input 2 51P 51N 51Q 86B 52 F2 52 F...

Page 184: ...strained differential protection function is the only function of the 87 protection element required Set the pickup of the 2 nd 5 th and 87 unrestrained functions to 0 setting disabled The 87 restrain...

Page 185: ...us indication in SER reports TRUE when 86 tripped 86 TRIPPED TRIPPED NORMAL IN6 IN8 Optional inputs Used for programmable alarms and SER reporting For example sudden pressure trip or transformer hot s...

Page 186: ...Phase differential trip OUT3 contact closes if restrained or unrestrained trip occurs 87TRIP OUT TRIP NORMAL BESTlogic Expression VO3 87RT 87UT VO4 Time overcurrent trip May be used to direct trip ma...

Page 187: ...inding transformer applications Figure 8 3 is a one line drawing and Figure 8 4 is a logic drawing that represents the logic settings and equations shown in Table 8 6 In Table 8 6 the user can see the...

Page 188: ...10 0 SL VO11 151PT 251PT 51NT 151NT 251NT 151QT 251QT 87RT 87UT SL VO12 87UT 151PPU 251PPU 51NPU 151NPU 251NPU 151QPU 251QPU 87RPU SL VO13 IN6 SL VO14 IN7 SL VO15 IN8 52 1 86T T r i p CT Input 1 Out4...

Page 189: ...d must be ordered Paralleled CTs inside a delta tertiary 3Io can also feed the 51N The 87 51 151 and 251 protection elements are logic enabled by the settings shown in Table 8 6 to provide a trip thro...

Page 190: ...LMMAJ and Minor Alarm ALMMIN A fourth logic variable Logic Alarm ALMLGC has no associated front panel LED When the relay self test detects a problem in the relay ALMREL as programmed for the BASIC TX...

Page 191: ...put 2 251N Used for timed neutral overcurrent protection for CT input circuit 2 0 2 CT Input 2 251Q Used for timed negative sequence overcurrent protection for CT input circuit 2 0 2 CT Input 2 Table...

Page 192: ...is TRUE when any 87 or 51 element picks up PROT PICKE PU NORMAL BESTlogic Expression VO11 87UT 151PPU 251PPU 51NPU 151NPU 251NPU 151QPU 251QPU 87RPU 87UT is included to trigger the fault recorder beca...

Page 193: ...ure 8 6 is a logic drawing that represents the logic settings shown in Table 8 11 In Table 8 11 the user can see the protection and control elements that are enabled for the TX W CTL application and h...

Page 194: ...43 Mode3 52 1 Close 143 43 5 VO4 52 2 Trip OUT4 Output Logic 101 Mode1 101T 101C 101SC Alarm ALMMAJ ALMMIN ALMLGC SA RESET VO5 52 2 Close OUT5 Output Logic 52 2 Close VO6 Major Alarm Output Logic IN5...

Page 195: ...rdinated with the low side bus protection to provide Phase Neutral and Negative Sequence timed backup protection for the low side bus if the bus protection is out of service Typically the 251 protecti...

Page 196: ...for CT input circuit 2 breaker status indication in SER reports TRUE when breaker closed BREAKER 2 CLOSED OPEN IN3 Optional input Used for 86 status indication and locks out the low side and high side...

Page 197: ...LOSE NORMAL 243 Differential Cutoff switch The 87 function is blocked when the switch is closed 2 ON OFF 87 CUTOFF DISABLD NORMAL 343 Automatic setting group change logic auto manual switch 2 ON OFF S...

Page 198: ...ALAR ALARM NORMAL BESTlogic Expression VO6 ALMMAJ VO11 Protective trip expression VO11 is TRUE when any 87 51 151 or 251 element trips PROTECTIVE TRIP NORMAL BESTlogic Expression VO11 87RT 87UT 51NT 1...

Page 199: ...W BU and transformer protection TX W BU The control switch elements are referred to as virtual because they have no physical form they exist only in logic form and they can only be operated via the A...

Page 200: ...rotection in the event of a common mode failure Typically the 87 protection element provides high speed restrained differential and unrestrained differential phase and ground protection for faults ins...

Page 201: ...the group setting state When Input D0 of the setting group selection element is high it is interpreted as a binary 1 causing the logic to switch to group 1 For normal operation setting group 0 is acti...

Page 202: ...ssure tripping EXT BFI 52B SUPV INI NORMAL IN7 Breaker Failure Initiate by external relays with fault detector supervision Typically used for overcurrent tripping relays EXT BFI 50 SUPV INI NORMAL IN8...

Page 203: ...y BFI with fault detector supervision expression VO10 BF BLK Logic Block breaker failure protection when relay is in test mode VO15 2 CT Input 2 INI Logic Used for breaker failure tripping with no cur...

Page 204: ...1PT 251NT 251QT VO9 BFPU 101T VO5 Breaker 2 close Close breaker if virtual control switch is TRUE and 86T or 86B LO is not tripped CLOSE BKR2 CLOSE NORMAL BESTlogic Expression VO5 101C IN3 IN4 VO6 Sig...

Page 205: ...gic Expression VO12 87RPU 87UT 250TPPU 250TNPU 250TQPU 51NPU 151PPU 151NPU 151QPU 251PPU 251NPU 251QPU 87UT is included to trigger the fault recorder because there is no unrestrained pickup output VO1...

Page 206: ...BE1 851 OR BE1 951 BUS RELAY CIRCUIT IN2 BUS RELAY INSTANTANEOUS BLOCK B4 B3 OUT4 F1 B8 B7 OUT6 TX W BU TS BUS OUT5 BUS 94 BUS IN3 BUS RELAY FEEDER BACKUP MODE B6 B5 IN4 BUS RELAY TEST MODE OUT4 F2 OU...

Page 207: ...ptional CT Input 1 CT Input 2 52 2 C lose BE1 CDS220 D2850 01 vsd 04 23 99 CT Input 2 151P 151N 251P 251N 251Q 86T 43 C u t o f f Out2 250TP 250TN 86B 50TP 50TN BF Out3 86F 52 2 101 Trip T C Out4 Out5...

Page 208: ...me that provides a second level of bus protection and Feeder Relay out of Service backup protection Figure 8 10 shows the interconnection of BE1 851 or BE1 951 relays for backup and feeder protection...

Page 209: ...P0004 09 vsd 08 21 00 C1 C2 C5 C6 C7 C8 C7 C8 C7 C8 C14 C15 C7 C8 C3 C4 C7 C8 C31 C32 BE1 851 OR BE1 951 BACKUP RELAY CIRCUIT TS BUS IN4 BACKUP RELAY TEST MODE 83 F1 83 F2 83 Fn IN2 BACKUP RELAY FEED...

Page 210: ...1 Fn C1 C2 BE1 851 OR BE1 951 FEEDER RELAY CIRCUIT TS Fn IN4 FEEDER RELAY TEST MODE 83 Fn OUT3 Fn B7 B8 IN2 BUS 94BUS Fn C5 C6 BE1 CDS220 TX W BU RELAY CIRCUIT TS BUS IN8 TX W BU RELAY TEST MODE 83 F1...

Page 211: ...N7 0 0 0 0 SL 43 2 SL 143 0 SL 243 0 SL 343 0 SL 443 0 SL 543 0 SL 643 0 SL 743 2 SL 101 1 SL CKTMON 0 0 0 SL VOA 0 SL VO1 87RT VO8 VO14 SL VO2 0 SL VO3 VO9 VO14 SL VO4 87RT VO9 VO14 VO10 101T SL VO5...

Page 212: ...C u t o f f 52 F1 851 P U F a i l Trip See Note 1 52 F2 851 P U F a i l Trip See Note 1 FEEDER 1 FEEDER 2 52 F3 851 P U F a i l Trip See Note 1 FEEDER 3 CT Input 2 IN7 IN5 NOTE 1 If a Feeder relay is...

Page 213: ...in Breaker Trip OUT4 Output Logic VO5 Bus Main Breaker Close OUT5 Output Logic VO6 BFI Output Logic OPTO OPTO OPTO OPTO VO15 Test Mode Alarm Point 23 OUT6 150TP Mode1 150TPT 150TPPU 150TN Mode1 150TNT...

