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Basler BE1-CDS240, Instruction Manual

The Basler BE1-CDS240 Instruction Manual is available for free download on our website. This comprehensive manual provides users with detailed instructions and information on operating and troubleshooting the Basler BE1-CDS240 product. Easily access the manual at 88.208.23.73:8080 and optimize your experience with this versatile product.

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9365200990 Rev F 

BE1-CDS240 Reporting and Alarm Functions 

6-11 

Setting the Load Profile Recording Function 

For the load profile recording function to log data, you must set the demand logging interval. This can be 
done from the ASCII command interface using the SG-LOG (setting general, logging interval). Table 6-6 
lists the settings for the optional load profile recording. 

 

Table 6-6. Load Profile Recording Settings 

Function 

Range 

Increment 

Unit of Measure 

Default 

Demand Log Interval 

1 – 60 

1 

Minutes 

15 

 

Retrieving the Load Profile Recording Function 

Load profile recorded data is reported by the ASCII command interface using the RD-LOG command. 
You may request the entire log or only a specific number of entries. 

DIFFERENTIAL CURRENT MONITORING FUNCTION 

Differential current monitoring is a diagnostic function designed to aid in the installation and 
commissioning of transformer banks. This function attempts to identify and prevent false trips due to 
incorrect polarity, incorrect angle compensation, or mismatch.  

During transformer commissioning, it would be particularly useful to analyze the system installation and 
create a record of the settings and measured currents. The differential current monitoring function can 
create a differential check record like the sample shown in the following paragraphs. These records are 
also useful when comparing the present system characteristics to the characteristics at commissioning. A 
differential record is generated automatically when the ASCII interface command RA-DIFF=TRIG (report 
alarm-differential, trigger) is issued or when a differential alarm is set. When no alarms are active, you 
must 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 are no problems in the installation or settings. The first part of the record is the date and time 
the record was captured and the basic relay identification.  

The second part is a record of the CT connections and 87 (differential) settings. These settings may be 
entered using the S<g>-87 command. Refer to Section 3, 

Input and Output Functions,

 and Section 4, 

Protection and Control, Differential Protection,

 for more information on entering settings that develop both 

the second and third parts of the record. Also, refer to Section 3, 

Input and Output Functions,

 for 

information on the CT polarity convention used in both the fourth and fifth parts of the record. 

The third part is a record of the compensation factors. It is important to note that the angle compensation 
cannot be entered manually. The angle compensation is calculated by the relay based on the CT and 
transformer connections. (See Section 3

, Input and Output Functions, Power system Inputs, Power 

Measurement, Setting Up the Power System Measurement Functions,

 for more information on 

automatically determining compensation.) Additionally, the tap compensation setting may be entered 
manually or automatically calculated. (See Section 4, 

Protection and Control, Differential Protection,

 for 

more information on auto-tap compensation.) 

The fourth part of the record attempts to identify polarity and angle compensation errors by looking at the 
phase angle differences of compared phases. The differential alarm is set whenever the minimum pickup 
or the slope ratio exceeds the differential alarm, percent of trip setting. If the differential alarm is set and 
neither the polarity alarm nor angle compensation alarm is set, a mismatch error is identified indicating 
that the most likely cause of the alarm is incorrect tap settings. The differential check record needs a 
specific amount of secondary current to properly measure phase angles. In 5-ampere relays, that amount 
of current is 150 milliamperes. In one-ampere relays, it is 30 milliamperes. If there is not enough current 
present to run the algorithm, the message 

I < 150 ma

 (or 30 ma) appears in the appropriate alarm 

column. Since all phase angles are referenced to A1, no current applied to A1 will cause the 

I < 150 

ma

 (or 30 ma) message to appear for all phases. 

The fifth part (MEASUREMENTS) displays the measured and calculated currents at the time of the 
differential record trigger. The relay measures secondary current and develops the tap compensated 
currents for use by the differential element. Primary current (

MEASURED I PRI

) is calculated simply as 

the secondary current multiplied by the CT turns ratio. Secondary current (

MEASURED I SEC

) is the 

current actually measured by the relay. Angle compensated current (

ANGLE COMPENSATED I

) is the 

Summary of Contents for BE1-CDS240

Page 1: ...INSTRUCTION MANUAL FOR CURRENT DIFFERENTIAL SYSTEM BE1 CDS240 Publication 9365200990 Revision F 12 08 ...

Page 2: ......

Page 3: ...f the front panel HMI and the ASCII command interface with write access security procedures A summary of setting metering reporting control and miscellaneous commands Testing and maintenance procedures Appendices contain time overcurrent characteristic curves overexcitation 24 inverse time curves terminal communication and settings calculations assistance Optional instruction manuals for the BE1 C...

Page 4: ...rest of Basler Electric It is not the intention of this manual to cover all details and variations in equipment nor does this manual provide data for every possible contingency regarding installation or operation The availability and design of all features and options are subject to modification without notice Should further information be required contact Basler Electric BASLER ELECTRIC ROUTE 143...

Page 5: ...4 00 12 08 DSP 1 03 02 12 08 Added Power Flow Polarity setting for VTP Setup App 1 03 02 03 08 DSP 1 03 01 11 06 Added alternate DST Daylight Saving Time settings Increased immunity to noise on IRIG input Improved breaker fail targeting Improved x62 timer when changing setting groups App 1 03 00 09 06 DSP 1 03 01 11 06 Added 59X auxiliary element Added 180 compensation parameter for the 87T functi...

Page 6: ...sion and Date Change F 12 08 Added information to support Power Supply Option 3 24 Vdc Added Power Flow Polarity setting for VTP Setup in Section 3 Updated Contact Sensing Input ranges and burden data for re designed contact sense circuit E 03 08 Added manual part number and revision to footers Added Settings Compare to the end of Section 6 Added alternate DST Daylight Saving Time settings Updated...

Page 7: ... SECTION 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 SECTION 13 TESTING AND MAINTENANCE 13 1 SECTION 14 BESTCOMS SOFTWARE 14 1 APPENDIX A TIME OVERCURRENT CHARACTERISTIC CURVES A 1 APPENDIX B OVEREXCITATION 24 INVERSE TIME CURVES B 1 APPENDIX C TERMIN...

Page 8: ...vi BE1 CDS240 Introduction 9365200990 Rev F This page intentionally left blank ...

Page 9: ...Digital Measurement Errors 1 15 MODEL AND STYLE NUMBER DESCRIPTION 1 16 OPERATIONAL SPECIFICATIONS 1 17 Metered Current Values and Accuracy 1 17 Metered Voltage Values and Accuracy 1 17 Metered Frequency Values and Accuracy 1 17 Calculated Values and Accuracy 1 18 Energy Data Reporting 1 18 Real Time Clock 1 18 87 Differential Functions 1 18 87ND Neutral Differential Function 1 20 Instantaneous Ov...

Page 10: ...igure 1 2 Tap Adjust for Mismatch 1 9 Figure 1 3 Currents on Different Voltage Bases 1 9 Figure 1 4 Delta Wye Transformer Circuits 1 11 Figure 1 5 Three Phase Connections Delta Wye Configuration CT Compensation 1 12 Figure 1 6 Three Phase Connections Delta Wye Configuration Internal Phase Compensation 1 13 Figure 1 7 Traditional Zero Sequence Trap for Application with Ground Banks 1 14 Figure 1 8 ...

Page 11: ... others Protection scheme designers may select from an embedded pre programmed logic scheme or from a number of logic library schemes found in BESTCOMS to perform the most common protection and control requirements or create a custom scheme using BESTlogic The BE1 CDS240 is available in a fully draw out MX case with configurations for horizontal 19 rack mounting horizontal panel mounting and verti...

Page 12: ...current source can have its polarity reversed in the relay which simplifies the commissioning process in the event polarity of a CT circuit is rolled The digital sampling rate tracks the measured frequency to provide high accuracy at frequencies other than nominal frequency to make this relay ideally suited for applications such as generator motor and generator step up transformer differential pro...

Page 13: ...s Phase Five 5 sets Neutral Four 4 sets Negative Sequence Each function is individually assignable to any of the current input circuits Functions are 50TP 150TP 250TP 350TP 450TP 550TP 650TP 750TP 50TN 150TN 250TN 350TN 450TN 50TQ 150TQ 250TQ and 350TQ Inverse time overcurrent functions with integrating or instantaneous reset Four 4 for Phase five 5 for Neutral and four 4 for Negative Sequence Eac...

Page 14: ...e and neutral voltage and currents and all derived positive neutral and negative sequence voltage and currents Power factor frequency watts vars and demands are also provided Metering including magnitude and angle is also provided for the phase and tap compensated restraint second and fifth harmonic and differential currents Reporting and Alarm Functions Relay Identification The relay includes fou...

Page 15: ...y for loss of voltage fuse blown or loss of continuity trip coil open Each of the four TCMs can be disabled with a circuit board jumper allowing the associated output to operate the same as the other outputs Fault Reporting Fault reports consist of simple target information fault summary reports and detailed oscillography records to enable the user to retrieve information about disturbances in as ...

Page 16: ...ovides a second dimension of security For example you could set security to deny access to control commands from the rear RS 232 port that is connected through a modem to a telephone line Security settings only affect write access You have read access from any port to any area Human Machine Interface Each BE1 CDS240 comes with a front panel display with LED light emitting diode indicators for powe...

Page 17: ...with multiple overcurrent elements and is intended for use in any low impedance current differential protection application including transformer generator motor reactor and bus protection Its unique capabilities make it ideally suited for applications with the following requirements Applications that require low burden to extend the linear range of CTs Applications where dedicated CTs for the dif...

Page 18: ...ristic shown in Figure 1 1 is applied in this application The differential current required to cause a trip is a percentage of the restraint current The restraint current is a measure of the current flowing into or through the zone of protection Thus for higher levels of restraint current where the CTs may be subject to saturation higher levels of differential current must be seen to cause a trip ...

Page 19: ... differential tap settings The setup parameters for each of the current input circuits are described in Section 3 Input and Output Functions Power System Inputs The CT ratio is included to allow the currents to be metered displayed and reported in primary values The CT ratio is also used as a parameter for the automatic tap calculation feature D2837 18 12 14 98 600 5 400A 600 5 400A 600 5 400A CDS...

Page 20: ...ly based upon operating conditions Problem 4 Phase Angle Shift General When differential protection is used in a transformer application the transformer often introduces a phase shift between the various current inputs to the zone of protection An example is a transformer with a delta connected high side and a wye connected low side as shown in Figure 1 4 Illustration A The currents in the phases ...

Page 21: ... 1 4 Delta Wye Transformer Circuits BE1 CDS240 Solution The input currents must be combined to mimic the way they are combined in the protected power transformer so that the currents presented to the differential protection are made up of the same components Traditionally 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...

Page 22: ...three in the CT performance calculation The BE1 CDS240 relays support the traditional solution so that they may be used in retrofit modernization projects However in a numerical relay it is possible to connect all of the CTs in wye as shown in Figure 1 6 so that the drawbacks mentioned above are not a consideration The BE1 CDS240 relay can numerically combine currents internally to accomplish a nu...

Page 23: ... Configuration Internal Phase Compensation Problem 5 Zero Sequence Current Sources Within the Zone of Protection General A ground source grounded transformer winding or zigzag grounding bank within the zone of protection can result in differential current being measured during ground imbalances The most common example of this is when the zone of protection is around a delta grounded wye transforme...

Page 24: ...ferential protection and circulate in the CT delta just as they circulate in the delta of the power transformer on the delta side The BE1 CDS240 selects the proper phase shift compensation settings to not only provide the correct phase shift but also to block zero sequence currents as appropriate The second solution of inserting a zero sequence trap is used in applications where there is a groundi...

Page 25: ...components of the differential current If the differential current is made up of a significant proportion of either of these two components the user can select to inhibit the sensitive percentage restrained protection from operating Since CT saturation can also cause the currents seen by the relay to be rich in harmonics an unrestrained instantaneous differential element is included to provide dep...

Page 26: ...og low pass filters the BE1 CDS240 uses digital signal processing technology and 144 samples per cycle over sampling to provide digital low pass filtering MODEL AND STYLE NUMBER DESCRIPTION BE1 CDS240 electrical characteristics and operating features are defined by a combination of letters and numbers that make up the style number The model number together with the style number describe the option...

Page 27: ...nd Accuracy Voltage Range 3 Wire Sensing 0 to 300 VL L 4 Wire Sensing 0 to 300 VL L Accuracy 10 to 75 hertz 50 V to 300 V 0 5 of reading 1 least significant digit at 25 C Temperature Dependence 0 02 per C Metered Frequency Values and Accuracy Frequency Range 10 to 75 hertz Accuracy 0 01 hertz 1 least significant digit at 25 C Sensing Input 3 Wire Sensing Phase A B 4 Wire Sensing Phase A Neutral Mi...

Page 28: ...s 100 000 Accuracy 1 at unity power factor Real Time Clock Accuracy 1 second per day at 25 C free running or 2 milliseconds with IRIG synchronization Resolution 1 millisecond Date and Time Setting Provisions Front panel communications port and IRIG Leap year and selectable daylight saving time correction provided Clock Power Supply Holdup Capacitor 8 to 24 hours depending on conditions Backup Batt...

Page 29: ... 10 0 to 20 0 A 1 Ampere CT Range 0 40 to 4 00 A Increment 0 01 A Minimum Pickup 1 or 5 Ampere CT Range 0 10 to 1 00 per unit Increment 0 01 Restraint Slope 1 or 5 Ampere CT Range 15 to 60 Increment 1 Second and Fifth Harmonic 1 or 5 Ampere CT Range 5 0 to 75 0 Increment 0 5 Unrestrained Pickup 1 or 5 Ampere CT Range 1 to 21 times TAP up to 30 times I nominal symmetrical Increment 1 0 00 0 50 1 00...

Page 30: ...l 50TP 50TN 5 Ampere CT 2 or 50 mA 1 Ampere CT 2 or 10 mA Dropout pickup ratio 95 of pickup value Negative Sequence 50TQ 5 Ampere CT 3 or 75 mA 1 Ampere CT 3 or 15 mA Dropout pickup ratio 95 of pickup value Current Pickup Ranges 50T 5 Ampere CT Range 0 5 to 150 0 A Increment 0 01 from 0 50 to 9 99 A 0 1 from 10 0 to 99 9 A 1 0 from 100 to 150 A 1 Ampere CT Range 0 1 to 30 0 A Increment 0 01 from 0...

Page 31: ...r 50 mA 1 Ampere CT 2 or 10 mA Current Pickup Negative Sequence 51Q Dropout pickup ratio 95 of pickup value Pickup Accuracy 5 Ampere CT 3 or 75 mA 1 Ampere CT 3 or 15 mA Current Input All 51 Functions 5 Ampere CT Range 0 50 to 16 0 A Increment 0 01 from 0 50 to 9 99 A 0 1 from 10 0 to 16 0 A 1 Ampere CT Range 0 10 to 3 20 A Increment 0 01 A Time Current Characteristic Curves Timing Accuracy All 51...

Page 32: ... 127P Pickup Setting Range 10 to 300 V Setting Increment 0 1 from 0 to 99 V 1 0 from 100 to 150 V Accuracy 2 or 1 V Dropout Pickup Ratio 102 Time Delay Setting Range 0 050 to 600 s Increment 1 ms from 0 to 999 ms 0 1 s from 1 0 to 9 9 s 1 s from 10 to 600 s Accuracy 0 5 or 1 cycle whichever is greater Negative Sequence Voltage Protection 47 Pickup Setting Range 1 0 to 300 VL N Setting Increment 0 ...

Page 33: ... V whichever is greater Dropout Pickup Ratio 98 Time Delay Setting Range 0 050 to 600 s Increment 1 ms from 0 to 999 ms 0 1 s from 1 0 to 9 9 s 1 s from 10 to 60 s Accuracy 0 5 or 1 cycle whichever is greater Frequency 81 181 281 381 481 581 Pickup Setting Range 40 00 to 70 00 Hz Setting Increment 0 01 Hz Accuracy 0 01 Hz Time Delay Setting Range 0 000 to 600 s Increment 1 ms from 0 to 999 ms 0 1 ...

Page 34: ...y 0 5 or cycles whichever is greater VT Fuse Loss Monitoring 60FL Nominal Voltage 50 to 250 V Nominal Current 5 A Current Sensing 0 5 to 10 A 1 A Current Sensing 0 1 to 2 A Automatic Setting Group Characteristics Number of Setting Groups 4 Switch Level Range 0 to 150 of the setting group 0 51 Phase Neutral or Negative Sequence pickup setting Accuracy 5 A Current Sensing 2 or 50 mA 1 A Current Sens...

Page 35: ...Vdc or 90 to 270 Vac Burden 10 W continuous 13 W maximum with all outputs energized Frequency Range 40 to 70 Hz Option 3 24 Vdc Input Voltage Range 17 to 32 Vdc Burden 12 W continuous 16 5 W maximum with all outputs energized Output Contacts Make and Carry for Tripping Duty 7 A continuous 30 A for 0 2 seconds per ANSI C37 90 Break Resistive or Inductive 0 3 A at 125 or 250 Vdc L R 0 04 maximum Con...

Page 36: ... update rate delays must be included to calculate the worst case delay An example of feedback is virtual outputs driving function block inputs or other higher numbered virtual outputs or function block outputs driving function block inputs For more information see Section 7 BESTlogic Programmable Logic Communication Ports Interface Front RS 232 COM 0 300 to 19 200 baud 8N1 full duplex Rear RS 232 ...

Page 37: ... to 70 C 40 F to 158 F Humidity Qualified to IEC 68 2 38 1st Edition 1974 Basic Environmental Test Procedures Part 2 Test Z AD Composite Temperature Humidity Cyclic Test UL Recognition U L recognized per Standard 508 U L File Number E97033 Note Output contacts are not U L recognized for voltages greater than 250 V C S A Certification C S A certified per Standard CAN CSA C22 2 Number 14 M91 C S A F...

Page 38: ...1 28 BE1 CDS240 General Information 9365200990 Rev F This page intentionally left blank ...

Page 39: ...INTERFACES 2 3 Front Panel HMI 2 3 ASCII Command Communications 2 4 BESTCOMS for BE1 CDS240 Graphical User Interface 2 5 GETTING STARTED 2 6 Connections 2 6 Entering Test Settings 2 6 Checking the State of Inputs 2 7 Testing 2 7 FAQ TROUBLESHOOTING 2 7 Frequently Asked Questions FAQs 2 7 Figures Figure 2 1 87 Phase Differential Element 2 2 Figure 2 2 51 HMI Screen 2 4 Tables Table 2 1 Function Cat...

Page 40: ...ii BE1 CDS240 Quick Start 9365200990 Rev F This page intentionally left blank ...

Page 41: ...lay and include references to the following items Note that not all items are appropriate for each function Human machine interface HMI screens for setting the operational parameters BESTCOMS for setting the operational parameters BESTCOMS for setting up the BESTlogic required for functions in your protection and control scheme Outputs from the function such as alarm and BESTlogic variables or dat...

Page 42: ... the CDS240 BATX A BE the preprogrammed logic scheme might be CDS240 BATX B VP the B standing for revision level B and VP for VA Power There are two types of BESTlogic settings element function block logic settings and output logic settings These will be described briefly in the following paragraphs Detailed information on using BESTlogic to design complete protection and control schemes for the p...

Page 43: ...ual Output 1 to Virtual Output 11 which is the intermediate logic expression for all of the element tripping outputs or 101T the trip output of the virtual breaker control switch or BFPU the pickup output of the breaker failure element that indicates that breaker failure has been initiated To assign this to OUT1 the BESTlogic command would be SL OUT1 VO1 USER INTERFACES Three user interfaces are p...

Page 44: ...ASCII Command Communications The BE1 CDS240 relay has three independent communications ports for serial communications Basler Terminal in BESTCOMS can be connected 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 same manner Communication with the relay ...

Page 45: ...could have entered RB OPCNTR and received only the operations counter report Partial object names are also supported For example you wish to read the entire peak 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 demand registers enter the command RD...

Page 46: ...asures the A phase B phase and C phase current magnitudes directly from the three current sensing inputs on Circuit 1 this is dependent on style configuration Circuit 2 measures the A phase B phase and C phase current 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 curren...

Page 47: ...n press the Up scrolling pushbutton until you reach the top screen in the current branch You know when you have reached the top 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 CDS240 REPORT STATUS From this position press the Down scrolling pushbutton one ...

Page 48: ...ions No the BE1 CDS240 can compensate for zero sequence blocking See Section 3 Input and Output Functions for additional information 8 Does the BE1 CDS240 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 CDS240 does offer an option to ensure that the contact will stay closed for at least 200 millis...

Page 49: ... the 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 access and exit commands are executed for you 16 Why doesn t the trip LED behave as expected when the relay picks up and trips A closely related question would be why don t the targets work If the logic...

Page 50: ...Section 12 Installation for additional information 19 How can I find out the version number of my BE1 CDS240 The application version can be found in three different ways 1 Use the HMI Screen 4 6 2 Use the ASCII command interface with the RG VER command 3 Use BE1 CDS240 BESTCOMS the version is provided on the General Operation Screen Identification Tab 20 How are reports and other information obtai...

Page 51: ...tion 3 16 Setting the Digital Input Conditioning Function 3 16 Retrieving Input Status Information from the Relay 3 17 OUTPUTS 3 17 Hardware Outputs and Virtual Outputs 3 17 Retrieving Output Status 3 18 Relay Trouble Alarm Disable 3 18 Programmable Hold Timer 3 18 Output Logic Override Control 3 19 Enabling Logic Override Control 3 19 Pulsing an Output Contact 3 19 Holding an Output Contact Open ...

Page 52: ...CT Input Circuit Settings 1 for Delta Wye Circuit Applications 3 10 Table 3 4 CT Input Circuit Settings 2 for Delta Wye Circuit Applications 3 11 Table 3 5 CT Input Circuit Settings 3 for Delta Wye Circuit Applications 3 12 Table 3 6 Internal Compensation Chart 3 14 Table 3 7 Contact Sensing Turn On Voltage 3 15 Table 3 8 Digital Input Conditioning Function Settings 3 17 Table 3 9 Output Hold Func...

Page 53: ...SP digital signal processor using an FIR finite impulse response anti aliasing filter algorithm This high sampling rate allows the analog filter to have a high cutoff point which virtually eliminates errors from the analog filter elements The output from the digital filter is sample data reduced to 24 samples per cycle From the digitally filtered samples the relay extracts the magnitude and angle ...

Page 54: ...of whether the relay is in 3 wire or 4 wire mode The metering and protective functions utilize V2 not 3V2 Negative sequence measurements can accommodate either ABC or ACB phase sequence Positive Sequence V1 Voltage Positive sequence voltage is calculated from the fundamental component of the three phase voltage inputs It is only available on three phase three wire or three phase four wire systems ...

Page 55: ...os Equation 3 3 I V I V VARs C C CB A A AB 3 sin sin Equation 3 4 I V where x xy x For three wire VT connection with ACB phase sequence I V I V WATTs B B BC A A AC 3 cos cos Equation 3 5 I V I V VARs B B BC A A AC 3 sin sin Equation 3 6 I V where x xy x For AN BN or CN VT connection I V x 3 WATTs x x x 3 cos Equation 3 7 I V x 3 VARs x x x 3 sin Equation 3 8 I V and type sensing on based C or B A ...

Page 56: ... PP PN N a N a PP VTP Setup Winding 1 6 1 N a 1 VTP Setup Polarity Normal or Reverse N a N a Normal CT Ratio Inputs 1 4 1 50 000 1 Turns 1 CT Connection Inputs 1 4 WYE DAB DAC GND N a N a Wye CT Ratio Independent Ground Input 1 50 000 1 Turns 1 Trans Connection Inputs 1 4 WYE DAB DAC ZAB ZAC NA GND N a N a Wye Ground Source Inputs 1 4 0 No 1 Yes N a N a 0 Trans Rotation Comp Inputs 1 4 A B C N a N...

Page 57: ...ominal voltage must be set at 120 3 or 69 3 volts Inom can be either the secondary rating of the CT 1 or 5 amp or the secondary current allowed by the CT ratio In BESTCOMS for the BE1 CDS240 under General Operation Power System VT Setup are settings for Nominal Voltage and Current Settings can also be made from the ASCII command interface using the SG NOM command Nominal Voltage Vnom is the nomina...

Page 58: ...connected in wye or one of two delta configurations as shown in Figure 3 3 As described in Section 1 General Information Differential Protection Application Considerations wye CT connections are recommended for most applications The CT ratio should always be entered as the actual ratio and not the effective ratio When the CTs are connected in delta the secondary current under balanced conditions i...

Page 59: ...l Operation Screen Transformer Setup Tab Use the pull down menus and check boxes to setup transformer circuits Settings can also be made using the HMI Screen 6 3 1 3 SETUP PWR_S CONN TXC or from the ASCII command interface using the SG CKT command For each circuit you can set Connection Insert Zero Sequence Trap Differential Circuit and Circuit Polarity You can also set Transformer Phase Relations...

Page 60: ...s is the case with a delta delta transformer the definition of the delta configuration is not important B A C b a c D2837 21 02 17 04 IC Ic Ia IB Ib Ic IA Ia Ib B C A b c a D2837 22 03 25 03 IA Ia Ic IB Ib Ia IC Ic Ib Figure 3 5a DAB Delta Figure 3 5b DAC Delta Figure 3 5 DAB DAC Delta With the appropriate CT and transformer connection information the relay can automatically determine the correct ...

Page 61: ...ble should be used for inputs that are not part of the transformer s circuit Applying CT circuit 4 for auxiliary ground is one possible example The table also specifies the settings for a transformer case where all of the 3 phase windings and all of the 3 phase CTs are connected in wye Tables 3 3 and 3 4 are applied when a combination of delta and wye connections are present in the transformer and...

Page 62: ...Connection CT Input Connection TX CT Phase Rotation WYE WYE WYE WYE DAB for DAB connections DAC for DAC connections NONE WYE DAB WYE DAB WYE NONE WYE DAC WYE DAC WYE NONE DAB WYE DAB WYE WYE NONE DAC WYE DAC WYE WYE NONE ZAB WYE ZAB WYE WYE NONE ZAC WYE ZAC WYE WYE R2 3 10 BE1 CDS240 Input and Output Functions 9365200990 Rev F ...

Page 63: ...ion Applied Transformer Connection CT Input Connection TX CT Phase Rotation WYE WYE WYE WYE DAB NONE WYE DAB WYE DAB WYE NONE WYE DAC WYE DAC WYE R2 DAB WYE DAB WYE WYE NONE DAC WYE DAC WYE WYE R2 ZAB WYE ZAB WYE WYE NONE ZAC WYE ZAC WYE WYE R2 9365200990 Rev F BE1 CDS240 Input and Output Functions 3 11 ...

Page 64: ...Connection CT Input Connection TX CT Phase Rotation WYE WYE WYE WYE DDAB NONE WYE DAB WYE DAB DAB NONE WYE DAC WYE DAC DAB R2 DAB WYE DAB WYE DAB NONE DAB DAB DAB DAB WYE NONE DAB DAC DAB DAC WYE R2 DAC WYE DAC WYE DAB R2 DAC DAB DAC DAB WYE R2 DAC DAC DAC DAC WYE R1 3 12 BE1 CDS240 Input and Output Functions 9365200990 Rev F ...

Page 65: ... optional HMI the validation routine and auto tap calculation is performed on exit of each screen This may cause an Out of Range error message from the auto tap calculation function The user is advised to enter valid CT input circuit settings on Screen 6 3 1 1 SETUP PWR_S CON CTP prior to entering the auto tap calculation settings If the user has previously set the auto tap calculation settings an...

Page 66: ...s 3 4 3 5 and 3 6 and the ground source setting Table 3 6 Internal Compensation Chart Compensation Ground Source A Phase B Phase C Phase Wye none 0 No IA IB IC Wye none 1 Yes IA I0 IB I0 IC I0 DAB 0 No or 1 Yes IA IB 3 IB IC 3 IC IA 3 DAC 0 No or 1 Yes IA IC 3 IB IA 3 IC IB 3 DDAB 0 No or 1 Yes IA 2IB IC 3 IA IB 2IC 3 2IA IB IC 3 IB IA 3 IC IB 3 IA IC 3 IC IB IA IB IC IA IC IA 3 IB IC 3 IA IB 3 IA...

Page 67: ...ge ratings To further enhance flexibility the input circuits are designed to respond to voltages at the lower end of the control voltage range while not overheating at the high end of the control voltage range Energizing levels for the contact sensing inputs are jumper selectable for a minimum of approximately 5 Vdc for 24 Vdc nominal sensing voltages 26 Vdc for 48 Vdc nominal sensing voltages or ...

Page 68: ...itored contact is detected to be open for longer than the debounce time At this point the logic variable will change from a closed logic one or TRUE state to an open logic zero or FALSE state Setting the Digital Input Conditioning Function Settings and labels for the digital input conditioning function are set using BESTCOMS Alternately settings may be made using the SG IN ASCII command Each of th...

Page 69: ... used for 50 Hz Retrieving Input Status Information from the Relay The status of the inputs can be determined by using BESTCOMS Metering screen the optional HMI using Screen 1 4 1 STAT OPER INPUT and from the ASCII command interface using the RG STAT command See Section 6 Reporting and Alarm Functions General Status Reporting for more information OUTPUTS BE1 CDS240 relays have ten or fourteen gene...

Page 70: ... outputs and de energizes the OUTA relay closing the OUTA contact Programmable Hold Timer Historically trip contact seal in circuits have been provided in electromechanical relays These seal in circuits consisted of a dc coil in series with the relay trip contact and a seal in contact in parallel with the trip contact The seal in feature serves several purposes for the electromechanical relays One...

Page 71: ...tion for monitoring when the output logic has been overridden See Section 6 Reporting and Alarm Functions Alarms Function for more information on programmable alarms Write access to control functions is required to use the select before operate control functions from either the optional HMI or the ASCII command interface It cannot be achieved using BESTCOMS Enabling Logic Override Control The logi...

Page 72: ...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 the output contact Control can be accessed from the ASCII command interface using the CS CO OUTn L control select control operate output contact n logic control command The output control commands require the use of Select Before Operate logic First the command must b...

Page 73: ...can also display the status 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 Section 6 Reporting and Alarm Functions General Status Reporting for more information An L indicates that the state of the output is controlled by logic A zero or one indicate...

Page 74: ...3 22 BE1 CDS240 Input and Output Functions 9365200990 Rev F This page intentionally left blank ...

Page 75: ... Operating Settings for Time Overcurrent 4 29 Retrieving Time Overcurrent Status from the Relay 4 30 Voltage Restraint Control for Time Overcurrent Protection 4 30 Operating Settings for Voltage Restraint Control for Time Overcurrent 4 32 Programmable Curves 4 32 Setting Programmable Curves 4 33 46 Curve 4 33 Negative Sequence Overcurrent Protection 4 34 Pickup Settings for Negative Sequence Overc...

Page 76: ...ector Switches 4 69 Retrieving Virtual Selector Switches Status from the Relay 4 70 101 Virtual Breaker Control Switches 4 70 BESTlogic Settings for Virtual Breaker Control Switches 4 70 Select Before Operate Control of Virtual Breaker Control Switches 4 71 Retrieving Virtual Breaker Control Switch Status from the Relay 4 72 Figures Figure 4 1 Setting Group Control Logic Block 4 1 Figure 4 2 BESTl...

Page 77: ...reen 50BF 4 56 Figure 4 51 Breaker Failure Screen 50BF Tab 4 57 Figure 4 52 General Purpose Logic Timers Logic Block 4 59 Figure 4 53 Mode 1 PU DO Pickup Dropout Timer 4 59 Figure 4 54 Mode 2 One Shot Nonretriggerable Timer 4 60 Figure 4 55 Mode 3 One Shot Retriggerable Timer 4 60 Figure 4 56 Mode 4 Oscillator 4 60 Figure 4 57 Mode 5 Integrating Timer 4 61 Figure 4 58 Mode 6 Latch 4 61 Figure 4 59...

Page 78: ...ting Settings for Over Underfrequency 4 54 Table 4 30 BESTlogic Settings for Breaker Failure 4 57 Table 4 31 Operating Settings for Breaker Failure 4 58 Table 4 32 BESTlogic Settings for General Purpose Logic Timers 4 62 Table 4 33 Operating Settings for General Purpose Logic Timers 4 63 Table 4 34 60FL Logic Parameters 4 65 Table 4 35 60FL Element Blocking Settings 4 66 Table 4 36 BESTlogic Setti...

Page 79: ...0TQ to zero using the Overcurrent Screen in BESTCOMS More information on each individual function for item 1 is provided in this section More information on items 2 and 3 is provided in Section 7 BESTlogic Programmable Logic and Section 8 Application SETTING GROUPS BE1 CDS240 relays provide a normal setting group SG0 and up to three auxiliary setting groups SG1 SG2 and SG3 See Figure 4 1 Auxiliary...

Page 80: ...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 so that the relay will power up using the same setting group as it was using when it was powered down To prevent the relay from changing settings while a fault condition is in process setting group changes are blocked when the relay is in a pick...

Page 81: ...g 0 D3 Logic 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 settings to the setting group selection logic Refer to Figure 4 2 Mode Discrete Inputs D0 0 D1 0 D2 0 D3 IN2 AUTOMATIC IN2 Manual logic control reads the status of the logic inputs to the settin...