Page 214: ...les coordination interval when used with 851 feeder protection inputs as part of a bus interlocking scheme IN5 of the Bus BE1 CDS220 For normal mode the 250T protection element should have a pickup se...

Page 215: ...alarm display to indicate when the relay is in feeder backup mode and to trip a feeder breaker instead of the bus breaker Alarms Three logic variables drive the front panel LEDs Relay Trouble ALMREL...

Page 216: ...ntial protection with high speed unrestrained instantaneous differential protection Differential function is blocked when virtual switch 43 is TRUE 43 1 Enabled 51P Applied to bus main CT 1 Normally f...

Page 217: ...150TN Applied to bus main CT 1 Used for backup bus OC trip 18 20 cycles delay no feeder picked up interlock Provides primary OC protection when 50T elements are used for feeder relay backup 0 1 CT In...

Page 218: ...O5 Breaker 1 close Close breaker 1 main if virtual control switch is TRUE and 86T or 86B LO is not tripped CLOSE BKR1 CLOSE NORMAL BESTlogic Expression VO5 101C IN3 IN4 VO6 Breaker Failure Initiate ou...

Page 219: ...PU 51PPU 51NPU 51QPU 150TPPU 150TNPU 150TQPU 151PPU 151NPU 151QPU VO13 Alarm to indicate that the differential cutoff switch is in the block operation position TRUE if virtual switch 43 is in the clos...

Page 220: ...and control elements that are enabled for the MOTOR application and how the elements are logically wired together equations If the user should decide to build on this scheme all elements required for...

Page 221: ...50TQ 51Q Trip IN2 50TN M Phase Loss Unbalance Ground Fault 51P 251P Overload Jam 150TP 151P Locked Rotor 243 143 Speed Switch Selector 50TP Start Detect High Inertia Low High Inertia Selector 250TP S...

Page 222: ...rotection element is connected to input 2 The 87 50 51 150 151 and 250 protection elements are logic enabled to provide a trip by the settings shown in Table 8 26 Protection elements set at 0 are sett...

Page 223: ...select between motion detection by external speed switch or motion detection by current sensing This is accomplished by the position of virtual switch 143 If we assume current sensing was selected the...

Page 224: ...panel LEDs Relay Trouble ALMREL Major Alarm ALMMAJ and Minor Alarm ALMMIN There is a fourth logic variable Logic Alarm ALMLGC but there is no associated front panel LED When the relay self test detec...

Page 225: ...bled with the SG TARG setting for this function 0 1 CT Input 1 50TN 50TN is used for ground fault backup protection 0 1 CT Input 1 50TQ 50TQ is used for loss of phase detection 0 1 CT Input 1 150TP Th...

Page 226: ...speed switch or current TRUE if motor energized 250TPPU and speed switch IN2 closed Or 50TP is picked up Used to unblock 151P for Locked Rotor protection STARTING H TRUE FALSE BESTlogic Expression VO...

Page 227: ...5 51PPU 250TPT VO15 Unbalance alarm TRUE if unbalance 51Q protection is picked up This condition will trip the motor if allowed to time out UNBALANCE ALARM NORMAL BESTlogic Expression VO15 51QPU MISCE...

Page 228: ...ailure Trip logic VO5 in Figure 8 16 can be modified by ORing the Breaker Failure Trip output with the expression VO10 CKTMON VO10 is designated as the Breaker Failure Initiate expression Example 1 il...

Page 229: ...tion may be added by using a 62 function block and a contact sensing input INX to monitor the close circuit The logic is shown in Figure 8 17 The output of the 62 protection block will close the desig...

Page 230: ...y the pickup and time dial settings are a compromise between a normal condition and a worst case condition Contact logic from the position of the source breakers can select which settings group is act...

Page 231: ...8 18 Output Seal In Logic Diagram Table 8 32 Output Contact Seal in Logic Command Purpose SG HOLD1 0 Turn off the hold timer for output 1 SL 62 1 IN1 0 Set the timer logic to mode 1 pickup dropout IN...

Page 232: ...on One Line Drawing 87 Mode1 87RT 87RPU IN4 63_SPR OPTO P0004 08 vsd 08 22 00 BLK 5 Note For clarity multiple variables going to the same OR Gate are shown by a single line into the OR Gate 87UT 2NDHA...

Page 233: ...gure 8 20 when the SPR contact closes IN4 will cause VO13 to go true This causes OUT1 OUT2 and OUT3 to close and OUT5 which would be wired in the close circuit to open VO13 is sealed in through VO9 wh...

Page 234: ...8 56 Application BE1 CDS220 This page intentionally left blank...

Page 235: ...9 SECURITY 9 1 INTRODUCTION 9 1 Setting Up Password Protection 9 1 Figures Figure 9 1 General Operation Screen Global Security Tab 9 2 Figure 9 2 General Operation Screen Global Security Tab with Pas...

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Page 237: ...M0 and the front panel human machine interface HMI are treated as the same port The communication ports and password parameters act as a two dimensional control to limit changes In order for a command...

Page 238: ...ds Passwords may be entered in the text boxes for Global Access Settings Access Reports Access and Control Access See Figure 9 2 Each access level may be enabled or not enabled for COM 0 Front RS232 a...

Page 239: ...Purpose Password User defined alphanumeric string with a maximum of 8 characters A setting of 0 zero disables password protection Com ports 0 Front RS 232 port 1 Rear RS 232 port 2 Rear RS 485 port M...

Page 240: ...9 4 Security BE1 CDS220 This page intentionally left blank...

Page 241: ...0 3 BE1 CDS220 Menu Tree Top Level All Branches 10 3 Figure 10 4 BE1 CDS220 Menu Tree Report Status 10 4 Figure 10 5 BE1 CDS220 Menu Tree Control Branch 10 5 Figure 10 6 BE1 CDS220 Menu Tree Metering...

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Page 243: ...the relay C Relay Trouble Indicator This red LED lights momentarily during start up and lights continuously when a relay failure is detected Section 6 Reporting and Alarm Functions provides a complete...

Page 244: ...tors These red LEDs light to indicate that a programmable alarm has been set Each indicator can be programmed to annunciate one or more conditions Section 6 Reporting and Alarm Functions provides deta...

Page 245: ...ed to return to the top of the menu branch The six branches of the menu tree are illustrated in Figure 10 3 and summarized in the following paragraphs STATUS BE1 CDS220 REPORT STATUS SETUP vTARG CTRL...

Page 246: ...1 1 3 1 NOTE 1 Up to 16 screens 2 No nav aids 3 Path on scrolled screen remains intact STAT TARG CT_1 CT CKT 1 IA 2 00K 23 IB 2 00K 23 IC 2 00K 23 IN 2 00K 23 IQ 2 00K DET CT_2 1 1 2 STAT TARG CT_2 CT...

Page 247: ...3 143 SWITCH LABEL ACTION 1 STATE NOTUSED 0 STATE 43 243 CONTROL CONTROL STAT v43 METER 2 CTRL 43 43 AUX SWITCHES OUT v43 BKR 2 1 CTRL SG SETTING GROUP CONTROL LOGIC OVERRIDE x BKR OUT CTRL OUT OUTPUT...

Page 248: ...100K 12 133 255 I_CAL I_CAL 3 1 1 1 CRNT CT_1 I_MEAS IA IC IB IA IC IB S 2 000K 2 300K 2 100K 12 133 255 I_CAL I_CAL 3 1 1 1 CRNT CT_1 I_CALC IN IQ S NA 2 300K NA I_MEA I_MEA 3 1 1 2 METER DIFF COMP...

Page 249: ...ETS 5 7 97 16 01 23 456 PREV vDET PREV 4 6 4 1 1 4 1 2 REPRT XFORMER TRANSFORMER REPORT SUMMARY DMD vDET VERS REPRT DMD RESET PEAK DEMAND SINCE RST YEST vI_ABC TODAY REPRT DMD YEST PEAK DEMAND YESTERD...