Page 82: ...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 signal applied to discrete inputs D0 and D1 This requires separate logic equations for only D0 and D1 if all setting groups are to be used Figure 4 4 shows how the active setting group follows the binary sum of the D0 and D1 inputs except when ...

Page 83: ...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 viewing of the BESTlogic settings for each preprogrammed logic scheme A custom logic scheme must be created and selected in the Logic pull down menu at the top of the screen before BESTlogic settings can be changed See Section 7 BESTlogic Programmable ...

Page 84: ...oup has a switch 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 monitored element can be any of the 51 protective functions Thus if you wish to switch settings based upon loading you could set it to monitor 51P If you wish to switch settings based upon...

Page 85: ... 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 the setting group change output pulses TRUE When the breaker is closed at time 40 minutes load current increases to approximately 90 percent of pickup As the load current decreases to 50 percent of pickup the Setting Group 1 return timer begins ti...

Page 86: ...etting group can be activated using the CO GROUP command Use the CO GROUP command to activate the setting group already selected The setting group activated with the CO GROUP command must match the setting group selected with the CS GROUP command If the setting group specified in each command doesn t match or the CO GROUP command isn t entered during the 30 second window the CO GROUP command is bl...

Page 87: ...relays provide three phase percentage restrained differential protection with high speed unrestrained instantaneous differential protection The differential protection includes harmonic restraint to improve security in transformer applications The 87 function see Figure 4 8 has nine outputs 87RPU restrained pickup 87RT restrained trip 87UT unrestrained trip 2NDHAR second harmonic A B C restraint p...

Page 88: ...etting is the ratio of operate current 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 sensitivity of the restrained element If the ratio of operate current to restraint current is above the slope setting and the operate current is above the minimum picku...

Page 89: ...m setting the 87RT 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 also set In many cases the second harmonic content of the inrush current may show up primarily in only one or two phases which can cause one or two phases to not be inhibited The BE1 CDS240 relay allows...

Page 90: ...of the BESTlogic Function Element screen is a pull down menu labeled Logic This menu allows viewing of the BESTlogic settings for each preprogrammed logic scheme A custom logic scheme must be created and selected in the Logic pull down menu at the top of the screen before BESTlogic settings can be changed See Section 7 BESTlogic Programmable Logic Enable the 87 function by selecting its mode of op...

Page 91: ... rating of the protected equipment KVn KV base for CT input n L L Voltage 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 1 in all other cases See Section 3 Input and Output Functions Table 4 6 Tap Compensation Settings for Phase Differential Rang...

Page 92: ...ttings on the TAP Screen the MVA and KV settings on the MVA Screen will be zeroed out If the user enters settings on the MVA Screen the automatically calculated taps are shown on both screens The auto tap calculation settings or the manual tap settings can be entered for each setting group with BESTCOMS or from the ASCII command interface using the S g TAP87 command NOTE to users of the BE1 87T Tr...

Page 93: ...ues Operating settings are made using BESTCOMS Figure 4 12 illustrates the BESTCOMS screen used to select operational settings for the 87 function To open the screen select Percentage Differential from the Screens pull down menu Then select the 87 Phase tab Alternately settings may be made using S g 87 ASCII command or through the optional HMI Screens 5 1 1 PROT SG 87 87 The operating settings for...

Page 94: ...nt of number x inputs x AxCOMPS I of Sum IRA 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 using the RG STAT command Status can also be determined using BESTCOMS Metering screen See Section 6 Reporting and Alarm Functions General Status Reporting for more ...

Page 95: ...traint current flowing thought CT Circuits 1 and 2 Using the relay s average restraint current mode offers some improvement by averaging the four CT inputs to determine the restraint current However is still below the typical 45 setting providing borderline 87R operation Using this mode Equation 4 6 applies IRESTRAINT 4 5 A IOPERATE 2 A SLOPE 4 44 100 I I RESTRAINT OPERATE Equation 4 6 Slope Calcu...

Page 96: ... slope 87R easily operates for the same fault condition that restrained in the original example Figure 4 13 By using virtual restraint the high current flowing thought CT Circuits 1 and 2 has no impact on the restraint calculations By using virtual restraint the restraint current is only proportional to current actually flowing through the protected transformer This avoids the need to apply a sepa...

Page 97: ...rovided by internal delta compensation If the CTs are connected in delta to provide external zero sequence compensation the calculated 3I0 neutral current exiting the zone will always be zero since it is filtered out by the CTs delta connection D2840 20 vsd 02 08 99 3IO 3Io Z0 IR IOP IR IO IO IO IO IO IO 3Io Figure 4 16 87ND Polarity Configuration These paragraphs discuss the details of how the fu...

Page 98: ...from the 87 phase differential function detects CT saturation the 87NDT trip logic output is routed through the timer The timer should be set longer than the normal clearing time for a fault just outside the zone of protection to allow it to ride through until the external fault is cleared If the target is enabled for this function the target reporting function will record an 87ND target when the ...

Page 99: ...wer System Inputs for more details on these settings The CT input with the highest CTR is selected as the driving tap and set to the minimum setting 2 0 for 5 ampere units or 0 4 for 1 ampere units Equation 4 8 is solved for the other tap The currents can be tap adjusted up to a spread ratio of 10 1 If the ratio between TAPN and TAPG is greater than 10 it will be necessary to adjust CT ratios to b...

Page 100: ...Milliseconds 0 05 to 60 sec 0 1 for 0 1 to 9 9 s 1 0 for 10 to 60 s Seconds Time Delay 0 to 3600 60 Hz or 0 to 2500 50 Hz Cycles 500 Time delays less than 10 cycles can be entered to the nearest 0 1 cycles from the optional HMI All time delays can be entered to the nearest 0 01 cycles from the ASCII command interface Time delays entered in cycles are converted to milliseconds or seconds Increment ...

Page 101: ...ection Each function block can be attached to any of the four hardware CT input circuits or the two virtual current circuits by the BESTlogic mode setting See Section 3 Inputs and Outputs for details on the virtual current circuits The instantaneous overcurrent protective functions in the BE1 CDS240 relay are labeled 50T because each has a settable time delay If the time delay is set to zero they ...

Page 102: ...eous Overcurrent BESTlogic settings are made from the BESTlogic Function Element screen in BESTCOMS Figure 4 21 illustrates the BESTCOMS screen used to select BESTlogic settings for the 50T elements To open the BESTlogic Function Element screen select Overcurrent from the Screens pull down menu Then select the 50T 150T 250T 350T 450T 550T or 650T 750T tab Open the BESTlogic Function Element screen...

Page 103: ...es a neutral overcurrent setting to be OUT OF RANGE the out of range setting will be forced in range by multiplying or dividing the current setting by five Operating Settings for Instantaneous Overcurrent Operating settings for the 50T functions consist of Pickup and Time delay values The Pickup value determines the level of current required for the element to start timing toward a trip Time delay...

Page 104: ...fore making any time delay settings changes Beside the Logic pull down menu is a pull down menu labeled Settings The Settings menu is used to select the setting group that the element s settings apply to Table 4 11 summarizes the operating settings for Instantaneous Overcurrent Table 4 11 Operating Settings for Instantaneous Overcurrent Range Setting 5 A 1 A Increment Unit of Measure Default Picku...

Page 105: ...tion is disabled by forcing the outputs to logic zero and resetting the timers to zero For example this could be used similar to a torque control contact on an electromechanical relay Each inverse time overcurrent function has a pickup a time dial and a curve setting See Appendix A Time Overcurrent Characteristic Curves for details on each of the curves available To make the protective element use...

Page 106: ...ion from the Mode pull down menu To connect the functions inputs select the button 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 series of variables to be connected to the input Select Save when finished to return to the BESTlogic Function Element scr...

Page 107: ...n the screen select Overcurrent from the Screens pull down menu and select either the 51 151 251 or 351 451 tab Alternately settings may be made using S g 51 ASCII command or from the optional HMI Screens 5 4 1 through 5 4 3 PROT SG 51 See Negative Sequence Overcurrent Protection later in this section for information on setting the negative sequence overcurrent protection The default unit of measu...

Page 108: ... Functions General Status Reporting for more information The status can also be determined using BESTCOMS Metering screen Voltage Restraint Control for Time Overcurrent Protection The 51P protection function can be set for voltage control or voltage restraint mode of operation 51V This feature is used to allow increased overcurrent sensitivity while providing security from operation due to load cu...

Page 109: ...sation The 51 27R function can be set to monitor either Vpp or Vpn depending upon the VTP connection settings See Section 3 Input and Output Functions Power System Inputs for more detail on how to set the VTP Connections Table 4 14 shows which voltage measurements are used by each phase overcurrent element for each possible VTP connection and 51 27 voltage monitoring mode setting Table 4 14 VTP Co...

Page 110: ...Restraint and Control Restraint I In Restraint mode the 51P pickup level is reduced linearly when the sensing voltage decreases below the restraint pickup level The 51P pickup level is determined by Equation 4 1 setting pickup 51P setting pickup restraint level voltage sensing Level Pickup Actual Equation 4 10 Restraint Pickup Level Control I In Control Mode pickup level is as selected by the 27R ...

Page 111: ...rve Coefficients button on the 51 tab in the Time Overcurrent screen Refer to Figure 4 25 The Curve Coefficients screen will appear see Figure 4 27 Enter the calculated values for each constant and select Done 9365200990 Rev F BE1 CDS240 Protection and Control 4 33 Programmable curve coefficients can be entered regardless of the curve chosen for the protection element However the programmable curv...

Page 112: ...f 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 magnitude of the current for a phase to phase fault is 3 2 87 of the three phase fault at the same location This is illustrated in Figure 4 28 The phase to phase fault is made up of both positive and negative sequence components as shown in Figure...

Page 113: ...e phase faults and 2 3 1 15 per unit fault current for phase to phase faults However for faults involving ground the sensitivity is reduced because the zero sequence components are trapped in the delta not seen by the delta side phase relays The phase relays will see only 1 3 0 577 per unit current for phase to ground faults Negative sequence overcurrent protection is immune to the effect caused b...

Page 114: ...e setting SG VTP The 24 function monitors VAB for both 3 wire and 4 wire connections Thus setting is in VPP Hz for VT connection 3W 4W AB BC CA and VPN Hz for VT connection AN BN CN For more information refer to Section 3 Input and Output Functions Nominal voltage for the BE1 CDS 240 is defined as a phase to neutral quantity Refer to Section 3 Input and Output Functions for details Nominal V Hz de...

Page 115: ...n towards reset at a linear rate based on the reset time dial setting See Appendix B Overexcitation 24 Inverse Time Curves for details on each of the available time curves If the target is enabled for the 24 element the target reporting function will record a target when the trip output is TRUE and the fault recording function trip logic expression is TRUE See Section 6 Reporting and Alarm Functio...

Page 116: ...he settings have been completely edited Table 4 19 lists the BESTlogic settings for Volts per Hertz Overexcitation Table 4 19 BESTlogic Settings for Volts per Hertz Overexcitation Function Range Purpose Default Mode 0 Disable 1 Enable 0 BLK Logic expression that disables the function when TRUE 0 Operating Settings for Volts per Hertz Overexcitation Operating settings for the 24 function consist of...

Page 117: ...6 Reporting and Alarm Functions for more information Settings for the alarm are made using BESTCOMS Figure 4 25 Alternately settings can be made with the SA 24 ASCII command Table 4 21 lists the programmable alarm settings for Volts per Hertz Overexcitation V Hz alarm settings cannot be set through the optional HMI Table 4 21 Programmable Alarm Settings for Volts per Hertz Overexcitation Setting R...

Page 118: ...m of 69 3 volts phase neutral 1 pu volts hertz 69 3 3 60 2 00 Using IEEE C37 102 Guide for AC Generator Protection as a guide for setting overexcitation protection the following example demonstrates how to set the BE1 CDS240 to provide a composite V Hz characteristic for protection of a generator and a step up transformer Alarm 105 1 second time delay V Hz 2 1 05 2 10 Inverse time pickup 105 Time ...

Page 119: ...he reset equation Equation 4 15 the calculation will be seconds 300 100 50 30 0 5 100 R T R R T FST E D T Equation 4 15 Time to Reset If the overexcitation condition returns prior to total reset i e less than 300 seconds timing resumes from that point at the inverse square rate For example if this condition recurs after 150 seconds or 50 of the total reset time then trip time from the second event...

Page 120: ...ogic Settings for Phase Undervoltage and Overvoltage in this section The phase undervoltage and overvoltage protective functions each include a timer and three independent comparators one for each phase The 27P 59P functions can be set to monitor VPP or VPN This is determined by the 27 59 mode parameter of the phase VT connections setting For more information on the VTP setup for PP or PN voltage ...

Page 121: ... details on the BESTlogic Expression Builder see Section 7 BESTlogic Programmable Logic Select Done when the settings have been completely edited Figure 4 38 BESTlogic Function Element Screen Phase 27P Table 4 22 summarizes the BESTlogic settings for Phase Undervoltage Overvoltage Table 4 22 BESTlogic settings for Phase Undervoltage Overvoltage Function Range Purpose Default 0 Disabled 1 Undervolt...

Page 122: ...elect the 27P 127P or 59 159P tab Alternately settings may be made using the S g 27P and S g 59P ASCII command or through the optional HMI using Screens 5 6 1 27P PROT SG 27 and 5 8 1 59P PROT SG 59 Figure 4 39 Voltage Protection Screen 27P 127P Tab Beside the Logic pull down menu is a pull down menu labeled Settings The Settings menu is used to select the setting group that the elements settings ...

Page 123: ...uld be entered and saved before making any time delay settings changes Example 1 Make the following operating settings to the 27P element Refer to Figure 4 39 Pickup 55 secondary volts Time 3 seconds Retrieving Phase Undervoltage Overvoltage Status from the Relay The status of each logic variable can be determined through the ASCII command interface using the RG STAT report general status command ...

Page 124: ...ge BESTlogic settings are made from the BESTlogic Function Element Screen in BESTCOMS Figure 4 41 illustrates the BESTCOMS screen used to select BESTlogic settings for the Overvoltage element To open the BESTlogic Function Element Screen for the Time Overvoltage element select Voltage Protection from the Screens pull down menu Then select the 59X tab Alternately settings may be made using SL 59X A...

Page 125: ...P or PN The time delay value determines the length of time between pickup and trip Time delays can be set in milliseconds seconds or cycles The default is milliseconds if no unit of measure is specified Operating settings are made using BESTCOMS Figure 4 42 illustrates the BESTCOMS screen used to select operational settings for the Auxiliary Overvoltage element To open the Voltage Protection scree...

Page 126: ... information The status can also be determined using BESTCOMS Metering screen 47 Negative Sequence Overvoltage Protection Figure 4 43 illustrates the inputs and outputs of the negative sequence overvoltage element Element operation is described in the following paragraphs Negative sequence overvoltage protection is not available if VTP connection is single phase D2881 29 08 12 04 Figure 4 43 Negat...

Page 127: ...e BESTCOMS screen used to select BESTlogic settings for the negative sequence overvoltage function To open the screen select Voltage Protection from the Screens pull down menu and then select the 47 Tab Then select the BESTlogic button at the bottom of the screen Alternately settings may be made using the SL 47 ASCII command Figure 4 44 BESTlogic Function Element Screen Negative Sequence 47 At the...

Page 128: ...lect Voltage Protection from the Screens pull down menu and then select the 47 tab Alternately settings maybe made using the S g 47 ASCII command or through the optional HMI interface using Screen 5 7 1 PROT SG 47 47 Figure 4 45 Voltage Protection Screen 47 Tab Beside the Logic pull down menu is a pull down menu labeled Settings The Settings menu is used to select the setting group that the elemen...

Page 129: ...d Alarm Functions General Status Reporting for more information The status can also be determined using BESTCOMS Metering screen FREQUENCY PROTECTION 81 Over Underfrequency Protection BE1 CDS240 frequency protection consists of six independent elements that can be programmed for underfrequency or overfrequency protection Each element has an adjustable frequency setpoint and time delay The 81 eleme...

Page 130: ...d out and the frequency remains in the pickup range for the remainder of the time delay the 81T will trip If the monitored voltage decreases below the user defined setpoint frequency protection is inhibited If the target is enabled for the element the target reporting function will record a target for the appropriate phase when the protective function trip output is TRUE and the fault recording fu...

Page 131: ...nsist of pickup values time delay values and a mode setting that defines whether an element provides under or over frequency protection and is selectable from a pull down menu under each element tab The pickup value determines the value of frequency required for the element to start timing toward a trip The time delay value determines the length of time between reaching the pickup value and trippi...

Page 132: ...or 0 1 to 99 9 1 0 for 100 to 150 Secondary Volts 40 0 Time delays less than 10 cycles can be entered to the nearest 0 1 cycles from the front panel HMI All time delays can be entered to the nearest 0 01 cycles from the ASCII 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...