Page 250: ...B1R 51N G 1 0 0 20 B5 51Q 0 xx x x xx C4R 151 151 PROT SG0 51 151 MODE PU TD CRV 151P 2 10 3 9 99 B1R 151N 2 1 0 0 21 B5 151Q 2 xx x x xx C4R 51 251 5 1 1 1 5 1 3 1 5 1 1 2 5 1 3 2 5 1 3 5 4 PROT GLOB...

Page 251: ...D DETAILS PHASE NEU Q INTERVAL XX XX XX CT CIRCUIT X X X 6 4 1 SETUP BREAKER BREAKER MONITOR AND ALARM SETUP DMD vDUTY XFRMR SETUP BKR DUTY CONTACT DUTY OPER MODE X MAXIMUM DUTY X XXXe XX PRI AMPS CT...

Page 252: ...scroll pushbutton will freeze the display Repeatedly pressing the RIGHT scroll pushbutton will progress through the scroll list in ascending order Repeatedly pressing the LEFT scroll pushbutton will...

Page 253: ...of the LCD HMI Control functions can be edited from menu branch 2 CONTROL Settings for general and reporting functions can be edited from menu branch 6 GENERAL SETTINGS To edit a setting using the ma...

Page 254: ...pen 0 state for Virtual Switch 243 Switch 243 open state label set to 87_OFF D Icon to show the current switch position status In Figure 10 11 the current status is the closed state which is labeled N...

Page 255: ...field of 8 asterisks appears with the cursor located under the leftmost character position You can enter passwords by performing the following procedures 1 Press the UP or DOWN scrolling pushbuttons...

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Page 257: ...Command Descriptions 11 3 HELP Command 11 3 ACCESS Command 11 3 EXIT Command 11 4 Settings S Command Descriptions 11 5 Reading All Settings 11 5 Reading Specific Groups of Settings 11 5 Reading Logic...

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Page 259: ...provides security against unauthorized operation Detailed information about making communication connections is provided in Section 12 Installation Communications port setup is covered in this section...

Page 260: ...time metering values No subgroup is used with metering commands REPORTS R Reports commands read and reset reporting functions such as time and date demand registers and breaker duty statistics Subgrou...

Page 261: ...tax and functionality when the manual is not available Entering HELP or H provides information about using the HELP command HELP1 or H1 returns a complete list of relay commands Entering HELP cmd wher...

Page 262: ...hen entering any string will provide access to the unprotected privileges Note In examples throughout this manual relay responses are printed in Courier New typeface ACCESS Command Examples Example 1...

Page 263: ...ers in the same form that they are programmed It can be used at the end of a programming session to make a record of the relay settings If saved in a file the report can be sent to another BE1 CDS220...

Page 264: ...87U 87R 87N D 251P 251N 251Q 151P 151N 151Q 51P 51N 51Q 0 SG TRIGGER BFT VO11 VO12 BFPU 2NDHAR 5THHAR SG ID1 BE1 CDS SG ID2 SUBSTATION_1 SG ID3 USER1_ID SG ID4 USER2_ID SG CLK M 24 0 SG SCREEN1 1 4 6...

Page 265: ...ic Information Syntax SL name Example SL SL or SL BASIC 87 Comments No password access is required to read settings Entering SL by itself returns all of the logic equations associated with the active...

Page 266: ...The following parameters pertain to relays using Modbus communication protocol at COM2 MFx ModbusTM extended precision format where x 0 for floating point or 1 for triple precision MPx ModbusTM parit...

Page 267: ...on Syntax HELP cmd or H cmd for help on cmd H1 for command list Example HELP H1 H SG COM Reference Section 11 ASCII Command Interface Miscellaneous Command Descriptions Metering Commands M Command Pur...

Page 268: ...d differential currents compensated currents Iop Syntax MD I p P S where p A B C G N Example MD I or MD IN or MD I S Reference Section 5 Metering MD ICOMP Command Purpose Read differential currents co...

Page 269: ...ort Example RA DIFF displays the differential report Reference Section 6 Reporting and Alarm Functions Differential Current Monitoring Function RA LGC Command Purpose Report Reset Logic Alarm informat...

Page 270: ...le RD Reference Section 6 Reporting and Alarm Functions Demand Functions RD PI Command Purpose Read Reset peak demand current I Syntax D PI p 0 where p A B C N Q Example D PI or RD PIA or RD PIN or RD...

Page 271: ...43STAT Command Purpose Report 43 status Syntax RG 43STAT Example RG 43STAT Reference Section 6 Reporting and Alarm Functions General Status Reporting RG ADDR Command Purpose Report Set COM1 COM2 Addre...

Page 272: ...mand Purpose Report OUTPUT status Syntax RG OUTSTAT Example RG OUTSTAT Reference Section 6 Reporting and Alarm Functions General Status Reporting RG TARG Command Purpose Report Reset Target status Syn...

Page 273: ...reset NEW records counter Reference Section 6 Reporting and Alarm Functions Sequence of Events Recorder Function RT Command Purpose Read Transformer Duty Status Syntax RT Example RT Reference Section...

Page 274: ...arm setting mask Syntax SA LGC alarm num 1 alarm num 2 alarm num n Example SA LGC or SA LGC 2 6 7 10 11 Reference Section 6 Reporting and Alarm Functions Alarms Function SA MAJ Command Purpose Read Se...

Page 275: ...Command Descriptions SG CLK Command Purpose Read Program format of date and time display Syntax SG CLK date format M D time format 12 24 dst enable 0 1 Example SG CLK D 12 1 or SG CLK M 24 0 Referenc...

Page 276: ...ing Inputs SG LOG Command Purpose Read Set load profile interval Syntax SG LOG interval where interval is between 1 and 60 minutes Example SG LOG or SG LOG 15 Reference Section 6 Reporting and Alarm F...

Page 277: ...CKTMON mode monitor status Example SL CKTMON or SL CKTMON 1 IN6 IN2 Reference Section 4 Reporting and Alarm Functions Trip Circuit Monitor SL GROUP Command Purpose Read Set Logic for Setting Group Mod...

Page 278: ...ode 0 1 2 Example SL 51 or SL 51P 1 0 or SL 151N 1 IN3 or SL 251Q 2 IN2 Reference Section 4 Protection and Control Overcurrent Protection SL 62 Command Purpose Read Set Logic for x62 Function Modules...

Page 279: ...0 62 0 5s 0 2s or S2 162 30c 12c Reference Section 4 Protection and Control General Purpose Logic Timers S g 87 Command Purpose Read Set the 87 parameters Syntax S g 87 minpu slope 2nd 5th URO 2nd har...

Page 280: ...rol Setting Groups ST DUTY Command Purpose Read Set Transformer Duty where mode 0 1 2 disable I t I 2 t Syntax ST DUTY mode dmax ct ckt BLKTXFMR logic Example ST DUTY 1 60E3 1 IN5 Reference Section 6...

Page 281: ...rmer Action 12 11 Figure 12 15 Example of Reversed CT Polarity 12 11 Figure 12 16 Typical Transformer Differential Connection 12 12 Figure 12 17 Typical Connection for Motor or Reactor Differential Pr...

Page 282: ...nal Computer to BE1 CDS220 12 26 Figure 12 29 Modem to BE1 CDS220 12 26 Figure 12 30 RFL9660 Protective Relay Switch to BE1 CDS220 Cable 12 26 Figure 12 31 SEL 2020 to BE1 CDS220 Relay 12 27 Figure 12...

Page 283: ...s or 69 Vdc for 125 Vdc nominal sensing voltages See Table 12 1 for the nominal turn on voltage ranges Table 12 1 Contact Sensing Turn On Voltage Nominal Turn On Voltage Range Nominal Control Voltage...

Page 284: ...er com register Registering your relays s with Basler Electric will give you Internet access to the latest BESTCOMS software and firmware updates for your devices In addition registration also allows...

Page 285: ...cations of the studs used for mounting Figure 12 9 shows the panel cutout and panel drilling dimensions for the MX case vertical panel mounting configuration Horizontal panel mounting configurations h...

Page 286: ...0 3 81 7 75 196 85 8 85 224 79 P0033 24 01 05 06 Figure 12 4 MX Case 19 Inch Rack Mount Side View Overall Dimensions 5 40 137 16 7 75 196 85 8 70 220 98 D2837 06 01 08 99 Figure 12 5 MX Case Vertical...