Page 133: ...an also be stopped by the BLK Block logic input being asserted Upon sensing 50 INI transition from 0 to 1 state a Control Timer seals in the 50 INI signal for the duration of the Control Timer setting If the Control Timer expires and the 50 INI signal is still present a BFIALM Breaker Failure Initiate Alarm signal will occur The Control Timer serves the purpose to improve security by presenting a ...

Page 134: ...down menu Then select the button labeled BESTlogic Alternately settings may be made using the SL 50BF ASCII command Figure 4 50 BESTlogic Function Element Screen 50BF 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 logic scheme A custom logic scheme must be created and selected in...

Page 135: ...t To open BESTlogic Function Element screen for the breaker failure element select Breaker Failure from the Screens pull down menu Alternately settings may be made using the S0 x50BF where x blank 1 2 or 3 ASCII command or through the optional HMI interface using Screens 5 11 1 through 5 11 4 PROT SG BF x50BF where x blank 1 2 or 3 Figure 4 51 Breaker Failure Screen 50BF Tab Beside the Logic pull ...

Page 136: ...the fr time delays can be entered to the nearest 0 01 cycles from the ASCII 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 E Pickup secondary amps Time ms Phase Fault Detector PU 3 00 Neutral Fault Detector PU 3 00 Control Timer 100 Delay Timer 100 R ined...

Page 137: ...tion trip logic expression is TRUE See Section 6 Reporting and Alarm Functions Fault Reporting for more details on the target reporting function Mode 1 PU DO Pickup Dropout Timer The output will change to logic TRUE if the INITIATE input expression is TRUE for the duration of PICKUP time delay setting T1 See Figure 4 53 If the initiate expression toggles to FALSE before time T1 the T1 timer is res...

Page 138: ... 23 03 Figure 4 54 Mode 2 One Shot Nonretriggerable Timer Mode 3 One Shot Retriggerable Timer This mode of operation is similar to the one shot nonretriggerable mode except that if a new FALSE to TRUE transition occurs on the INITIATE input expression the output is forced to logic FALSE and the timing sequence is restarted See Figure 4 55 Figure 4 55 Mode 3 One Shot Retriggerable Timer Mode 4 Osci...

Page 139: ...utput 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 output of the timer is toggled to FALSE D2843 12 10 23 03 Figure 4 57 Mode 5 Integrating Timer This type of timer is useful in applications where a monitored signal may be hovering at its threshold between on and off For example it is desired to...

Page 140: ... 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 Element screen 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 input Select Save when finished to return to the BESTlogic Function E...

Page 141: ...f 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 the mode and inputs of the element Beneath the Logic pull down menu is a pull down menu labeled Settings The Settings menu is used to select the setting group that the element s settings apply to See Section 7 BESTlogic Programmable Logic Logic Sch...

Page 142: ...using the RG STAT report general status or the RL report logic commands Status can also be determined using BESTCOMS Metering screen See Section 6 Reporting and Alarm Functions General Status Reporting for more information VOLTAGE TRANSFORMER FUSE LOSS DETECTION 60FL Fuse Loss Detection BE1 CDS240 relays have one 60FL element that can be used to detect fuse loss or loss of potential in a three pha...

Page 143: ...condition K A B C D G Detects when either one or two phases are lost L E F B G Detects when all three phases are lost M N Latches the 60FL output until the reset criteria are met Fuse Loss Detection Blocking Settings The 60FL logic bit is always enabled regardless of the SP 60FL setting User selectable block settings determine how certain not all current and voltage protective functions operate wh...

Page 144: ...ual voltage 3V0 measurements are blocked when the 60FL logic is TRUE 59X Mode 2 V Block Q All functions that use the negative sequence voltage V2 measurement are blocked when the 60FL logic is TRUE 47 PNQ Figure 4 63 Reporting and Alarms Screen VT Monitor Tab The directional tests are also supervised by the loss of potential function 60FL If the 60FL bit is TRUE then voltage sensing was loss or is...

Page 145: ...switch on the panel and wire the output to a contact sensing input on the relay or in series with the ground trip output of the relay Instead a virtual switch can be used to reduce costs with the added benefit of being able to operate the switch both locally through the HMI and remotely from a substation computer or through a modem connection to a remote operator s console The state of the switche...

Page 146: ...element select Virtual Switches from the Screens pull down menu Then select the BESTlogic button for the virtual switch to be edited Alternately settings may be made 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 settings for each preprogrammed logic sch...

Page 147: ...tor s can only be u logic mode o CS CO x43 Command Purpose Select and operate the virtual selector switches Synta CS CO x 43 Comments x no entry for 43 or 1 for 143 Action 0 pulse the switch to the opposite state for 200 milliseconds and then automatically return to starting state The virtual switch control commands require the use of select before operate logic First the command must be selected ...

Page 148: ...se spring return trip contact output 101T a momentary close spring return close contact output 101C When the virtual control switch is controlled to trip the 101T output pulses TRUE closed for 101SC output goes FALSE open When the virtual control and a slip contact output 101SC The slip contact output retains the status of the last control action That is it is FALSE open in the after trip state an...

Page 149: ...at the optional HMI through Screens 2 2 1 through 2 2 4 CTRL BKR BKR_x where x 1 for 101 2 for 1101 3 for 2101 or 4 for 3101 Control is also possible through the ASCII command interface by using the select before operate commands CS x101 control select virtual control switch and CO x101 control operate vi ual control switch Control is not p ediately without aving to execute an Exit Save settings c...

Page 150: ...ol Switch Status from the Rela ined through the ASCII rface by usi Metering The virtual breaker control switch state after trip or after close can be determ command inte ng the RG STAT reports general status command or on BESTCOMS screen See Section 6 Reporting and Alarm Functions General Status Reporting for more information HMI Screens 2 2 1 through 2 2 4 provide switch control and displays the ...

Page 151: ... 5 6 Power Factor 5 6 Apparent Power 5 6 True Power 5 6 Figures Figure 5 1 Metering Circuits 1 6 5 2 Figure 5 2 Metering Watts Vars VA Phase Phase Sequence Phase Neutral Ground 1 Frequency 5 2 Figure 5 3 Metering Alarms Targets Output Status Input Status 5 3 Figure 5 4 Metering Logic Bits Views 5 3 Tables Table 5 1 Auto Ranging Scales for Metered Values 5 1 Table 5 2 ASCII Command and HMI Metering...

Page 152: ...ii BE1 CDS240 Metering 9365200990 Rev F This page intentionally left blank ...

Page 153: ... Reporting and Alarm Functions Auto Ranging The BE1 CDS240 automatically scales metered values Table 5 1 illustrates the ranges for each value metered Table 5 1 Auto Ranging Scales for Metered Values Unit Display Ranges Metered Value Whole Units Kilo Units Mega Units Giga Units Current 0 A to 9 999 A 10 kA to 9 999 kA 10 MA N A Voltage 0 V to 9 999 V 10 kV to 9 999 kV N A N A Apparent Power N A 0 ...

Page 154: ...ering views can be selected from the View pull down menu These alternate views are shown in Figures 5 2 through 5 4 Figure 5 2 Metering Watts Vars VA Phase Phase Sequence Phase Neutral Ground 1 Frequency 5 2 BE1 CDS240 Metering 9365200990 Rev F ...

Page 155: ...Figure 5 3 Metering Alarms Targets Output Status Input Status Figure 5 4 Metering Logic Bits Views 9365200990 Rev F BE1 CDS240 Metering 5 3 ...

Page 156: ...phase M WATT3 METER POWER POWER Power Reactive M VAR METER POWER VARS Power Reactive A phase M VARA METER POWER VARS Power Reactive B phase M VARB METER POWER VARS Power Reactive C phase M VARC METER POWER VARS Power Reactive Three phase M VAR3 METER POWER POWER Power Apparent VA M S METER POWER POWER Power Factor M PF METER POWER POWER Frequency all values M FREQ METER FREQ Frequency Phase M FREQ...

Page 157: ...nts Comp B phase MD IB3COMP METER DIFF COMP IB Diff Currents Comp B phase MD IB4COMP METER DIFF COMP IB 5th Harmonics as a of Iop B phase MD IB5TH METER DIFF HARM Diff Currents Comp Iop C phase MD IC METER DIFF COMP IC Diff Currents Comp C phase MD IC1COMP METER DIFF COMP IC Diff Currents Comp C phase MD IC2COMP METER DIFF COMP IC 2nd Harmonics as a of Iop C phase MD IC2ND METER DIFF HARM Diff Cur...

Page 158: ...layed Frequency is sensed from A phase to Neutral for four wire sensing systems or from A phase to B phase for three wire sensing systems The frequency of auxiliary voltage VX is also measured Power Factor Three phase power factor is metered over a range of maximum lagging 0 00 to unity 1 00 to maximum leading 0 00 Apparent Power Metered apparent power is displayed over a range of 7 500 kilovolt a...

Page 159: ...ONS 6 15 Number of Through Faults Monitoring Function 6 15 Transformer Duty Monitoring 6 15 Transformer Alarms 6 16 VT MONITOR FUNCTIONS 6 17 Setting Fuse Loss Block Logic 6 17 BREAKER MONITORING 6 18 Breaker Status Reporting 6 18 Breaker Duty Monitoring 6 19 Breaker Alarms 6 24 TRIP CIRCUIT MONITOR 6 25 FAULT REPORTING 6 27 Fault Reporting Expressions and Settings 6 27 Targets 6 28 Fault Summary ...

Page 160: ...s Metering Screen 6 43 Figure 6 29 BESTlogic Function Element Screen Alarm Reset Logic 6 44 Figure 6 30 General Operation Screen Identification Tab 6 45 Figure 6 31 General Operation Screen General Info Tab 6 45 Figure 6 32 BESTCOMS Settings Compare Setup Dialog Box 6 46 Figure 6 33 BESTCOMS Settings Compare Dialog Box 6 46 Tables Table 6 1 Circuit Identification Settings 6 1 Table 6 2 Time and Da...

Page 161: ...e 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 settings may be made using the SG ID ASCII command Figure 6 1 General Operation Screen Identification Tab To change these delete the old label from the cell and type the new label Identification settings are summarized in Table 6 1 Table 6 1 Circuit Id...

Page 162: ...oss of IRIG signal The alarm 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 volts or higher to be recognized as a valid signal Maximum input signal level is 10 to 10 volts 20 volt range Input resistance is nonlinear and rated at 4 k at 3 5 volts Sett...

Page 163: ... can be adjusted only by using ASCII commands They cannot be set with BESTCOMS or through the HMI The following serial commands must be entered in the order shown and all parameters must be entered in order for the alternate DST settings to function properly Select Floating Date or Fixed Date Configuration SG DST 1 Floating Date or 2 Fixed Date Example SG DST 2 selects Fixed Date configuration If ...

Page 164: ... 3101 3101SC STATUS AFTER CLOSE 1 CO GROUP STATUS L ACTIVE LOGIC STATUS CDS240 BA87 A BE LOGIC VAR 0 31 STATUS 00000000 00000000 00000000 00000000 LOGIC VAR 32 63 STATUS 00000000 00000000 00000000 00000000 LOGIC VAR 64 95 STATUS 00000000 00000000 00000000 00000000 LOGIC VAR 96 127 STATUS 00000000 00000000 00000000 00001111 LOGIC VAR 128 159 STATUS 00000000 00000000 00000000 00000000 LOGIC VAR 160 ...

Page 165: ...e Logic for more information about BESTlogic Variables This information is not available from the HMI RL report logic also reports the BESTlogic logic variables Active Group The active group is indicated on this line HMI Screen 1 4 4 STAT OPER ACTIVEG also provides this information ASCII command RG GRPACTIVE can also be used to view active group status See Section 4 Protection and Control Setting ...

Page 166: ... 6 7 7 7 8 7 9 8 0 8 1 8 2 8 3 8 4 8 5 8 6 8 7 8 8 8 9 9 0 9 1 9 2 9 3 9 4 9 5 8 1 P U 1 8 1 P U 2 8 1 P U 3 8 1 P U 4 8 1 P U 5 8 1 P U 8 1 T 1 8 1 T 2 8 1 T 3 8 1 T 4 8 1 T 5 8 1 T 5 0 T Q P U 1 5 0 T Q P U 2 5 0 T Q P U 3 5 0 T Q P U 5 0 T Q T 1 5 0 T Q T 2 5 0 T Q T 3 5 0 T Q T 1 0 1 T 1 1 0 1 T 2 1 0 1 T 3 1 0 1 T 1 0 1 C 1 1 0 1 C 2 1 0 1 C 3 1 0 1 C 1 0 1 S C 1 1 0 1 S C 2 1 0 1 S C 3 1 0 1...

Page 167: ...and Reporting Function Thermal Demand Calculation Method The demand reporting function incorporates an algorithm to digitally simulate a thermal or exponential response Thermal demand values are computed by an exponential algorithm with the demand interval or response period defined as the time taken by the meter to reach 90 percent of the final value for a step change in the current being measure...

Page 168: ...reen used to select demand reporting settings To open the screen shown in Figure 6 3 select Reporting and Alarms from the Screens pull down menu Then select the I Demand tab Alternately setting may be made using the SG DI Read Program Demand Current settings and SG DC Read Set Demand Circuit ASCII commands or the HMI using Screen 6 4 1 SETUP DMD DETAILS Demand settings for include columns labeled ...

Page 169: ...eset 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 time stamps in the demand registers can also be read and reset or preset from the ASCII command interface using the RD report demands command Overload and Unbalance Alarms Function The programmable alarms function include...

Page 170: ...ion when the BE1 CDS240 is ordered The Load Profile 4000 Point Data Array option 2 or 3 as the third character from the right in the style chart uses a 4 000 point data array for data storage Refer to Section 1 General Information Model and Style Number Description for more information on optional selections At the specified programmed interval Load Profile takes the data from the demand calculati...

Page 171: ...on 4 Protection and Control Differential Protection for more information on entering settings that develop both the second and third parts of the record Also refer to Section 3 Input and Output Functions for information on the CT polarity convention used in both the fourth and fifth parts of the record The third part is a record of the compensation factors It is important to note that the angle co...

Page 172: ...fferential report will not be generated unless the slope ratio drops below the differential alarm setting then increases above the setting Alternatively a record can be generated using the RA DIFF TRIG ASCII command Example 1 is based on the connections of Figure 12 15 an autotransformer with tertiary load Current transformers are located in double breakers on the transformer H winding side a sing...

Page 173: ...lay programmable alarms The alarm point must be mapped to activate an alarm and or light an LED For more information on mapping the alarm functions see Alarms Function Major Minor and Logic Programmable Alarms later in this section The differential alarm is set as a percentage of the percentage restrained differential characteristic See Figure 6 5 for a graph showing the percentage restrained diff...

Page 174: ...NIMUM PICKUP 0 01 to 1 00 TIMES TAP 5 I IRESTR OP 100 15 TO 60 SA DIFF 67 OF THE PERCENTAGE RESTRAINED DIFFERENTIAL D2850 15 05 27 99 Figure 6 5 Differential Alarm Characteristics Figure 6 6 Percentage Differential Screen Diff Alarm Tab 6 14 BE1 CDS240 Reporting and Alarm Functions 9365200990 Rev F ...

Page 175: ...T selected by the transformer duty monitoring function ST DUTY is monitored In the accumulated I t Duty registers 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 t is calculated from the time the pickup expression is TRUE The user selects which of the...

Page 176: ...se values can also be read and set through the ASCII command interface using the RT DUTY report transformer duty command It should be noted that when reading and writing to these registers only the set of registers that is selected to be monitored by the mode setting accumulated I t or I2 t and the CT setting CT 1 6 is affected The other set of registers is ignored The transformer duty registers c...

Page 177: ...the settings for the transformer programmable alarms function Table 6 9 Transformer Programmable Alarms Settings Setting Range Purpose Default 0 Disabled 1 Transformer alarm function enabled and set for percent duty Mode 2 Transformer alarm function enabled and set for through faults 0 Alarm Limit in mode 1 0 to 100 Increment 1 Measured in of DMAX 0 Alarm Limit in mode 2 0 to 99999 Increment 1 Num...

Page 178: ...rting purposes It also counts the opening strokes of the breaker and records them in the breaker operations counter register Setting the Breaker Status Reporting Function Since the relay is completely programmable it is necessary to program which logic variable is to be monitored for breaker status This is done with BESTCOMS Figure 6 9 Alternately the ASCII command SB LOGIC setting breaker logic c...

Page 179: ... breaker operations counter register can be read from HMI Screen 4 3 1 REPRT BRPTS STATUS Pressing the Edit key allows the user to enter a number into the register to preset it to a value to match an existing mechanical cyclometer on the breaker mechanism Write access to the reports functional area must be gained to edit this value at the HMI The current value of the breaker operations counter can...

Page 180: ... 1 to 3 Using values for Imax load and Imax fault in primary amperes the relay multiplies by the CTR before doing calculations the value for maximum breaker duty Dmax is calculated from either of these two equations 1 N load max N load max max I Ops I D 1 N fault max N fault max max I Ops I D Both of the last two equations should yield the same value for Dmax When testing the relay by injecting cu...

Page 181: ...ecord pre trigger Post trigger recording Post trigger 1 4 to 5 cycles of pre trigger E F Fault currents recorded G RedTRIPLED flashing W hen SG TRIGGER PU isTRUE H RedTRIPLED solid Breaker interruption duty T ransformer fault duty Setting group change blocked I J K D2843 42 09 29 03 SB LOGICsetting T rip W hen SG TRIGGER PUor Logic goes F ALSE W hen SG TRIGGER PUor Logic isTRUE W hen SG TRIGGER PU...

Page 182: ...ickup to perform distance calculations If the SG_TRIGGER TRIP expression does not become TRUE the fault was cleared by a down stream device For these pickup only events fault current voltage angle and distance recorded in the fault summary report will be for the power system cycle ending two cycles prior to the end of the fault record This is also the case if the fault record was triggered through...

Page 183: ...creen 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 BESTlogic Function Element screen For more details on the BESTlogic Expression Builder See Section 7 BESTlogic Programmable Logic Select Done when the settings have been completely edited Figure 6 12 BESTlogic Functi...

Page 184: ...re Breaker Clearing Time Monitoring The breaker clearing time monitoring function monitors the time from when a trip output occurs as defined by the TRIP logic expression to when the fast dropout current detector detects that current is zero in all three poles of the breaker see Locator D for Figure 6 10 The monitored breaker is determined by the CT circuit parameters set in the SB DUTY function T...

Page 185: ...age and continuity If a breaker is closed or the 86 Lockout relay is reset and no voltage is detected across the trip contacts then either the fuse supplying the circuit is blown or there is a loss of continuity in the trip coil circuit The trip circuit monitor function obtains the breaker status from a programmable setting which is set using the Trip Coil Enable parameter in the SB LOGIC command ...

Page 186: ...breaker trip coil may not perform as desired when the trip coil monitor is active The connection of other devices in parallel with the trip coil causes a voltage divider to occur when the breaker or trip circuit is open Figure 6 16 shows a schematic representation of the equivalent circuit This may cause false tripping of the other devices and prevent the BE1 CDS240 trip circuit monitor from relia...

Page 187: ...r an event and to record fault current magnitudes at the time of trip The trip expression is used to illuminate the Trip LED on the HMI The Trip LED will turn on and remain on as long as the trip expression is true The Trip LED will remain on or sealed in after the trip expression becomes false if targets are associated with the trip The breaker monitoring function uses the trip expression to star...

Page 188: ... Function Purpose Default Logic expression used to define Trip fault reporting condition When this expression becomes TRUE 1 it triggers data recording and illuminates the Trip LED BFT1 BFT2 BFT3 BFT4 VO11 TRIPPED Logic expression used to define Pickup fault reporting condition When this expression becomes TRUE 1 it initiates the pickup timing sequence and the Trip LED will flash on and off BFRT1 ...

Page 189: ...ve Sequence Overvoltage Enabled 59P 159P Phase Overvoltage Enabled 59X Auxiliary Overvoltage Enabled 81 181 281 381 481 581 Under Over Frequency Enabled 62 162 262 362 General Purpose Logic Timer Enabled 60FL Fuse Loss Detection Enabled Target logging for a protective function can be disabled if the function is used in a supervisory or monitoring capacity The following paragraphs describe how the ...

Page 190: ...ULT PREV Targets for previous events are recorded in the fault summary reports which are described in detail later in this section When the relay trips and targets are logged for the event the Trip LED is sealed in on the front of the relay and menu tree branch Screen 1 1 1 STAT TARGETS is automatically displayed on the LCD See Section 4 Human Machine Interface for more information about the autom...

Page 191: ...tal 3V0 3rd harmonic Auxiliary Overvoltage 60FL Fuse Loss 62 162 262 362 Logic Timers 81 181 281 381 481 581 Frequency 87R ABC Phase Differential Restrained 87U Phase Differential Unrestrained 87ND 187ND Neutral Differential Restrained The RG TARG report general targets command can be used to read and reset the targets Write access to Reports must be gained to reset the targets using the ASCII com...

Page 192: ...highlighted The Trigger button ASCII command The Refresh button is used to refresh the list of faults The Download button will download the sel fault storing it on the selected driv Fault Summary Report Example A fault summary report collects several items of information about a fault that can aid in determining why a fault occurred without having to sort through all of the detailed information av...

Page 193: ...he initial trigger of the event This is based on either the pickup logic expression or the logic trigger expression becoming TRUE as defined by the 2 ID These lines report station and device identifier information mber is assigned using the SG COM command described in Section 11 ASCII ber This line reports the sequential number from 1 to 255 assigned to the report by the BE1 Eve T fault was detect...

Page 194: ...the fault is cleared prior to the relay tripping the recorded fault currents are for the power system cycle two cycles prior to the end of the fault Refer to Figure 6 10 and Table 6 11 call out F VAN VBN VCN V1 V2 3V0 These lines report the voltage magnitudes and angles measured two power system cycles immediately following the trip trigger If the fault is cleared prior to the relay tripping the r...

Page 195: ...ond record begins after five cycles there will be a gap some data not recorded between the records Refer to Figure 6 10 Legend E In that illustration the number of records was set to 32 which equates to 15 cycles recorded The first record is triggered and has 3 cycles of pre trigger data and 12 cycles of post trigger data The fault takes longer than 12 cycles to clear so a second record is necessa...

Page 196: ...Figure 6 24 Fault Record Filenames Only one oscillographic report file can be requested at a time Reports are transmitted in COMTRADE format A configuration file CFG a data file DAT or a header report HDR can be requested Header files contain the fault summary report followed by all the pertinent settings that are associated with the requested fault record These settings include the following BEST...

Page 197: ...the event the event or variable name and the state that the variable changed to For user programmable logic variables contact sensing inputs virtual switches and virtual outputs the user programmed variable name and state names are logged in the SER report instead of the generic variable name and state names For more information refer to Section 7 BESTlogic Programmable Logic User Input and Output...

Page 198: ...and reports all input and output events since the last RS 0 command was issued RS 0 resets the new records counter to zero 5 RS LGC report SER logic A report is retrieved for all logic events since the last RS 0 command was issued RS 0 resets the new records counter to zero 6 RS NEW report SER new events since RS 0 reset Events are retrieved for the period of time covered by the New Events Counter...

Page 199: ...ouble RA REL alarm is cleared by pressing the HMI Reset key while viewing Screen 1 3 or using the RA 0 or RA REL 0 commands then the relay will attempt to return back online by issuing a software reset The relay resets by going through a full startup and initialization cycle If no problems are detected the relay returns online and enables protection Major Minor and Logic Programmable Alarms The pr...

Page 200: ...l communication operation 25 COMM ERROR ALARM Communication failure 26 CLOCK ERROR ALARM Real time clock not set 27 uP RESET ALARM Microprocessor has been reset 28 SETTING CHANGE ALARM Setting change made by user 29 EE NON FATAL ERR ALARM EEPROM nonfatal recoverable error 30 OUTPUT OVERRIDE ALARM One or more output contacts have logic override condition 31 IRIG SYNC LOST ALARM Loss of IRIG synchro...

Page 201: ...d 65 VN MAX DEMAND ALARM Max Neutral Voltage Demand threshold exceeded 66 VN MIN DEMAND ALARM Min Neutral Voltage Demand threshold exceeded 67 VOLTS PER HERTZ ALARM Volts per Hertz Alarm threshold exceeded 68 27 UNDER VOLTAGE ALARM Phase Undervoltage Alarm threshold exceeded 69 59 OVER VOLTAGE ALARM Phase Overvoltage Alarm threshold exceeded 70 60 FUSE LOSS ALARM One or more phases of voltage lost...

Page 202: ...iority logic The HMI display scrolls between displaying all active alarm points This includes alarms that are not programmable relay trouble alarms Any latched alarms that are not currently active can be reset by pressing the HMI Reset key See Figure 6 27 for logic Logic variables for ALMMAJ ALMMIN and ALMLGC can also be set to operate any of the output contacts to give an indication that an alarm...

Page 203: ...ts Figure 6 27 shows the alarm reset logic After an operation alarms information can be viewed using BESTCOMS Select Metering from the Reports pull down menu From the View pull down menu select Alarms Status Figure 6 28 Figure 6 28 Alarms Status Metering Screen The RA report alarms command can be used to read detailed alarm reports and reset latched alarms Links between Programmable Alarms and BES...

Page 204: ...bles could be used to actuate an output relay to signal a SCADA RTU that an alarm condition exists HARDWARE AND SOFTWARE VERSION REPORTING Hardware and software version reporting is used to determine what style chart selections are included in the relay the relay serial number and the version of the embedded software firmware Model style number serial number information is contained on the label o...

Page 205: ...Figure 6 30 General Operation Screen Identification Tab Figure 6 31 General Operation Screen General Info Tab 9365200990 Rev F BE1 CDS240 Reporting and Alarm Functions 6 45 ...

Page 206: ...sk click on the folder box and browse for the file If you wish to Download settings from unit to compare click on the RS 232 box to setup the Com Port and Baud Rate Click on the Compare box to compare the settings files that you have selected Figure 6 32 BESTCOMS Settings Compare Setup Dialog Box If there are any differences in the two files a dialog box will pop up notifying you that Differences ...

Page 207: ... 12 Sending and Retrieving Relay Settings 7 12 Debugging the Logic Scheme 7 12 USER INPUT AND OUTPUT LOGIC VARIABLE NAMES 7 13 BESTLOGIC APPLICATION TIPS 7 13 Figures Figure 7 1 BESTlogic Function Blocks page 1 of 5 7 2 Figure 7 2 BESTlogic Function Blocks page 2 of 5 7 3 Figure 7 3 BESTlogic Function Blocks page 3 of 5 7 4 Figure 7 4 BESTlogic Function Blocks page 4 of 5 7 5 Figure 7 5 BESTlogic ...

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Page 209: ...tual outputs 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 memory and several others are available in the logic library of BESTCOMS Basler Electric s Windows based graphical user interface program Each scheme is configured for a typical protection applic...

Page 210: ...Figure 7 1 BESTlogic Function Blocks page 1 of 5 7 2 BE1 CDS240 BESTlogic Programmable Logic 9365200990 Rev F ...

Page 211: ...Figure 7 2 BESTlogic Function Blocks page 2 of 5 9365200990 Rev F BE1 CDS240 BESTlogic Programmable Logic 7 3 ...

Page 212: ...Figure 7 3 BESTlogic Function Blocks page 3 of 5 7 4 BE1 CDS240 BESTlogic Programmable Logic 9365200990 Rev F ...

Page 213: ...Figure 7 4 BESTlogic Function Blocks page 4 of 5 9365200990 Rev F BE1 CDS240 BESTlogic Programmable Logic 7 5 ...

Page 214: ...Figure 7 5 BESTlogic Function Blocks page 5 of 5 7 6 BE1 CDS240 BESTlogic Programmable Logic 9365200990 Rev F ...

Page 215: ...101C 2101 Closed 51NT 51Neutral Tripped 2101SC 2101 Slip Contact 51NPU 51 Neutral Picked Up 3101T 3101 Tripped 51QT 51 Negative Sequence Tripped 3101C 3101 Closed 51QPU 51 Negative Sequence Picked Up 3101SC 3101 Slip Contact 151PT 151 Phase Tripped Timers 151PPU 151 Phase Picked Up 62 62 Output 151NT 151 Neutral Tripped 162 162 Output 151NPU 151 Neutral Picked Up 262 262 Output 151QT 151 Negative ...

Page 216: ... Tripped Percentage Differential 250TNPU 250T Neutral Picked Up 87RT 87 Phase Restraint Tripped 250TQT 250T Negative Sequence Tripped 87RPU 87 Phase Restraint Picked Up 250TQPU 250T Negative Sequence Picked Up 87UT 87 Phase Unrestraint Tripped 350TPT 350T Phase Tripped 87NDT 87 Neutral Tripped 350TPPU 350T Phase Picked Up 87NDPU 87 Neutral Picked Up 350TNT 350T Neutral Tripped 187NDT 187 Neutral T...

Page 217: ...ower These variables include 43 143 243 343 443 543 643 743 101SC 1101SC 2101SC 3101SC and SG0 through SG3 All control commands including logic override control are also stored in EEPROM If you override output logic and force an output to open that condition will be maintained even if operating power is cycled When the logic is running and logic expression SL VO n is FALSE then output VO n 0 When ...

Page 218: ...uilder was first opened The Cancel button resets the expression to its original state when the BESTlogic Expression Builder was first opened and returns the user to the previous screen The Save button saves the expression shown in the text window and returns the user to the previous window LOGIC SCHEMES A logic scheme is a group of logic variables written in equation form that defines the operatio...

Page 219: ...difying the settings Naming the new logic distinguishes it from the preprogrammed logic scheme In the 16 character preprogrammed logic name the last 4 characters refer to revision A dash and BE Basler Electric When customizing a programmed logic scheme it is recommended that the user include the revision level of their scheme and change the BE to a 2 digit code representative of the user s company...

Page 220: ...d by selecting the desired logic scheme in BESTCOMS and then typing over the logic scheme s name Changes are not activated until the new settings have been uploaded to the device Creating or Customizing a Logic Scheme Before customizing a preprogrammed logic scheme the scheme must be renamed The following procedure outlines the process of customizing or creating a logic scheme Step 1 Copy the prep...

Page 221: ...energized OUT1 and 2 are form C and have 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 an output logic expression causes the coil to be energized with the contacts closed in the normal state Caution should be taken with normally closed contact logic because there are no sh...

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Page 223: ...3 Integration of Protection Control and I O Elements 8 13 Alarms 8 13 CDS240 TXCL B BE BASIC TRANSFORMER WITH CONTROL LOGIC SCHEME 8 16 Protection Elements 8 19 Integration of Protection Control and I O Elements 8 20 Alarms 8 20 CDS240 TXBU B BE TRANSFORMER DIFF WITH BACKUP LOGIC SCHEME 8 24 Protection Elements 8 27 Integration of Protection Control and I O Elements 8 28 Test Mode 8 28 Alarms 8 29...

Page 224: ...TX A BE Virtual Switch Logic 8 7 Table 8 5 CDS240 BATX A BE Virtual Output Logic 8 7 Table 8 6 CDS240 BATX A BE Hardware Output Logic 8 8 Table 8 7 CDS240 BA87 B BE Logic Settings and Equations 8 11 Table 8 8 CDS240 BA87 B BE Contact Input Logic 8 14 Table 8 9 CDS240 BA87 B BE Function Block Logic 8 14 Table 8 10 CDS240 BA87 B BE Virtual Switch Logic 8 15 Table 8 11 CDS240 BA87 B BE Virtual Output...

Page 225: ...9365200990 Rev F BE1 CDS240 Application iii Table 8 37 Miscellaneous Logic Expressions 8 52 Table 8 38 Output Contact Seal in Logic 8 56 Table 8 39 Logic Settings Associated with Figure 8 19 8 58 ...

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Page 227: ...nd control elements and settings In many cases this eliminates the need to create a custom logic scheme from scratch Please note that this preprogrammed logic scheme also illustrates typical ways of using or controlling various functions The user may choose to create a custom logic scheme by mixing preprogrammed logic with user defined logic The logic also can be modified to incorporate some of th...

Page 228: ...er the protection engineer cannot depend on the internal 51 time overcurrent element to backup the primary differential 87 protection element of the same relay A common mode failure such as the power supply could disable the entire relay and leave the transformer with no protection In addition the self testing feature of the product is designed to disable the relay outputs when a problem is detect...

Page 229: ... SL 150BF 0 0 0 0 0 SL 250BF 0 0 0 0 0 SL 350BF 0 0 0 0 0 SL 50TP 0 0 SL 50TN 0 0 SL 50TQ 0 0 SL 150TP 0 0 SL 150TN 0 0 SL 150TQ 0 0 SL 250TP 0 0 SL 250TN 0 0 SL 250TQ 0 0 SL 350TP 0 0 SL 350TN 0 0 SL 350TQ 0 0 SL 450TP 0 0 SL 450TN 0 0 SL 550TP 0 0 SL 650TP 0 0 SL 750TP 0 0 SL 51P 0 0 SL 51N G 0 SL 51Q 0 0 SL 151P 1 0 SL 151N 1 0 SL 151Q 1 0 SL 251P 2 0 SL 251N 2 0 SL 251Q 2 0 SL 351P 0 0 SL 351N...