Page 287: ...9 23 1 344 TYP 34 14 975 TYP 24 77 225 TYP 5 72 250 TYP 6 35 275 TYP 6 99 6 61 167 89 5 563 141 30 250 DIA HOLES 18 PLC S WESTINGHOUSE FT31 or FT32 Hole Pattern 4 PLC S BASLER M1 4 PLC S G E M2 4 PLC...

Page 288: ...12 6 Installation BE1 CDS220 D2837 05 06 22 00 14 50 368 3 14 32 363 73 940 TYP 23 88 1 00 25 4 075 TYP 1 91 Figure 12 7 MX Case Vertical Panel Mount Side View Overall Dimensions...

Page 289: ...BE1 CDS220 Installation 12 7 Figure 12 8 MX Case Horizontal Panel Mount Front View Overall Dimensions...

Page 290: ...Vertical Panel Mount Panel Drilling Diagram NOTE The dimensions of the panel drilling diagram are for the MX case vertical panel mount or the MX case horizontal panel mount Rotate this drawing ninety...

Page 291: ...it wiring and should not be removed Without the lock washer the 8 32 screw may bottom out and prevent a good mechanical connection with the terminal block Maximum wire lug width accommodated by Termin...

Page 292: ...11 Typical AC Connection Diagram POWER SUPPLY 1 IN IN 2 4 IN IN 3 A2 A3 C17 C18 C20 C19 C21 C22 C23 C24 Part of CONTROL POWER 52b C25 C27 C29 C31 IN 5 C26 IN 6 C28 IN 7 C30 IN 8 C32 BE1 CDS OUT 1 2 OU...

Page 293: ...th the primary See Figures 12 13 and 12 14 D2877 06 07 17 00 Figure 12 13 Standard CT Polarity Figure 12 14 Current Transformer Action On occasion however protection engineers will encounter situation...

Page 294: ...connection wye delta AB or Delta AC For more information refer to Section 3 Input And Output Functions Input Current Optional independent ground input IG can be connected for overcurrent or neutral di...

Page 295: ...cation Overcurrent neutral ground IN operates on internally calculated residual 3I0 current For complete metering and independent backup protection for motors and reactors add a BE1 951 Overcurrent Pr...

Page 296: ...w Side Breaker 52 A B C Optional 1 3 2 1 3 4 B14 B10 B12 B13 B11 D5 D6 D3 D4 D1 D2 7 Circuit Switcher 9 D7 D8 Optional 8 IG IG IC1 IB1 IA1 IC2 IB2 IA2 IA IC VB 6 VA VC C15 C14 C13 C16 VN BE1 951 5 4 P...

Page 297: ...information on applying overcurrent backup refer to Section 8 Application Overcurrent neutral ground IN operates on internally calculated residual 3I0 current VTP connections shown are for H1 case For...

Page 298: ...blem 5 Phase Residual and I2 overcurrent elements can be connected to either CT circuit for backup protection For more information on applying overcurrent backup refer to Section 8 Application Overcur...

Page 299: ...t for backup protectiion For more information on applying overcurrent backup refer to Section 8 Application Overcurrent neutral ground IN operates on internally calculated residual 3I0 current For com...

Page 300: ...aults A loaded tertiary requires the application of a three input current differential scheme Phase Residual and I2 overcurrent elements can be connected to either CT circuit for backup protection For...

Page 301: ...uit for backup protectiion For more information on applying overcurrent backup refer to Section 8 Application Overcurrent neutral ground IN operates on internally calculated residual 3I0 current For c...

Page 302: ...phase input circuit must be connected in wye with zero sequence compensation for the grounded winding provided by internal delta compensation 1 BE1 CDS220 B10 B14 B12 B9 B13 B11 X1 X2 X3 1 Low Side B...

Page 303: ...BE1 951 Overcurrent Protection System with the BE1 CDS220 A BE1 951 on the Bus Source Breaker can also be used in conjunction with Feeder BE1 851 or BE1 951 relays to create a high speed bus interloc...

Page 304: ...up refer to Section 8 Application Overcurrent neutral ground IN operates on internally calculated residual 3I0 current Four wire connection shown as typical For more information on case connections se...

Page 305: ...n on applying overcurrent backup refer to Section 8 Application Residual current not available on delta connected CTs Overcurrent neutral ground IN operates on internally calculated residual 3I0 curre...

Page 306: ...on applying overcurrent backup refer to Section 8 Application Residual current not available on delta connected CTs Overcurrent neutral ground IN operates on internally calculated residual 3I0 curren...

Page 307: ...nsing versus virtual sensing Settings validation Proper operation of equipment main or auxiliary Proper alarming to SCADA and or targeting Refer to Section 7 BESTlogic Programmable Logic for informati...

Page 308: ...N C N C N C N C Figure 12 28 Personal Computer to BE1 CDS220 20 7 6 3 2 1 1 2 3 4 5 TXD RXD 5V SGND TXD RXD N C SGND 50 FEET MAX FEMALE DB 9 DCE FEMALE DB 25 DCE 06 23 00 P0001 16 DTR 9 6 7 8 N C N C...

Page 309: ...Table 12 3 An RS 485 connection diagram is provided in Figure 12 32 Table 12 3 RS 485 Pinouts COM 2 Terminal Function Name Direction D5 A Send Receive A SDA RDA In Out D4 B Send Receive B SDB RDB In O...

Page 310: ...supports IRIG Standard 200 98 Format B002 The demodulated dc level shifted input signal must be 3 5 volts or higher to be recognized as a high logic level The maximum acceptable input voltage range is...

Page 311: ...with Internal Compensation 13 9 Phase Differential Restrained Minimum Pickup Trip 13 11 Phase Differential Restrained Slope Trip 13 12 Phase Differential Unrestrained Trip 13 18 Verify Other Set Point...

Page 312: ...13 68 Automatic Setting Group Change 13 69 Automatic Change 13 69 Manual Change Mode 1 13 72 Manual Change Mode 2 13 73 MAINTENANCE 13 74 Figures Figure 13 1 BE1 CDS Rear View Terminal Connections 13...

Page 313: ...Restrained Element Response Time Setup Commands 13 41 Table 13 28 Restrained Trip Operate Times 13 42 Table 13 29 Second Harmonic Restraint Elements Setup Commands 13 43 Table 13 30 Fifth Harmonic Res...

Page 314: ...ode 6 Timer Initiate Commands 13 68 Table 13 80 Automatic Setting Group Change Function Test Commands 13 69 Table 13 81 Automatic Group Control Selection 13 70 Table 13 82 Time Overcurrent 51P Element...

Page 315: ...unctional or commissioning tests Basler Electric performs detailed acceptance testing on all devices to verify all functions meet published specifications All products are packaged and shipped using s...

Page 316: ...n be subjected to a recreation of captured events with the aide of equipment capable of replicating COMTRADE record files In these instances there is significant merit in testing relays in this manner...

Page 317: ...port on the last events The following summarizes the reporting capabilities of the relay through the optional front panel HMI Flashing Trip LED flashes during pickup of protective elements based on th...

Page 318: ...self test During this brief test all front panel LEDs will flash momentarily the display will indicate each step of the self test relay model software version and then settle into the default display...

Page 319: ...cation Purpose To verify that the BE1 CDS relay model number style number and current software program version matches the unit unit labels Reference Commands RG VER Step 1 Through any communications...

Page 320: ...rnatively transmit the command RG STAT and review the response at the tail end of the line INPUT 12345678 You may also view the input status on HMI screen 1 4 1 STAT OPER INPUT Step 4 Transmit the com...

Page 321: ...contacts and then verify that the sequence of events recorder logged the events Current Circuit Verification Purpose To verify that the relay internal CT circuits accurately measures currents and pola...

Page 322: ...s or to change setting logic to test a specific function Always remember to enable these functions and install operation settings before placing the relay in service To guard against placing the relay...

Page 323: ...llowing tests The settings for the following tests should be recorded before starting the test You will refer to these settings throughout the test procedure Angle Compensation and Ground Source compe...