Page 230: ...87 CT Input G Optional Out5 CT Input 1 CT Input 2 52 2 T r i p BE1 CDS240 D2843 33 02 26 03 CT Input 2 151P 151N 151Q 251P 251N 251Q Out1 Out3 Figure 8 1 Typical One line Diagram for CDS240 BATX A BE 8 4 BE1 CDS240 Application 9365200990 Rev F ...

Page 231: ...he 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 inside the differential zone At the same time it provides security against mis operations resulting from transformer inrush by restraining and preventing a trip in the presence of 2nd and 5th harmonics Typically the 1...

Page 232: ...ogic Alarm ALMLGC has no associated front panel LED When the relay self test detects a problem in the relay ALMREL as programmed for the CDS240 BATX A BE scheme the Relay Trouble LED lights output A operates and all outputs are disabled When a Major Alarm is detected ALMMAJ the associated LED lights and output 6 operates When a Minor Alarm ALMMIN is detected the associated LED lights but in this s...

Page 233: ...CT input circuit 2 0 2 Circuit 2 Input 0 Logic No manual selection logic is used 0 Input 1 Logic No manual selection logic is used 0 Input 2 Logic No manual selection logic is used 0 Input 3 Logic No manual selection logic is used 0 GROUP Auto Manual Logic Set to 1 0 to enable automatic selection No manual selection is used 0 1 Discrete Inputs Table 8 4 CDS240 BATX A BE Virtual Switch Logic State ...

Page 234: ... there is no unrestrained pickup output VO13 Optional Use to annunciate an alarm when alarm point 21 is enabled VO13 is TRUE when IN6 is TRUE IN6 ALARM ACTIVE NORMAL BESTlogic Expression VO13 IN6 VO14 Optional Use to annunciate an alarm when alarm point 22 is enabled VO14 is TRUE when IN7 is TRUE IN7 ALARM ACTIVE NORMAL BESTlogic Expression VO14 IN7 VO15 Optional Use to annunciate an alarm when al...

Page 235: ...ping 87RT for internal faults Therefore a high speed unrestrained instantaneous differential element 87UT is also required for transformer applications When the 87 protection element is applied to other than transformer protection set the pickup thresholds for the 2nd 5th and 87UT units to 0 setting disabled CDS240 BA87 B BE Basic Differential Logic Scheme This logic scheme CDS240 BA87 B BE provid...

Page 236: ...0 51P N and Q protection elements and outputs are automatically reconfigured to provide feeder protection The 150 151P N and Q protection elements of the BE1 CDS240 are time coordinated with the bus and feeder circuit protection providing overall backup protection from the transformer side of the bus main breaker through the first down line interrupting device on the distribution circuit CDS240 MO...

Page 237: ... SL 187ND 0 0 SL 50BF 0 0 0 0 0 SL 150BF 0 0 0 0 0 SL 250BF 0 0 0 0 0 SL 350BF 0 0 0 0 0 SL 50TP 0 0 SL 50TN 0 0 SL 50TQ 0 0 SL 150TP 0 0 SL 150TN 0 0 SL 150TQ 0 0 SL 250TP 0 0 SL 250TN 0 0 SL 250TQ 0 0 SL 350TP 0 0 SL 350TN 0 0 SL 350TQ 0 0 SL 450TP 0 0 SL 450TN 0 0 SL 550TP 0 0 SL 650TP 0 0 SL 750TP 0 0 SL 51P 1 0 SL 51N 1 0 SL 51Q 1 0 SL 151P 0 0 SL 151N 0 0 SL 151Q 0 0 SL 251P 0 0 SL 251N 0 0 ...

Page 238: ...Figure 8 3 Typical One line Diagram for CDS240 BA87 B BE 8 12 BE1 CDS240 Application 9365200990 Rev F ...

Page 239: ...quence timed backup protection for zones beyond the equipment being protected In the low impedance bus application the 51 protection element must coordinate with the feeder protection of the circuits connected to the bus Integration of Protection Control and I O Elements The logic settings in Table 8 3 also include the logic equations that connect the various elements of the basic differential sch...

Page 240: ...2 CLOSED OPEN IN3 Optional input Used for 86 status indication in SER reports TRUE when 86 is tripped 86 TRIPPED TRIPPED NORMAL IN6 IN8 Optional inputs Used for programmable alarms and SER reporting For example sudden pressure trip or transformer hot spot alarm etc Drives VO13 VO15 that are programmable alarm points 21 23 Label inputs as appropriate INPUT_6 INPUT_7 INPUT_8 CLOSED OPEN Table 8 9 CD...

Page 241: ...an alarm VO6 TRUE when any programmed major alarm condition is TRUE MAJOR ALARM ALARM NORMAL BESTlogic Expression VO6 ALMMAJ VO11 Protective Trip expression TRUE when any 87 or 51 element trips PROTECTIVE TRIP TRIP NORMAL BESTlogic Expression VO11 87RT 87UT 51PT 51NT 51QT VO12 Protection Picked Up expression TRUE when any 87 or 51 element picks up PROT PICKED UP PU NORMAL BESTlogic Expression VO12...

Page 242: ...c CDS240 TXCL B BE scheme was designed to provide a primary zone of differential relaying and three backup zones of time overcurrent relaying for phase and ground faults in two winding transformer applications This scheme also uses virtual control switch logic to eliminate the need for external control switches The control switch elements are referred to as virtual because they have no physical fo...

Page 243: ...P 0 0 SL 47 0 0 SL 59P 0 0 SL 59X 0 0 SL 159P 0 0 SL 81 0 0 SL 181 0 0 SL 281 0 0 SL 381 0 0 SL 481 0 0 SL 581 0 0 SL 62 0 0 0 SL 162 0 0 0 SL 262 0 0 0 SL 362 0 0 0 SL GROUP 1 0 0 0 0 343 SL 43 3 SL 143 3 SL 243 2 SL 343 2 SL 443 0 SL 543 0 SL 643 0 SL 743 0 SL 101 1 SL 1101 0 SL 2101 0 SL 3101 0 SL VOA 0 SL VO1 87RT 87UT 151PT 51NT 151NT 151QT SL VO2 87RT 87UT 151PT 51NT 151NT 151QT 43 SL VO3 IN...

Page 244: ...l Out4 CT Input 1 C u t o f f CT Input 2 52 2 101 C l o s e T r i p T C Auto Manual BE1 CDS240 D2843 35 02 26 03 CT Input 2 151P 151N 151Q 251P 251N 251Q Group Control 343 143 43 243 Figure 8 5 Typical One line Diagram for CDS240 TXCL B BE 8 18 BE1 CDS240 Application 9365200990 Rev F ...

Page 245: ...f a delta wye transformer The ground input G is an option on the BE1 CDS240 and 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 to provide a trip through the BE1 CDS240 outputs Protection elements set at 0 are setting disabled and will not provide a trip output even if logic enabled Typically the BE1 CDS24...

Page 246: ...he front panel LEDs Relay Trouble ALMREL Major Alarm ALMMAJ 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 CDS240 TXCL A BE scheme the Relay Trouble LED lights Output A operates and all outputs are disabled When a Major Alarm is detected ALMMAJ the associated LE...

Page 247: ...ent protection for CT input circuit 2 0 2 Circuit 2 251Q Used for timed negative sequence overcurrent protection for CT input circuit 2 0 2 Circuit 2 Input 0 Logic No manual selection logic is used 0 Input 1 Logic No manual selection logic is used 0 Input 2 Logic No manual selection logic is used 0 Input 3 Logic No manual selection logic is used 0 GROUP Auto Manual Logic Disable automatic selectio...

Page 248: ...unrestrained or any 251 time overcurrent trip occurs or 101T tripped is TRUE TRIP BKR2 TRIP NORMAL BESTlogic Expression VO4 87RT 87UT 101T 251PT 251NT 251QT VO5 Breaker 2 Close VO5 TRUE if breaker control switch 101C is TRUE closed and 86 lockout is not tripped CLOSE BKR2 CLOSE NORMAL BESTlogic Expression VO5 IN3 101C VO6 Used to annunciate an alarm by contact closure or opening if any of the cond...

Page 249: ... Relay Trouble Alarm OUTA contact closes when relay trouble alarm occurs BESTlogic Expression OUTA VOA OUT1 Phase differential trip OUT1 is a high speed trip contact OUT1 contact closes if restrained unrestrained 51 or 151 trip occurs BESTlogic Expression OUT1 VO1 OUT2 Breaker 1 Trip OUT2 contact closes if restrained unrestrained 51 151 or 43 virtual switch trip occurs BESTlogic Expression OUT2 VO...

Page 250: ...d to select test mode enable The user may choose to eliminate the use of external switches as the virtual switches are fully functional equivalents of their physical counterparts Figure 8 7 is a logic drawing that represents the logic settings and equations shown in Table 8 19 Figure 8 8 is a Device Interconnection for Integrated Protection System and Figure 8 9 is a one line drawing In Table 8 19...

Page 251: ...oing to the same OR Gate are shown by a single line into the OR Gate 50TP Mode2 50TPT 50TPPU 50TN Mode2 50TNT 50TNPU 50TQ Mode2 50TQT 50TQPU BLK BLK BLK 12 VO11 PROT TRIP VO12 PROT PU VOA Relay Trouble OUTA Output Logic VO1 86T Trip OUT1 Output Logic VO2 86B Trip OUT2 Output Logic VO3 52 2 86F Trip OUT3 Output Logic 4 VO4 52 2 Trip OUT4 Output Logic VO5 52 2 Close OUT5 Output Logic Feeder Backup M...

Page 252: ...ure 8 8 Device Interconnection for Integrated Protection System using BE1 CDS240 for Transformer Protection and BE1 851 or BE1 951 for Bus and Feeder Protection 8 26 BE1 CDS240 Application 9365200990 Rev F ...

Page 253: ...e high side CT Input 1 and the 87 and 251 protection elements are connected to the low side CT Input 2 The 51 protection element N only is connected to a ground CT at the grounded side of a delta wye transformer The ground input G is an option on the BE1 CDS240 and 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 e...

Page 254: ...ntegration of Protection Control and I O Elements The logic settings in Table 8 19 also include the logic equations that establish the control connections between elements of the CDS240 TXBU B BE scheme For example the two underlined commands in the settings of Table 8 19 provide the electrical connection between the 87 element trip enabled by the program and Trip Outputs 1 and 4 Referring to Figu...

Page 255: ...side breaker when TRUE TRUE when 86B is tripped 86B TRIPPED TRIPPED NORMAL IN5 Puts transformer and bus relays in feeder backup mode when feeder relay out of service is detected by an open contact Feeder relays such as BE1 851 or BE1 951 using one of the preprogrammed schemes with interlock logic FEEDERS_OK NORMAL FDR_OOS IN6 Breaker Failure Initiate by external relays with breaker status supervis...

Page 256: ...rrent protection for CT input circuit 2 0 2 Circuit 2 251Q Used for timed negative sequence overcurrent protection for CT input circuit 2 0 2 Circuit 2 50TP Used as fault detector for Breaker 2 external BFI IN7 supervision 0 2 Circuit 2 50TN Used as fault detector for Breaker 2 external BFI IN7 supervision 0 2 Circuit 2 50TQ Used as fault detector for Breaker 2 external BFI IN7 supervision 0 2 Cir...

Page 257: ... BESTlogic Expression VO1 87RT 87UT 151PT 51NT 151NT 151QT VO2 Transformer fault trip 86B for example VO2 TRUE Trip bus breaker via lockout for bus faults 250T w 18 20 cycles delay TRIP 86B TRUE FALSE BESTlogic Expression VO2 250TPT 250TNT 250TQT VO3 Breaker 2 breaker failure trip 86F for example TRUE when BFT or 62 times out TRIP 86F TRUE FALSE BESTlogic Expression VO3 BFT2 62 VO4 Breaker 2 Trip ...

Page 258: ...250T 51 151 or 251 element picks up PROT PICKED UP PU NORMAL BESTlogic Expression VO12 250TPPU 250TNPU 87RPU 87UT 250TQPU 151PPU 251PPU 51NPU 151NPU 251NPU 151QPU 251QPU Note 87UT is included to trigger the fault recorder because there is no unrestrained pickup output VO13 Alarm to indicate that the differential cutoff switch is in the block operation position TRUE if Virtual Switch 43 is in the c...

Page 259: ...51 or BE1 951 for feeder protection and the BE1 CDS240 for bus protection When interconnected with feeder relays using preprogrammed feeder logic FDR W IL the CDS240 BSBU A BE scheme provides complete backup except for reclosing for the feeder relays if relay failure occurs or when they are out of service for testing or maintenance Virtual control switch logic is used for local or remote SCADA con...

Page 260: ...SL 181 0 0 SL 281 0 0 SL 381 0 0 SL 481 0 0 SL 581 0 0 SL 62 0 0 0 SL 162 0 0 0 SL 262 0 0 0 SL 362 0 0 0 SL GROUP 2 IN7 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 1101 0 SL 2101 0 SL 3101 0 SL VOA 0 SL VO1 87RT VO8 VO14 SL VO2 250TPT 250TNT 250TQT SL VO3 VO9 VO14 SL VO4 87RT VO9 VO14 VO10 101T SL VO5 IN3 IN4 101C SL VO6 VO7 VO15 SL VO7 87RT VO9 VO14...

Page 261: ...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 83 F2 83 Fn IN5 TX W BU RELAY FEEDER BACKUP MODE C26 C25 C32 C31 BE1 CDS220 F1 BE1 851 F2 BE1 851 Fn BE1 851 NOTES 1 BE1 951 relays using FDR W IC logic could be substituted for BE1 851 relays See Note 1 52 BUS MAIN TX W BU BE1 CDS220 B...

Page 262: ...Figure 8 11 Typical One line Diagram for CDS240 BSBU A BE 8 36 BE1 CDS240 Application 9365200990 Rev F ...

Page 263: ...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 150TNPU 150TQ Mode1 150TQT 150TQPU BLK BLK BLK 101 Mode1 101T 52 2 Trip 101C 52 2 Close 101SC 50TP Mode1 50TPT 50TPPU 50TN Mode1 50TNT 50TNPU 50TQ Mode1 50TQT 50TQPU BL K BLK BLK 6 87 Mode1 87RT 87RPU BLK 87UT 2NDHAR 5THHAR 43 Mode2 DIFF Cut...

Page 264: ...or normal mode the 250T protection element should have a pickup setting greater than the highest feeder instantaneous element to ensure that it will not pickup before any feeder relay When a Feeder Relay Out of Service signal is detected through IN7 of the BE1 CDS240 CDS240 BSBU A BE the relay switches from normal mode to feeder backup mode The 250T protection element is reset from setting group 0...

Page 265: ...ed front panel LED When the relay self test detects a problem in the relay ALMREL as programmed for the CDS240 BSBU A BE scheme the Relay Trouble LED lights Output A operates and all outputs are disabled When a Major Alarm is detected ALMMAJ the associated LED lights but in this scheme no output relay is programmed to operate When a Minor Alarm ALMMIN is detected the associated LED lights but in t...

Page 266: ...ly for bus time OC protection coordinated with feeder relay time OC When in feeder relay backup mode provides primary time OC protection for feeder SG1 settings must coordinate with other feeder 51 elements 0 1 Circuit 1 51N Applied to bus main CT 1 Normally for bus time OC protection coordinated with feeder relay time OC When in feeder relay backup mode provides primary time OC protection for fee...

Page 267: ...ain 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 Circuit 1 Input 0 Logic Switch to setting group 1 if feeder relay is out of service as indicated by closed contact from relay with BACKUP logic such as BE1 851 BE1 951 or BE1 CDS240 IN7 Input 1 Logic No manual selection logic is...

Page 268: ...p overcurrent trip Or for control switch trip TRIP BKR1 TRIP NORMAL BESTlogic Expression VO4 87RT VO9 VO14 VO10 101T VO5 Breaker 1 Close VO5 TRUE if virtual control switch is TRUE and 86T or 86B LO is not tripped CLOSE BKR1 CLOSE NORMAL BESTlogic Expression VO5 IN3 IN4 101C VO6 Breaker Failure Initiate output Initiate breaker failure protection in relay using backup logic VO6 TRUE Initiate breaker...

Page 269: ...nt has picked up PROT PICKED UP PU NORMAL BESTlogic Expression VO12 50TPPU 150TPPU 50TNT 150TNPU 87RPU 50TQPU 150TQPU 51PPU 151PPU 51NPPU 151NPU 51QPU 151QPU VO13 Alarm to indicate that the differential cutoff switch is in the block operation position TRUE if Virtual Switch 43 is in the closed position 87 BLOCKED ACTIVE NORMAL BESTlogic Expression VO13 43 VO14 Alarm that relay is in feeder backup ...

Page 270: ...against stator phase and ground faults locked rotor jam thermal overload and unbalanced current Basic frequent starting protection is also provided Virtual control switch logic is used for local or remote control and can be used to replace the equivalent panel control switches The control switch elements are referred to as virtual because they have no physical form they exist only in logic form an...

Page 271: ...0 0 SL 24 0 0 SL 27P 0 0 SL 127P 0 0 SL 47 0 0 SL 59P 0 0 SL 59X 0 0 SL 159P 0 0 SL 81 0 0 SL 181 0 0 SL 281 0 0 SL 381 0 0 SL 481 0 0 SL 581 0 0 SL 62 0 0 0 SL 162 0 0 0 SL 262 0 0 0 SL 362 0 0 0 SL GROUP 0 0 0 0 0 0 SL 43 0 SL 143 2 SL 243 2 SL 343 0 SL 443 0 SL 543 0 SL 643 0 SL 743 0 SL 101 0 SL 1101 0 SL 2101 0 SL 3101 0 SL VOA 0 SL VO1 VO11 SL VO2 0 SL VO3 0 SL VO4 VO14 SL VO5 VO15 SL VO6 0 ...

Page 272: ...nce 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 Start Running Detect 87 CT Input 1 CT Input 2 DIFF SOURCE Figure 8 13 Typical One line Diagram for CDS240 MOTR A BE 8 46 BE1 CDS240 Application 9365200990 Rev F ...

Page 273: ...to provide a trip by the settings shown in Table 8 31 Protection elements set at 0 are setting disabled and will not provide a trip output even if logic enabled Typically the 87 protection element provides high speed percent restrained phase and ground protection for faults inside the differential zone For the CDS240 MOTR A BE application shown in Figure 8 14 the percent restrained differential pr...

Page 274: ...ed then when the breaker is closed 50TP picks up forcing VO7 high and removing the block from 151P locked rotor protection Locked rotor 151P picks up and starts timing If the motor current drops below the 50TP setting before 151P times out the locked rotor protection is blocked and the motor start was successful However if the motor current stays high until 151P times out the motor is tripped thro...

Page 275: ...rammed to operate NOTE Tables 8 32 through 8 36 provide detailed logic definitions for the inputs outputs protection and control elements Only those inputs logic blocks virtual switches and outputs in use for the CDS240 MOTR A BE preprogrammed logic are described in the following tables Table 8 32 CDS240 MOTR A BE Contact Input Logic State Labels Input Purpose Name Label Energized De Energized IN1...

Page 276: ... MOTR A BE Virtual Switch Logic State Labels Switch Purpose Mode Label True False 143 Speed Switch selector When enabled the motor starting is determined by speed switch When None starting is determined by current detector set at 85 of locked rotor current 2 On Off SPEED SWITCH ENABLED NONE 243 Selector Switch to customize the protection for high or low inertia applications When high is selected b...

Page 277: ...ression Restrained diff trip 50TN ground fault 50TQ loss of phase 150TP low inertia locked rotor 51P overload 51Q unbalance 151P high inertia locked rotor 251P Jam or VO13 Emergency Trip PROTECTIVE TRIP TRIP NORMAL BESTlogic Expression VO11 150TPT 50TNT 87RT VO13 50TQT 51PT 151PT 251PT 51QT VO12 Protective pickup expression Restrained and unrestrained diff trip 50TN ground fault 50TQ loss of phase...

Page 278: ...through the ASCII command interface using the SL set logic commands Several of the Reporting And Alarm Functions provided in the relay require programmable logic expressions to determine their functionality These logic expressions are included with the settings associated with each function Table 8 37 cross references the manual Sections and commands associated with each miscellaneous logic expres...

Page 279: ...es using the trip circuit continuity monitor in breaker failure logic Example 1 Breaker failure trip expression SL VO5 BFT VO10 CKTMON IN4 343 Example 2 Block upstream instantaneous expression SL VO4 VO12 VO5 CKTMON IN4 343 If the internal breaker failure function block is not being used the trip circuit continuity and voltage monitor alarm can be used to detect when the test switches have been op...

Page 280: ...s her operating practices and his her setting practices For instance on systems with wye connected loads the ground units are most sensitive to this situation On systems with delta connected loads the negative sequence units are most sensitive to this situation It may not be necessary to block the instantaneous units if their settings prevent them from tripping for a switching imbalance To maintai...

Page 281: ...r a low resistance connection The third is to prevent the relay contact from dropping out until the current has been interrupted by the 52a contacts in series with the trip coil If the tripping contact opens before the dc current is interrupted the contact may be damaged The first two of these items are not an issue for solid state relays but the third item is an issue To prevent the output relay ...

Page 282: ...re 8 18 The user wants to trip and lockout the high side circuit switcher for a differential trip but not for an overcurrent trip He she does not want the transformer to be re energized until someone locally checks and resets the relay Referring to Figure 8 19 which is an adaptation of CDS240 BA87 B BE logic an 87 trip will cause VO7 to go TRUE This causes OUT1 OUT2 and OUT3 to close and OUT5 that...

Page 283: ...ple Use the application shown in Figure 8 18 and 8 19 The user wants to trip and lockout the high side circuit switcher CSW for a Sudden Pressure Relay 63_SPR trip The SPR trip is to be supervised and sealed in via the BE1 CDS240 relay Since this is an external function it is desired that the relay annunciate that the trip came from the SPR instead of an internal protective element Referring to Fi...

Page 284: ...0 SL 51Q 1 0 SL VO1 VO7 VO13 SL VO2 VO7 VO13 SL VO3 VO7 VO13 SL VO4 51PT 51NT 51QT SL VO5 VO7 VO13 SL VO6 ALMMAJ SL VO7 87RT 87UT VO8 SL VO8 VO7 TRSTKEY SL VO9 VO13 ARSTKEY SL VO11 51PT 51NT 51QT 87RT 87UT SL VO12 87UT 51PPU 51NPU 51QPU 87RPU SL VO13 IN4 VO9 SL OUT1 VO1 SL OUT2 VO2 SL OUT3 VO3 SL OUT4 VO4 SL OUT5 VO5 SL OUT6 VO6 ...

Page 285: ...NTS SECTION 9 SECURITY 9 1 INTRODUCTION 9 1 Setting 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 Passwords Shown 9 2 Tables Table 9 1 Password Protection Settings 9 3 ...

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Page 287: ...2 port COM0 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 to be accepted the entered password must be correct and the command must be entered through a valid port Only one password can be active at one time for any area or port For example if a use...

Page 288: ... 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 RS 232 and HMI COM 1 Rear RS 232 and COM 2 Rear RS 485 Access levels may also be enabled for multiple ports Figure 9 2 General Operation Screen Global Security Tab with Passwords Shown 9 2 BE1 CDS240 Security 9365200990 Rev F ...

Page 289: ...rotection settings Table 9 1 Password Protection Settings Setting Range 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 ...

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Page 291: ...Tree Top Level All Branches 10 2 Figure 10 3 BE1 CDS240 Menu Tree Report Status 10 3 Figure 10 4 BE1 CDS240 Menu Tree Control Branch 10 4 Figure 10 5 BE1 CDS240 Menu Tree Metering PRI SEC Branch 10 5 Figure 10 6 BE1 CDS240 Menu Tree Reports Branch 10 6 Figure 10 7 BE1 CDS240 Menu Tree Protection Branch 1 of 2 10 7 Figure 10 8 BE1 CDS240 Menu Tree Protection Branch 2 of 2 10 8 Figure 10 9 BE1 CDS24...

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Page 293: ... and power supply input voltages B Power Indicator This green LED lights when operating power is applied to 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 description of all relay failure alarm diagnostics D E Minor Alarm Major Alarm Indicators T...

Page 294: ...eters the active logic scheme name and diagnostic information is provided by the LCD Information and settings are displayed in a menu with branches The Menu Tree subsection provides more information about the menu branches Menu Tree A menu tree with six branches can be accessed through the front panel controls and display The LEFT and RIGHT scrolling pushbuttons are used to view each of the six br...

Page 295: ...iguration settings such as communication LCD contrast transformer ratios and system frequency General Settings menu branch structure is illustrated in Figure 10 9 In the following figures notice near the upper left hand corner of each screen display one two three or four digit numbers with decimal points between each digit These numbers are reference numbers to the screens in the menu tree They ar...

Page 296: ...Figure 10 4 BE1 CDS240 Menu Tree Control Branch 10 4 BE1 CDS240 Human Machine Interface 9365200990 Rev F ...

Page 297: ...D2840 29 09 24 03 VOLT SEQ VARS WATTS SCREENS 3 4 2 W atts 3 4 3 V ars 6 AUX FREQ Figure 10 5 BE1 CDS240 Menu Tree Metering PRI SEC Branch 9365200990 Rev F BE1 CDS240 Human Machine Interface 10 5 ...

Page 298: ...Figure 10 6 BE1 CDS240 Menu Tree Reports Branch 10 6 BE1 CDS240 Human Machine Interface 9365200990 Rev F ...

Page 299: ...x xm 650TP x x xx xm 750TP x x xx xm 50TP 50TN 5 1 4 5 1 2 1 PROT SG0 50T 50TN MODE PU TDELAY 50TN 0 115 15 S 150TN x x xx xm 250TN x x xx xm 350TN x x xx xm 450TN x x xx xm 450P 50TQ 5 1 1 3 PROT SG0 51 51Q MODE PU TD CRV 51Q 0 10 3 9 99 S1R 151Q 2 1 0 0 21 S2 251Q 1 xx x x xx xxx 351Q x xx x x xx xxx 51N 27R 5 1 3 3 PROT SG0 87 TAP MVA 0 MANUAL TAP1 x xx TAP2 x xx TAP3 x xx TAP4 x xx MVA 87 5 1 ...

Page 300: ...Figure 10 8 BE1 CDS240 Menu Tree Protection Branch 2 of 2 10 8 BE1 CDS240 Human Machine Interface 9365200990 Rev F ...

Page 301: ... Figure 10 9 BE1 CDS240 Menu Tree General Settings Branch 9365200990 Rev F BE1 CDS240 Human Machine Interface 10 9 ...

Page 302: ...EFT 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 progress through the scroll list in descending order Pressing the UP scroll pushbutton will leave the automatic scroll list and place you in the menu tree at Screen 1 3 STAT SCREENS Once the user h...

Page 303: ...rom 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 manual scrolling pushbuttons perform the following procedures 1 Scroll to the screen that displays the function to be edited 2 Press the Edit pushbutton to gain access If password security has been initiated for settings you will be prompted to enter ...

Page 304: ... Switch 243 Switch 243 closed state label set to NORMAL C User selectable label for the open 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 NORMAL E Current switch status This indicator should correspond to the current user labeled switch status The sw...

Page 305: ...password A 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 until the proper first character of the password appears Pressing UP scrolls through the alphabet and then the numbers in ascending order Pressing DOWN scrolls through the numbers and then t...

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Page 307: ...d 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 Settings 11 9 Configuring the Serial Port Communication Protocol 11 12 COMMAND SUMMARY 11 13 Miscellaneous Commands 11 13 Metering Commands 11 13 Control Commands 11 15 Report Commands 11 15 Setting Command...

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Page 309: ...pgrade to HyperTerminal that fixes the problem is available from the Microsoft s source of HyperTerminal Hilgraeve Inc at www hilgraeve com The upgrade is referred to as HyperTerminal Private Edition Companies that download and use this software must review the terms and conditions associated with the use of the software SERIAL PORT Communication connections consist of two Data Communication Equip...

Page 310: ...ort all real 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 Subgroups include Alarms A Breaker Monitoring B Demand Recording D Fault Summary Reporting F General Information G Sequence of Events Recorder S and Oscillography O SETTINGS S This group contain...

Page 311: ...nformation on command syntax 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 where cmd is a specific command returns information about the use and format of the command along with an example of how the command is used HELP Command Purpose Obtain help on co...

Page 312: ...ivileges then 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 A valid password is entered ACCESS OPENUP ACCESS GRANTED GLOBAL Example 2 An invalid password is entered ACCESS POENUP ACCESS DENIED Example 3 The current access privilege is read ACCESS ACC...

Page 313: ...d of the relay settings If saved in a file the report can be sent to another BE1 CDS240 that will use the same settings Because the report that is created is a set of commands sending the report to a different relay re programs that relay with the settings contained in the S report Reading Specific Groups of Settings While the S command is useful for reading all relay settings several commands are...

Page 314: ...P N SG CKT4 WYE 0 A P N SG CTP1 1 WYE SG CTP2 1 WYE SG CTP3 1 WYE SG CTP4 1 WYE SG CTG 1 SG VTP 1 00 4W PP PP 1 0 SG NOM 69 3 5 00 SG IN1 4 16 SG IN2 4 16 SG IN3 4 16 SG IN4 4 16 SG IN5 4 16 SG IN6 4 16 SG IN7 4 16 SG IN8 4 16 SG IN9 4 16 SG IN10 4 16 SG IN11 4 16 SG IN12 4 16 SG HTIME 20s SG SGCON 5 SG DC 1 2 3 4 SG DIP 15 T SG DIN 1 T SG DIQ 1 T SG LOG 15 SG TARG 87U 87R 87ND 187ND 24 27P 127P 4...

Page 315: ...000000 SG RID7 REMOTE_7_NAME 000000000000 SG RID8 REMOTE_8_NAME 000000000000 SG RID9 REMOTE_9_NAME 000000000000 SG RID10 REMOTE_10_NAME 000000000000 SG RID11 REMOTE_11_NAME 000000000000 SG RID12 REMOTE_12_NAME 000000000000 SG RID13 REMOTE_13_NAME 000000000000 SG RID14 REMOTE_14_NAME 000000000000 SG RID15 REMOTE_15_NAME 000000000000 SG RID16 REMOTE_16_NAME 000000000000 SG USERST1 0 2 0 33 SG USERST...

Page 316: ...SN IN1 BREAKER OPEN CLOSED SN Command Example Example 1 Read the programmed labels for the alarm output OUTA SN VOA VOA_LABEL TRUE FALSE S g Command Purpose Read all Protection settings Syntax S g where g setting group 0 3 or for all groups Example S or S0 or S1 S g Command Example Example 1 Obtain a list of settings for Setting Group 1 S1 S1 TAP87 MANUAL 2 00 2 00 2 00 2 00 S1 TAP87ND 2 00 2 00 S...

Page 317: ...0 50m S1 27P 0 00 50m 0 00 S1 127P 0 00 50m 0 00 S1 47 0 00 50m S1 59P 0 00 50m S1 59X 0 00 50m S1 159P 0 00 50m S1 81 00 00 0m O S1 181 00 00 0m O S1 281 00 00 0m O S1 381 00 00 0m O S1 481 00 00 0m O S1 581 00 00 0m O S1 81INH 40 0 S1 62 0m 0m S1 162 0m 0m S1 262 0m 0m S1 362 0m 0m SP 60FL ENA PNQ SP CURVE 0 2663 0 0339 1 0000 1 2969 0 5000 SP GROUP1 0 0 0 0 51P SP GROUP2 0 0 0 0 51P SP GROUP3 0...

Page 318: ...settings associated with the CDS240 BATX A BE logic scheme SL CDS240 BATX A BE SL N CDS240 BATX A BE BASLER SL 87 1 0 SL 87ND 0 0 SL 187ND 0 0 SL 50BF 0 0 0 0 0 SL 150BF 0 0 0 0 0 SL 250BF 0 0 0 0 0 SL 350BF 0 0 0 0 0 SL 50TP 0 0 SL 50TN 0 0 SL 50TQ 0 0 SL 150TP 0 0 SL 150TN 0 0 SL 150TQ 0 0 SL 250TP 0 0 SL 250TN 0 0 SL 250TQ 0 0 SL 350TP 0 0 SL 350TN 0 0 SL 350TQ 0 0 SL 450TP 0 0 SL 450TN 0 0 SL ...

Page 319: ... 0 SL 3101 0 SL VOA 0 SL VO1 87RT 87UT SL VO2 0 SL VO3 0 SL VO4 151PT 51NT 151NT 151QT SL VO5 251PT 251NT 251QT SL VO6 ALMMAJ SL VO7 0 SL VO8 0 SL VO9 0 SL VO10 0 SL VO11 87RT 87UT 151PT 251PT 51NT 151NT 251NT 151QT 251QT SL VO12 87RPU 87UT 151PPU 251PPU 51NPU 151NPU 251NPU 151QPU 251QPU SL VO13 IN6 SL VO14 IN7 SL VO15 IN8 SL OUTA VOA SL OUT1 VO1 SL OUT2 VO1 SL OUT3 VO1 SL OUT4 VO4 SL OUT5 VO5 SL ...

Page 320: ...MPx ModbusTM parity where x N None O Odd and E Even MRx ModbusTM remote delay time where x 10 msec to 200 msec MSx ModbusTM stop bit where x 1 for one stop bit or 2 for two stop bits If a non zero address is programmed in the A parameter then the relay will ignore all commands that are not preceded by its specific address If an address of 0 is programmed then the relay will respond with an error m...