Page 324: ...hese currents are the compensating currents when the relay is in service for this application Under a test scenario any set of balanced 180 out of phase single phase input currents that we apply to th...

Page 325: ...ero Sequence Compensated Currents Angle Compensation And Ground Source Settings 87A Element 87B Element 87C Element CT1 CT2 CT1 CT2 CT1 CT2 CT1 CT2 WYE NONE WYE NONE IA IA IB IB IC IC WYE NONE WYE G I...

Page 326: ...Minpu Tap DAB NA NA 3 Minpu Tap 3 Minpu Tap DAC NA 3 Minpu Tap NA 3 Minpu Tap Step 3 Test minimum pickup Slowly ramp up test current until the relay trips Monitor an appropriate contact per the logic...

Page 327: ...I1 decreasing with maximum restraint y1MI I1 increasing with maximum restraint y1AD I1 decreasing with average restraint y1AI I1 increasing with average restraint Condition Restraint Min PU Trip If M...

Page 328: ...DAB 2 tap 2 3 tap 13 6 B Y Y N WYE G DAB 2 tap 2 3 tap 13 6 C N Y Y WYE G DAC 2 tap 2 3 tap 13 7 A Y Y N WYE G DAC 2 tap 2 3 tap 13 7 B N Y Y WYE G DAC 2 tap 2 3 tap 13 7 C Y N Y DAB WYE 2 3 tap 2 tap...

Page 329: ...B2 IB2 B11 B12 IB1 B3 B4 IC2 B13 B14 IC1 B5 B6 IA2 B9 B10 IA1 B1 B2 IB2 B11 B12 IB1 B3 B4 IC2 B13 B14 IC1 B5 B6 IA2 B9 B10 IA1 B1 B2 IB2 B11 B12 IB1 B3 B4 IC2 B13 B14 IC1 B5 B6 A B C D2857 27 vsd 05...

Page 330: ...B2 IB2 B11 B12 IB1 B3 B4 IC2 B13 B14 IC1 B5 B6 IA2 B9 B10 IA1 B1 B2 IB2 B11 B12 IB1 B3 B4 IC2 B13 B14 IC1 B5 B6 IA2 B9 B10 IA1 B1 B2 IB2 B11 B12 IB1 B3 B4 IC2 B13 B14 IC1 B5 B6 A B C D2857 30 vsd 05...

Page 331: ...arting balanced test current will not result in a minimum pickup trip Use the appropriate equation under the column heading Min PU in Figure 13 3 If it will result in a minimum pickup adjust both star...

Page 332: ...nrestrained test Step 7 1 Calculate the test points using the compensation settings recorded in Step 1 and the appropriate equations shown in Tables 13 8 through 13 10 In this case substitute the unre...

Page 333: ...virtual outputs and their Boolean logic equations Verify that the desired virtual output equations match the reported equations Verify the programmable hold timer setting for each hardware output by t...

Page 334: ...ugh CTRL 43 743 Step 5 Obtain write access to the relay by using the ACCESS command For each virtual selector switch enabled in your logic scheme change the switch position by entering CS x43 1 TRUE 0...

Page 335: ...s as required for the system installation Reference Commands RD PI RD PI p Refer to Section 6 Reporting and Alarm Functions Demand Functions for setting details To use the optional front panel HMI go...

Page 336: ...access to the reporting functions R password and then initiate the RG TARG 0 command or press the RESET key while the optional front panel HMI screen 1 1 STAT TARGETS screen is displayed Purpose To v...

Page 337: ...mmended that the load be placed on the protected zone and a differential check record be triggered recorded and examined See Section 6 Reporting and Alarm Functions Differential Current Monitoring Fun...

Page 338: ...he load picked up results in a trip scenario 4 examine the fault summary and oscillography records to determine the cause of the trip If it is not a fault re energize the transformer and pick up less...

Page 339: ...ngle Tap CT CKT1 WYE 3 12 CT CKT2 DAC 4 68 ALARMS PHASE A PHASE B PHASE C DIFFERENTIAL OK OK OK POLARITY OK OK OK ANGLE COMP OK OK OK MISMATCH OK OK OK MEASUREMENTS PHASE A PHASE B PHASE C MEASURED I...

Page 340: ...ts the same as expected Does the phase sequence match the phase sequence setting SG PHROT or HMI screen 6 3 3 Examine the angle and tap compensated currents on the polar graph from the line labeled Ta...

Page 341: ...of the relay digital I O connections can be accomplished in several ways depending upon the user s preferences and practices Repeating the digital I O connection verification commissioning tests Monit...

Page 342: ...sion of BESTCOMS software BESTCOMS can also be downloaded from the Basler Electric web site http www basler com An on line form can be completed to obtain a password for downloading BESTCOMS from the...

Page 343: ...RT to log and trigger fault recording E Exit Y Save settings Step 3 Send to the relay the commands listed in Table 13 14 NOTE The tap settings listed in the S TAP87 command are within the range of set...

Page 344: ...Verify that pickup occurred within the specified accuracy of the relay see Table 13 15 as indicated by the low and high limits in Table 13 16 Table 13 15 Sensing Input Type Accuracy CT secondary rati...

Page 345: ...NPU values Step 8 Optional Confirm that the relay acknowledged each change of state of OUT1 87 restrained trip by using the RS command Gain write access to the relay a and reset the new events counter...

Page 346: ...inimum pickup operating characteristic and dividing it by the slope For example for a minimum pickup setting of 0 30 and a slope setting of 15 the knee of the operating curve is plotted at a point equ...

Page 347: ...s decreased from balance the maximum restraint has a vertical characteristic When increasing one current relative to the other it will shift to the right with a sloping characteristic as it continues...

Page 348: ...2 current at balance 3 per unit 11 40 amperes Input 1 is being increased relative to a fixed input 2 current Thus the maximum restraint used by the relay is input 1 the larger of the two currents in...

Page 349: ...g characteristic diagram If you are applying this relay using the maximum restraint operating characteristic continue with Step 4 Otherwise you may proceed directly to Step 12 to test the average rest...

Page 350: ...129 1 0 35 30 0 40 1 0 76 1 0 57 0 025 0 49 0 025 1 0 35 30 2 00 5 3 80 5 2 86 0 114 2 66 0 106 1 0 35 45 0 40 1 0 76 1 0 73 0 029 0 42 0 025 1 0 35 45 2 00 5 3 80 5 3 64 0 146 2 09 0 084 1 0 35 60 0...

Page 351: ...from balance increasing current from balance D2857 14 vsd 10 15 99 Average Restraint Operating Characteristic Sidebar 13 6 Average Restraint When Increasing One Input from Balance In order to test th...

Page 352: ...CURRENT IN MULTIPLES OF TAP 1 2 3 Slope IOP 100 IRESTR 15 minimum pickup 0 30 x tap Differential current 3 243 Average Restraint Characteristic Example You may also use the average restraint operatin...

Page 353: ...ed URO disabled 2 nd harm sharing 1 yes E Exit Y Save settings Step 13 Apply balancing current to phase A input 1 and phase A input 2 at the magnitude indicated in each row of either Table 13 24 5 amp...

Page 354: ...alues for testing the relay either by increasing one current from a balanced condition or decreasing it Either technique can be utilized to test this function Refer to the descriptions of both methods...

Page 355: ...lements Table 13 27 Restrained Element Response Time Setup Commands Command Purpose A Gain access SL N NONE Zero out custom logic settings overwrite with logic none settings Y Confirm overwrite SL N D...

Page 356: ...n Table 13 28 Table 13 28 Restrained Trip Operate Times Function Differential current Time Restrained trip 1 5 times pu Less than 3 cycles Restrained trip 5 times pu Less than 2 cycles Second Harmonic...

Page 357: ...ude from Step 4 that caused OUT 2 to close and OUT1 to open These output contact changes indicated that the 2 nd harmonic restraint function is now restraining the 87RT operation Step 6 Remove both 60...

Page 358: ...ared E Exit Y Save settings Step 3 Apply 2 0 amps of 60 Hz current to the A phase input 1 The OUT1 87RT restrained trip output contact should close upon application of current Step 4 Apply 300 Hz curr...

Page 359: ...hared E Exit Y Save settings Step 3 Apply current to A phase input 1 increasing the magnitude until OUT1 closes Since the URO setting is 1 and Tap 1 2 this should occur at 2 amperes Accuracy when incr...

Page 360: ...put 1 and A phase input 2 at 180 o phase relation to input 1 Step 4 To force an unrestrained trip at 1 5 times pickup you must apply a step change in the current on input 2 to 8 0 amps Apply step chan...

Page 361: ...5 B10 B12 B14 B16 IA1 IB1 IC1 IG IA2 IB2 IC2 IA1 IB1 IC1 IG IA2 IB2 IC2 Figure 13 15 Connection for 87ND Minimum Pickup Verification Step 2 To prepare the 87ND element for testing transmit the command...

Page 362: ...ground input and slowly ramp up until OUT1 closes Step 5 Accuracy when increasing or decreasing the input current is 4 of setting or 75 milliamperes whichever is larger for 5 ampere sensing inputs and...

Page 363: ...87ND 2 0 Enables 87ND mode IG v CT2 no blk SL VO1 87NDT Enables OUT1 to close for 87ND restrained trip SG CT2 1 WYE NA 0 input 2 ctr 1 ct wye xfmr na no grd source SG CTG 1 gnd input ctr 1 SG TRIGGER...

Page 364: ...2 00 Calc Tap 2 00 From Balance From Balance Type Pickup Bal Input A PU Bal Input A PU Pickup A Pickup A 5 0 35 15 2 00 1 2 00 1 2 70 0 108 1 30 0 075 5 0 35 15 10 00 5 10 00 5 11 76 0 470 8 50 0 340...

Page 365: ...TN and S0 50TQ from Table 13 41 to the relay If your relay is supplied with the HMI option you may also go to the front panel interface screen PROT SG0 50T 50T and edit the S0 50TP S0 50TN and S0 50TQ...

Page 366: ...SL VO2 150TNT SL VO3 50TQT SL VO3 150TQT SG TARG 50T SG TARG 150T SG TRIGGER 50TPT 50TNT 50TQT 50TPPU 50TNPU 50TQPU 0 SG TRIGGER 150TPT 150TNT 150TQT 150TPPU 150TNPU 150TQTPU 0 Table 13 44 Instantane...

Page 367: ...of a power system and the equipment Under unbalanced fault conditions these components will very likely be harmful to equipment and potentially to personnel Positive sequence components are comprised...

Page 368: ...51PT 51NT 51QT 51PPU 51NPU 51QPU 0 Enable 51PT 51NT 51QT to log targets and trigger fault recording E Exit Y Save settings Step 3 Transmit to the relay the appropriate row of the setting commands S0 5...

Page 369: ...U 0 Table 13 49 Time Overcurrent 251 Element Test Logic Replace These Commands With These Commands For 251 Element Tests SL 51 1 0 SL 251 1 0 SL VO1 51PT SL VO1 251PT SL VO2 51NT SL VO2 251NT SL VO3 5...

Page 370: ...TRIGGER 51PT 51NT 51QT 51PPU 51NPU 51QPU 0 Enable 51PT 51NT 51QT to log targets and trigger fault recording E Exit Y Save settings Step 3 Transmit to the relay the appropriate row of the setting comma...

Page 371: ...s respectively Use Table 13 51 or 13 52 as a reference for substituting the commands used in Step 1 Step 9 Optional Repeat steps 1 through 8 for the 51 151 and 251 elements in setting groups 1 2 and 3...

Page 372: ...rent Detector Dropout Settings Sensing Type Dropout Setting A or B 1 ampere nominal systems 0 1 A D E or F 5 ampere nominal systems 0 5 A Step 3 Connect a current source to terminals B1 and B2 A phase...

Page 373: ...each of the eight virtual switches In your testing you may substitute any or all of the switches as you choose If you give an invalid command such as CS 243 1 CO 243 1 when switch 243 is programmed fo...

Page 374: ...e Result OUT1 contact closes for 200 milliseconds and returns to the open state Table 13 60 Mode 1 Test Commands Command Purpose CS 43 P Selects virtual switch 43 for change to closed true state and r...

Page 375: ...ify virtual switch Mode 3 operation Reference Commands SL 243 CS CO 243 Step 1 Prepare for Mode 3 testing by transmitting the commands in Table 13 64 to the relay Table 13 64 Mode 3 Test Commands Comm...

Page 376: ...screen CTRL BKR or by using the RG STAT command See Section 6 Reporting and Alarm Functions for more information Step 3 Send the commands in Table 13 67 to the relay or if the optional HMI is supplied...

Page 377: ...utput based on the 400 millisecond pickup time setting Table 13 70 x62 Mode 1 Timer Initiate Commands Command Purpose A Gain write access CS 43 1 Selects 43 for close operation CO 43 1 Executes 43 for...

Page 378: ...te input by pulsing the 143 switch from a FALSE state to a TRUE state and then back to a FALSE state You may view the state changes of the 143 switch at front panel interface CTRL 43 143 screen 2 1 2...

Page 379: ...ables 62 1 shot re triggerable mode 343 initiate no blocking S0 62 15s 20s Sets 62 delay at 15 seconds 62 dropout at 20 seconds EXIT Exit Y Save settings Step 2 Send the commands in Table 13 75 to the...

Page 380: ...the third FALSE to TRUE initiate signal forced the 62 timer T1 to restart Fifteen seconds after the third 343 FALSE to TRUE initiate signal the 62 timer output went TRUE again and then went FALSE aft...

Page 381: ...o longer than 10 seconds to interrupt the T1 timer CS 43 0 Selects 43 for FALSE operation CO 43 0 Executes 43 for FALSE operation Wait at least 5 seconds for the T2 timer to time out and reset the int...

Page 382: ...te to TRUE and a reset command by changing the BLK input 143 switch to TRUE NOTE The CS and CO commands of Table 13 79 are performed two times Follow the timing sequence to illustrate timer mode actio...

Page 383: ...mands in Table 13 80 to the relay Table 13 80 Automatic Setting Group Change Function Test Commands Command Purpose A Gain access SL N NONE Zero out custom logic settings overwrite with logic none set...

Page 384: ...on you may also go to the front panel interface screen PROT SG0 51 51 and edit the 51P settings After you send the commands to your relay EXIT and save Y the changes An ohmmeter or continuity tester m...

Page 385: ...e commands in Table 13 84 Table 13 84 Automatic Group Control Selection Command Purpose A Gain access CS 143 1 Selects 143 for TRUE operation CO 143 1 Executes 143 TRUE operation setting group 1 E Exi...

Page 386: ...p logic block that the active setting group remained SG3 Verify the events that occurred in reverse order when the current was being stepped down Manual Change Mode 1 Manual Change Mode 1 test procedu...

Page 387: ...res are a continuation of the Mode 1 test procedures Do not change the logic or settings except for those in Step 1 and subsequent Step 1 Send to the relay the commands in Table 13 88 Table 13 88 Bina...

Page 388: ...e case When the drawout assembly is removed the current transformer input circuits are automatically shorted by internal case contacts The case contains no components that are likely to require servic...

Page 389: ...Fault Sequence of Events 14 28 Download Oscillography File 14 28 METERING 14 28 FILE MANAGEMENT 14 29 Saving a Settings File 14 29 Opening a Settings File 14 29 Uploading a Settings File 14 29 Downloa...

Page 390: ...Reporting and Alarms Screen Fault Recording Tab 14 21 Figure 14 27 Inputs and Outputs Screen Inputs 1 4 Tab 14 21 Figure 14 28 Inputs and Outputs Screen Outputs 1 14 A Tab 14 22 Figure 14 29 Virtual S...

Page 391: ...preprogrammed logic schemes that are stored in the relay This gives the engineer the option off line of developing his her setting file using a preprogrammed logic scheme customizing a preprogrammed l...

Page 392: ...ve for installation One available serial port Installing the Program on Your PC Using Microsoft Windows 1 Insert the CD in the PC CD ROM drive 2 When the Setup and Documentation CD menu appears click...

Page 393: ...d want to go to this screen you may use the Screens pull down menu or click on the System Setup Summary icon as is shown at the right margin of this paragraph This screen has two areas or folder tabs...

Page 394: ...second tab of the System Setup Summary screen Figure 14 4 provides the remaining summary information for the relay in regard to monitoring metering and alarms Again a legend for the color coding of r...

Page 395: ...select or name the active logic see the paragraphs on BESTlogic Select Logic Scheme for Display In Figure 14 4 below the pull down Menu bar there is a pull down arrow for the Logic window in the Tool...

Page 396: ...in the serial number of the relay and the various software and firmware application version information Additionally you may enter the name of the relay substation identification and other installati...

Page 397: ...value is entered for you For example if you entered 220 for the Turns value and the secondary nominal current input is 1 the primary amperes value is 220 If you change the secondary nominal current i...

Page 398: ...ake changes in any or all areas Clicking a box for a specific communication port toggles the functional area for that port either ON or OFF Notice that the front panel human machine interface HMI and...

Page 399: ...code for the latest version of BESTCOMS is contained within BESTCOMS If you have an earlier version of the embedded firmware in your relay and selected that information on the General Info tab under...

Page 400: ...is 0 Auxiliary setting groups allow adapting the coordination settings to optimize them for a predictable situation Sensitivity and time coordination settings can be adjusted to optimize sensitivity o...

Page 401: ...to Tap Calculation the MANUAL display changes to AUTO In this mode the transformer MVA can be set in the range of 5 to 9 999 and kv CT can be set in the range of 01 to 1 000 The Restrained Pickup can...

Page 402: ...up is adjusted using the pull down menu with Times Tap as the default Other options include Input 1 2 amps and Input 1 or 2 Full Load The allowed range for Times Tap is 0 010 times tap to 1 000 times...

Page 403: ...overcurrent elements They are divided up into three tabs 51 151 and 251 The pull down Pickup menu allows you to select the relative pickup quantity BE1 CDS220 relays measure the current input in secon...

Page 404: ...e of each phase neutral and negative sequence instantaneous overcurrent elements with settable time delay The screens for the instantaneous elements are almost identical to the 51 screen The settable...

Page 405: ...e delay from when the breaker failure initiate is received and the trip output is asserted first pull down the Units menu and set the units for time measurement i e milliseconds seconds minutes or cyc...

Page 406: ...ng functions see Section 4 Protection and Control Logic settings for the logic timers can be made by clicking on the BESTlogic button and with your custom logic selected Use the Mode pull down menu an...

Page 407: ...se the pull down menu to set the unit of measure for the threshold settings Load Profile is an optional function and is not available on some units This option uses a 4 000 point data array for data s...

Page 408: ...knows when the breaker is closed Set the Breaker Status Logic by clicking on the Logic button With your custom logic selected select the control logic Three breaker alarm points are programmable for c...

Page 409: ...Disabled Enabled I and Enabled I2 100 Duty Maximum in primary amps and Block Accumulation Logic In addition three transformer alarms are provided Points 1 3 The pull down arrows will allow the Mode t...

Page 410: ...y clear the existing programming by clicking on the Clear button or clicking on each individual variable The fault recording function can record up to 32 oscillographic records in non volatile memory...

Page 411: ...u and select Inputs and Outputs or click on the Inputs and Outputs icon that is shown at the right margin of this paragraph This screen has three folder tabs and the first tab is Inputs 1 4 Inputs 1 4...

Page 412: ...in the BE1 CDS220 relay that are set by this tab Functionality is the same as described for Inputs 1 4 Outputs 1 6 A On this tab Figure 14 28 the only feature that you may change is to select the prog...

Page 413: ...101 can be made by clicking on the BESTlogic button With your custom logic selected select the mode logic by using the Mode pull down menu Trip outputs include Trip Close and Slip Contact 443 543 643...

Page 414: ...O1 through VO5 have hardware output contacts To change the label for the True State click on the True State field and enter the new name To change the label for the False State click on the False Stat...

Page 415: ...nd the ASCII command is SB LOGIC for Setting Breaker Logic To program a logic function find the logic function in the list and click on the associated BESTlogic or Logic button The BESTlogic Function...

Page 416: ...st change only those settings that are different With BESTCOMS there is an easy way to do that Pull down the Copy menu from the pull down menu as shown in Figure 14 35 There is only one choice Copy Fr...

Page 417: ...a communication error if you are not configured to an actual relay If you have communication with the relay a dialog box opens Figure 14 38 allowing you to View Download Relay Fault Files If there hav...

Page 418: ...ault Summary also change automatically OK the file names and then exit the dialog box You have now downloaded the oscillography file You may view this oscillography file using Basler Electric s BESTwa...

Page 419: ...ng BESTCOMS Then pull down the Communication menu and select Upload Settings to Device You are prompted to enter the password If the password is correct the upload begins and the percent complete load...

Page 420: ...See Figure 14 41 Select the location of the first file to compare under Left Settings Source and select the location of the second file to compare under Right Settings Source If you are comparing a Se...

Page 421: ...e settings files and document the information It will not write or change any settings in the settings file bst at this time Profile files for each device are needed to print documentation for that pa...

Page 422: ...14 32 BESTCOMS Software BE1 CDS220 This page intentionally left blank...

Page 423: ...0 Figure A 7 Time Characteristic Curve I I1 Inverse Time 99 1373 Similar to ABB CO 8 A 11 Figure A 8 Time Characteristic Curve I2 Inverse Time 99 1597 Similar to GE IAC 51 A 12 Figure A 9 Time Charact...

Page 424: ...ii Time Current Characteristics BE1 CDS220 This page intentionally left blank...

Page 425: ...1 and multiples of 2 to 40 times the pickup setting but not over 150 A for 5 A CT units or 30 A for 1 A CT units Sixteen inverse time functions one fixed time function and one programmable time funct...

Page 426: ...mely Inverse 4 9883 0 01290 1 0000 2 0469 0 0280 4 7742 A A Standard Inverse 0 01414 0 00000 1 0000 0 0200 0 0280 2 0000 B B Very Inverse I 2 t 1 4636 0 00000 1 0000 1 0469 0 0280 3 2500 C C Extremely...

Page 427: ...1P 151N 151Q 251P 251N 251Q ASCII commands or human machine interface HMI Screens 5 x 4 1 51P N Q 5 x 4 2 151P N Q and 5 x 4 3 251P N Q For more information refer to Section 4 Protection and Control O...

Page 428: ...CO 2 99 1369 0 3 0 8 1 7 2 4 3 4 4 2 5 0 5 8 6 7 7 7 8 6 9 7 L1 ABB CO 5 99 1370 0 4 0 8 1 5 2 3 3 3 4 2 5 0 6 0 7 0 7 8 8 8 9 9 D ABB CO 6 99 1371 0 5 1 1 2 0 2 9 3 7 4 5 5 0 5 9 7 2 8 0 8 9 10 1 M A...

Page 429: ...BE1 CDS220 Time Overcurrent Characteristic Curves A 5 Figure A 1 Time Characteristic Curve S S1 Short Inverse 99 1369 Similar to ABB CO 2...

Page 430: ...A 6 Time Overcurrent Characteristic Curves BE1 CDS220 Figure A 2 Time Characteristic Curve S2 Short Inverse 99 1595 Similar To GE IAC 55...

Page 431: ...BE1 CDS220 Time Overcurrent Characteristic Curves A 7 Figure A 3 Time Characteristic Curve L L1 Long Inverse 99 1370 Similar to ABB CO 5...

Page 432: ...A 8 Time Overcurrent Characteristic Curves BE1 CDS220 Figure A 4 Time Characteristic Curve L2 Long Inverse 99 1594 Similar To GE IAC 66...

Page 433: ...BE1 CDS220 Time Overcurrent Characteristic Curves A 9 Figure A 5 Time Characteristic Curve D Definite Time 99 1371 Similar To ABB CO 6...

Page 434: ...A 10 Time Overcurrent Characteristic Curves BE1 CDS220 Figure A 6 Time Characteristic Curve M Moderately Inverse 99 1372 Similar to ABB CO 7...

Page 435: ...BE1 CDS220 Time Overcurrent Characteristic Curves A 11 Figure A 7 Time Characteristic Curve I I1 Inverse Time 99 1373 Similar to ABB CO 8...

Page 436: ...A 12 Time Overcurrent Characteristic Curves BE1 CDS220 Figure A 8 Time Characteristic Curve I2 Inverse Time 99 1597 Similar to GE IAC 51...

Page 437: ...BE1 CDS220 Time Overcurrent Characteristic Curves A 13 Figure A 9 Time Characteristic Curve V V1 Very Inverse 99 1374 Similar to ABB CO 9...

Page 438: ...A 14 Time Overcurrent Characteristic Curves BE1 CDS220 Figure A 10 Time Characteristic Curve V2 Very Inverse 99 1596 Similar to GE IAC 53...

Page 439: ...BE1 CDS220 Time Overcurrent Characteristic Curves A 15 Figure A 11 Time Characteristic Curve E E1 Extremely Inverse 99 1375 Similar to ABB CO 11...

Page 440: ...A 16 Time Overcurrent Characteristic Curves BE1 CDS220 Figure A 12 Time Characteristic Curve E2 Extremely Inverse 99 1598 Similar to GE IAC 77...

Page 441: ...BE1 CDS220 Time Overcurrent Characteristic Curves A 17 Figure A 13 Time Characteristic Curve A Standard Inverse 99 1621...

Page 442: ...A 18 Time Overcurrent Characteristic Curves BE1 CDS220 Figure A 14 Time Characteristic Curve B Very Inverse 99 1376...

Page 443: ...BE1 CDS220 Time Overcurrent Characteristic Curves A 19 Figure A 15 Time Characteristic Curve C Extremely Inverse 99 1377...

Page 444: ...A 20 Time Overcurrent Characteristic Curves BE1 CDS220 Figure A 16 Time Characteristic Curve G Long Time Inverse 99 1622...

Page 445: ...screens Commands are organized by function in the following groups and tables Miscellaneous Table B 1 Metering Table B 2 Control Table B 3 Report Table B 4 Setting Table B 5 Alarm Setting Table B 6 G...

Page 446: ...phase Read CT circuit 1 current primary or secondary units 3 1 1 1 M2 Read CT circuit 2 current primary or secondary units all phases 3 1 2 M2 phase Read CT circuit 2 current primary or secondary unit...

Page 447: ...Address for Polled Communications 6 1 x RG BREAKER Report general information breaker status 1 4 5 RG DATE M D Y Read Set date 1 4 6 RG GRPACTIVE Report active group 1 4 4 RG GRPCNTRL Report group lo...

Page 448: ...len R reply ack X XON ena Read Set serial communication protocol 6 1 x SG CT t CTratio Read Set Phase Neutral CT ratio 6 3 1 x SG DI p interval method ct ckt Read Set demand interval method and CT cir...

Page 449: ...able Name Setting Command ASCII Command Function HMI Screen SN var name TRUE label FALSE label Read Set user programmable names N A Table B 11 Protection Setting Commands ASCII Command Function HMI Sc...

Page 450: ...B 6 Command Cross Reference BE1 CDS220 Table B 12 Global Command ASCII Command Function HMI Screen GS PW t password com ports 0 1 2 Read or change a password N A...

Page 451: ...INAL C 1 WINDOWS TERMINAL C 2 Figures Figure C 1 Connection Description Dialog Box C 1 Figure C 2 COM Properties Dialog Box C 1 Figure C 3 ASCII Setup Dialog Box C 2 Figure C 4 Terminal Preferences Di...

Page 452: ...ii Terminal Communication BE1 CDS220 This page intentionally left blank...

Page 453: ...ER a Click drop down menu CONNECT USING Select Direct To ComX where X is the port you are using on your computer b Click OK Step 6 Dialog Box COMX Properties a Make the following selections using Figu...

Page 454: ...k File and click Save Figure C 3 ASCII Setup Dialog Box Step 9 HyperTerminal is now ready to communicate with the relay Table C 1 describes the required connection for each RS 232 port Table C 1 RS 23...

Page 455: ...lowing changes using Figure c 6 as a guide Under Connector select the appropriate communication port for your computer Adjust the Baud Rate setting so that it matches the setting of the relay The defa...

Page 456: ...C 4 Terminal Communication BE1 CDS220 This page intentionally left blank...

Page 457: ...Maximum External Fault D 6 Calculate Slope D 7 Harmonic Restraint Settings D 10 SETTING NOTE 1 CT PERFORMANCE EVALUATION SATURATION FACTOR D 11 Saturation Factor Defined from the ANSI C Classification...

Page 458: ...ii Settings Calculations BE1 CDS220 This page intentionally left blank...

Page 459: ...gure D 1 and Table D 1 for the application parameters used in this example 11 05 99 D1873 21 3 1916 3 1171 1 300 5T 600 5MR ZS 2 100MV A 10 LTC ZT 5 12MVA 69 kV 12 20MVA 12 47 kV 3 1200 5MR 800 5T 10...

Page 460: ...d CTs for three phase fault R R I 3 V R L F3 B3 Note that the wye connection produces a lower burden on the CTs see Setting Note 2 Where Neglecting RR use RL from Table D 1 HIGH LOW V 4 22 7 0 32 VB3...

Page 461: ...lead burden Step 4 Determine the effective CT accuracy class VCE Ratio Maximum use in Turns CT of Number Accuracy Base VCE N N V A C HIGH LOW 200 120 60 400 VCE 3 533 240 160 800 VCE Step 5 Determine...

Page 462: ...KV Base the tap adjust factor calculation can completely cancel this source of mismatch However if the no load taps in the protected transformer could be changed without the BE1 CDS220 tap adjust fact...

Page 463: ...ecommended for typical installations where no unmonitored load needs to be considered This value is well above the magnetizing current and provides a safe margin at the knee point of the slope charact...

Page 464: ...es the rating of the transformer Due to the operating characteristics of the BE1 CDS220 unrestrained differential element a setting of six times the self cooled rating provides security for inrush We...

Page 465: ...n a setting of URO 4 times tap for this example Step 4 Convert pickup setting to primary amperes As a reality check convert the unrestrained pickup sensitivity to high side and low side primary ampere...

Page 466: ...et the slope characteristic from the origin in the operate direction on the operate versus restraint characteristic see Figure D 2 Unmonitored loads Iunmon such as station service or small capacitor b...

Page 467: ...e point intersection of the minimum pickup tripping characteristic and the slope tripping characteristic unmon offset I IE I 24 0 0 24 0 offset I Where IE is assumed to be less than 4 of the self cool...

Page 468: ...hese settings When second harmonic sharing is enabled restraint for the A phase differential element is determined by Setting Restraint 2nd 100 1 2 2 2 st op nd op nd op nd op IA IC IB IA The B phase...

Page 469: ...degree of transient DC offset good design practice requires that the ratio error remain below 10 during the initial transient offset period if possible particularly when fast tripping is in effect It...

Page 470: ...d by the accuracy class definition The Rsx100 term represents the voltage drop across the CT internal resistance A new SF which takes the internal CT resistance into account can be defined on the exci...

Page 471: ...cal axis 0 to 4 shows that for ZB values equal to or greater than the burden value Zc the two saturation factor equations are nearly identical The ANSI Accuracy Class method yields the larger more con...

Page 472: ...timistic results in cases where the CT internal resistance is significant The Excitation Curve method requiring more data yields more accurate results and should be used when the SF is marginal SETTIN...

Page 473: ...IA RW 2RL 2RR IB IC RL RR Since IA IB IC VS IA RW 3RL 3RR VT VS RW IA VT 3IA RL RR Where IA 3 Phase fault current RR Relay burden RL Lead burden RW Winding burden SETTING NOTE 3 PHASE TO PHASE FAULT...

Page 474: ...ION FACTOR SF 0 5 In this case the maximum slope is set to 60 percent S 60 This occurs when poor CTs are used This situation should be avoided if possible since no accurate calculations can be made to...

Page 475: ......

Page 476: ...ROUTE 143 BOX 269 HIGHLAND IL 62249 USA http www basler com info basler com PHONE 1 618 654 2341 FAX 1 618 654 2351 lBasler Electric lBasler Electric...

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