Page 321: ...Interface Miscellaneous Command Descriptions Metering Commands M Command Purpose Read all metered values in primary or secondary units Syntax M P S where P primary S secondary Example M or M S Reference Section 5 Metering M V3V0 Command Purpose Read calculated neutral voltage 3V0 in primary units Syntax M V3V0 Example M V3V0 Reference Section 5 Metering M FAST Command Purpose Read fast metered val...

Page 322: ...urpose Read metered 3 Phase Watts W in primary units Syntax M WATT phase where phase 3 A B C Example M WATT or M WATT3 M WATTA M WATTB or M WATTC Reference Section 5 Metering M I Command Purpose Read CT circuit 1 6 current primary or secondary units Syntax M n I p y where n 1 6 p A B C N Q y P for primary S for secondary Example M1 or M2 I or M3 IA Reference Section 5 Metering MD Command Purpose R...

Page 323: ... 3 Input And Output Functions Outputs CO OUT Section 4 Protection and Control Setting Groups CO GROUP Section 4 Protection and Control Virtual Switches CO 43 Section 4 Protection and Control Virtual Switches CO 101 CS Command Purpose Control Selection Syntax CS control mode where control GROUP OUT x43 x101 mode 0 3 L for GROUP 0 1 P L ENA DIS for OUT 0 1 P for x43 and T C for x101 Example CS GROUP...

Page 324: ...y Alarm Sequence of Events information Syntax RA SER Example RA SER Reference Section 6 Reporting and Alarm Functions Sequence of Events Recorder Function RB Command Purpose Read Breaker Status Syntax RB Example RB Reference Section 6 Reporting and Alarm Functions Breaker Monitoring RB DUTY Command Purpose Read Set Breaker Contact Duty Log where n 1 2 3 4 for Ckt1 Ckt2 Ckt3 Ckt4 Syntax RB DUTY n p...

Page 325: ...6 Reporting and Alarm Functions Demand Functions RD LOG Command Purpose Report load profile data Syntax RD LOG n Example RD LOG 23 view load profile record for last 23 records Reference Section 6 Reporting and Alarm Functions Demand Functions RD P Command Purpose Read Reset peak demands since reset Syntax RD P 0 Example RD P or RD P 0 Reference Section 6 Reporting and Alarm Functions Demand Functi...

Page 326: ...ce Section 6 Reporting and Alarm Functions Demand Functions RD TVAR Command Purpose Report today s Forward and Reverse demand vars Syntax RD TVAR Example RD TVAR Reference Section 6 Reporting and Alarm Functions Demand Functions RD TWATT Command Purpose Report today s Forward and Reverse demand watts Syntax RD TWATT Example RD TWATT Reference Section 6 Reporting and Alarm Functions Demand Function...

Page 327: ...ons Energy Data RE KWH Command Purpose Read Reset Preset 3 Phase KiloWattHours in primary units Syntax RE KWH pos kwh neg kwh Example RE KWH or RE KWH 100 10 or RE KWH 0 0 Reference Section 6 Reporting and Alarm Functions Energy Data RF Command Purpose Read Reset Fault Report Data Syntax RF n NEW 0 TRIG where n record or NEW new records Example RF displays a directory of all fault reports in memor...

Page 328: ...Format set by SG CLK Command Reference Section 6 Reporting and Alarm Functions General Status Reporting RG DST Command Purpose Report start and stop times and dates for Daylight Saving Time referenced to local time Syntax RG DST Example RG DST Reference Section 6 Reporting and Alarm Functions Clock RG GRPACTIVE Command Purpose Report active group Syntax RG GRPACTIVE Example RG GRPACTIVE Reference ...

Page 329: ...atus Reporting RL Command Purpose Read Logic Variables each Logic Variable is 32 bits long Syntax RL n where n 1 2 3 4 5 or 6 Example RL or RL 1 Reference Section 6 Reporting and Alarm Functions General Status Reporting RO Command Purpose Read Oscillographic COMTRADE DAT CFG HDR Fault Report Syntax RO nA B A CFG DAT HDR n report num A B ASCII BINARY OSC 1 2 A 1999 format Example RO 3A1 CFG RO 3A1 ...

Page 330: ...s Syntax S Example S Reference Section 11 ASCII Command Interface Settings S Command Descriptions Alarm Setting Commands SA Command Purpose Read all alarm settings for Major Minor and Logic alarms Syntax SA Example SA Reference Section 6 Reporting and Alarm Functions Alarms Function SA 24 Command Purpose Read Set Volts Per Hertz alarm settings Syntax SA 24 alarm level td m alarm level volts per he...

Page 331: ...orting and Alarm Functions Demand Functions SA DV Command Purpose Read Set Voltage Max and Min demand alarm setting Syntax SA DV p max alm lvl min alm lvl where p P N alm lvl Sec Volts Example SA DV or SA DVP 0 0 or SA DVN 100 10 Reference Section 6 Reporting and Alarm Functions Demand Functions SA DVAR Command Purpose Read Set Var demand alarm setting Syntax SA DVAR pos alm lvl neg alm lvl where ...

Page 332: ...ntax SB Example SB Reference Section 6 Reporting and Alarm Functions Breaker Monitoring SB DUTY Command Purpose Read Set Breaker Contact Duty where n 1 2 3 4 for Ckt1 Ckt2 Ckt3 Ckt4 Syntax SB DUTY n Exponent DMax BLKBKR logic Example SB DUTY1 1 5 60E3 IN5 Reference Section 6 Reporting and Alarm Functions Breaker Monitoring SB LOGIC Command Purpose Read Set Breaker Contact Logic where n 1 2 3 4 for...

Page 333: ...k Protocol DNP manual for BE1 CDS240 SDNP USERAI Command Purpose Read Set user configuration of DNP Analog Input points Syntax SDNP USERAI T startndx endndx startpDftID endpDftID where T is total number of points in user map startndx is a reporting index of data with default index startDftID endndx is a reporting index of data with default index endDftID Max number of points specified in one comma...

Page 334: ... XON ena Example SG COM0 9600 or SG COM1 9600 A0 P24 R1 X1 Reference Section 11 ASCII Command Interface Settings S Command Descriptions Configuring the Serial Port Communication Protocol SG CTG Command Purpose Read Set Ground CT ratio Syntax SG CTG ct ratio Example SG CTG 80 or SG CTG 400 5 Reference Section 3 Input and Output Functions Power System Inputs SG CTP Command Purpose Read Set Phase CT ...

Page 335: ...1st Tue in Nov Reference Section 6 Reporting and Alarms Function Clock SG FREQ Command Purpose Read Enter power system Frequency Syntax SG FREQ freq HZ Example SG FREQ 60 or SG FREQ 50 Reference Section 3 Input and Output Functions Power System Inputs SG HOLD Command Purpose Read Program Output Hold operation Syntax SG HOLD n 1 0 hold ena where 1 TRUE 0 FALSE Example SG HOLD or SG HOLD1 1 or SG HO...

Page 336: ... Human Machine Interface Front Panel Display SG SGCON Command Purpose Read Set SGC output on time Syntax SG SGCON time where time is in s ec Example SG SGCON or SG SGCON 1S or SG SGCON 5S Reference Section 4 Protection and Control Setting Groups SG TARG Command Purpose Report Enable Target List and reset target logic Syntax SG TARG x x x rst TARG logic where x 50T 51 87U 87R BF etc Example SG TARG...

Page 337: ...dule Syntax SL GROUP mode D0logic D1logic D2logic D3logic AUTOlogic Example SL GROUP or SL GROUP 1 IN3 IN4 0 0 0 Reference Section 4 Protection and Control Setting Groups SL N Command Purpose Read Set Name of the active logic Syntax SL N name Example SL N CDSTEST Reference Section 7 BESTlogic Programmable Logic Logic Schemes SL OUT Command Purpose Read Set Hardware Output Logic Syntax SL OUT x y y...

Page 338: ...52INIlogic 52Statuslogic BLKlogic Example SL 50BF or SL 50BF 1 VO1 VO2 VO3 0 or SL 50BF 1 VO1 IN1 Reference Section 4 Protection and Control BF Breaker Failure Protection SL 50T Command Purpose Read Set Logic for x50 Function Modules where x blank 1 2 4 5 6 7 Syntax SL x50T p mode BLK logic where p P N Q and mode Ckt Example SL 50TP or SL 50TP 1 0 or SL 150TN 1 IN3 or SL 250TQ 2 IN2 Reference Sect...

Page 339: ...Programmable Logic User Input and Output Logic Variable Names Protection Setting Commands S g Command Purpose Read all Protection settings Syntax S g where g setting group 0 3 or for all groups Example S or S0 or S1 Reference Section 11 ASCII Command Interface Settings S Command Descriptions S g 24 Command Purpose Read Set 24 pickup level time delay reset delay and curve Syntax S g 24 pu V Hz td r...

Page 340: ...d Purpose Read Set x51 pickup level time dial and curve where x blank 1 2 3 4 Syntax S g x51 p pu A td crv where g 0 3 p P N Q Example S0 51P or S0 51P 7 5 6 5 S1 or S1 151Q 3 2 0 S1 or S2 251Q 3 2 0 S1 Reference Section 4 Protection and Control Overcurrent Protection S g 59 Command Purpose Read Set 59 pickup level and time delay Syntax S g x59 p pu V td m where x blank or 1 g 0 1 2 3 and p P X Ex...

Page 341: ... NQ P N Q Example SP 60FL or SP 60FL ENA PNQ or SP 60FL DIS DIS Reference Section 4 Protection and Control Voltage Transformer Fuse Loss Detection SP CURVE Command Purpose Read Set the user programmable 51 curve parameters Syntax SP CURVE A B C N R Example SP CURVE or SP CURVE 1 0 0 0 2 5 0 Reference Section 4 Protection and Control Overcurrent Protection SP GROUP Command Purpose Read Program auxi...

Page 342: ...11 34 BE1 CDS240 ASCII Command Interface 9365200990 Rev F This page intentionally left blank ...

Page 343: ...onnections I O Option A Shown 12 11 Figure 12 13 Horizontal or Vertical Rear View Terminal Connections I O Option E Shown 12 12 Figure 12 14 Typical AC Connection 3 Restraint Windings 2 IG Inputs with Voltage Protection 12 14 Figure 12 15 Typical AC Connection 4 Restraint Windings 1 IG without Voltage Protection 12 15 Figure 12 16 Typical Application Two winding Transformer with 4 Restraint Connec...

Page 344: ...0 Installation 9365200990 Rev F Tables Table 12 1 Contact Sensing Turn On Voltage 12 1 Table 12 2 RS 232 Pinouts COM0 and COM1 12 24 Table 12 3 RS 485 Pinouts COM 2 12 26 Table 12 4 IRIG Terminal Assignments 12 27 ...

Page 345: ...rgizing levels for the contact sensing inputs are jumper selectable for a minimum of approximately 5 Vdc for 24 Vdc nominal sensing voltage 26 Vdc for 48 Vdc nominal sensing voltages 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 Contact Sensing Turn On Voltage Nominal Control Voltage Jumper L Position...

Page 346: ...give you Internet access to the latest BESTCOMS software and firmware updates for your devices In addition registration also allows Basler Electric to contact you if a problem is found in the design or manufacturing of our products that might affect you The registration process only takes a few minutes Please have the serial number s of your relay s available when registering MOUNTING Because the ...

Page 347: ...are horizontal mount units but shown vertically so that small details can be more easily read Vertical and horizontal configurations are functionally the same with some controls and indicators relocated All dimensions given on the above listed drawings are dimensioned in inches millimeters Figure 12 2 Horizontal Panel Mount or Vertical M size Panel Mount Front View 9365200990 Rev F BE1 CDS240 Inst...

Page 348: ...igure 12 3 Horizontal Panel Mount Top View or Vertical M size Panel Mount Side View Figure 12 4 Horizontal Panel Mount Side View or Vertical M size Top View 12 4 BE1 CDS240 Installation 9365200990 Rev F ...

Page 349: ...Figure 12 5 Horizontal Rack Mount Front View 9365200990 Rev F BE1 CDS240 Installation 12 5 ...

Page 350: ...Figure 12 6 Horizontal Rack Mount Top View Figure 12 7 Horizontal Rack Mount Side View 12 6 BE1 CDS240 Installation 9365200990 Rev F ...

Page 351: ...Figure 12 8 Vertical Panel Mount L size Front View 9365200990 Rev F BE1 CDS240 Installation 12 7 ...

Page 352: ...Figure 12 9 Vertical Panel Mount L size Top View Figure 12 10 Vertical Panel Mount L size Side View 12 8 BE1 CDS240 Installation 9365200990 Rev F ...

Page 353: ...Panel Drilling Diagram NOTE These dimensions are for the MX case vertical panel mount or the MX case horizontal panel mount Rotate this drawing ninety degrees for the MX case horizontal panel mount 9365200990 Rev F BE1 CDS240 Installation 12 9 ...

Page 354: ...ls A1 through A28 are for current inputs and use 8 32 pan head Phillips screws with a lock washer The remaining terminals use 6 32 pan head Phillips screws with no washer See Figure 12 15 to locate these terminals The lock washers on Terminals B C and D are integral parts of the current input circuit wiring and should not be removed Without the lock washer the 8 32 screw may bottom out and prevent...

Page 355: ...Figure 12 12 Horizontal or Vertical Rear View Terminal Connections I O Option A Shown 9365200990 Rev F BE1 CDS240 Installation 12 11 ...

Page 356: ...Figure 12 13 Horizontal or Vertical Rear View Terminal Connections I O Option E Shown 12 12 BE1 CDS240 Installation 9365200990 Rev F ...

Page 357: ...n 12 AWG copper wire attached to the rear ground terminal of the relay case When the relay is configured in a system with other protective devices a separate ground bus lead is recommended for each relay Except as noted above connections should be made with minimum wire size of 14 AWG Be sure to use the correct input power for the power supply specified 9365200990 Rev F BE1 CDS240 Installation 12 ...

Page 358: ...Figure 12 14 Typical AC Connection 3 Restraint Windings 2 IG Inputs with Voltage Protection 12 14 BE1 CDS240 Installation 9365200990 Rev F ...

Page 359: ...Figure 12 15 Typical AC Connection 4 Restraint Windings 1 IG without Voltage Protection 9365200990 Rev F BE1 CDS240 Installation 12 15 ...

Page 360: ...Figure 12 16 Typical Application Two winding Transformer with 4 Restraint Connections 12 16 BE1 CDS240 Installation 9365200990 Rev F ...

Page 361: ...Figure 12 17 Typical DC Connection Diagrams 9365200990 Rev F BE1 CDS240 Installation 12 17 ...

Page 362: ...12 19 D2877 06 07 17 00 Figure 12 18 Standard CT Polarity Figure 12 19 Current Transformer Action On occasion however protection engineers will encounter situations where CT polarity is reversed for a specific application That is non polarity of the CT secondary will be in phase with the primary current flow Figure 12 20 For example a transformer differential CT from a breaker with a different pol...

Page 363: ...ential System Many of these applications can be used in concert with other Basler numeric systems such as the BE1 851and BE1 951 Overcurrent Protection System the BE1 CDS220 Current Differential System or the BE1 GPS100 Generator Protection System Figure 12 21 Three phase Voltage Sensing Alternate VTP Input 9365200990 Rev F BE1 CDS240 Installation 12 19 ...

Page 364: ...Figure 12 22 BE1 CDS240 Connected for Primary Protection BE1 851 Connected for Independent Backup 12 20 BE1 CDS240 Installation 9365200990 Rev F ...

Page 365: ...Figure 12 23 BE1 CDS240 Percentage Differential Bus Protection 9365200990 Rev F BE1 CDS240 Installation 12 21 ...

Page 366: ...Figure 12 24 Typical Connection for Motor Generator or Reactor Differential Protection 12 22 BE1 CDS240 Installation 9365200990 Rev F ...

Page 367: ...S240 Connected for Primary Current Differential Voltage and Frequency Protection and Metering BE1 GPS100 Connected for Independent Backup Fault Protection Detection of Abnormal Situations and Backup Monitoring 9365200990 Rev F BE1 CDS240 Installation 12 23 ...

Page 368: ...ensing 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 information about customizing preprogrammed logic and creating user defined logic and Section 8 Application for information about the application of preprogrammed logic schemes COMMUNICATIONS CONNECTIONS The ...

Page 369: ...1 CDS240 P0052 99 View looking into female connector Figure 12 26 RS 232 Pinouts Figure 12 27 Personal Computer to BE1 CDS240 Figure 12 28 Modem to BE1 CDS240 9365200990 Rev F BE1 CDS240 Installation 12 25 ...

Page 370: ...th a standard communication cable A twisted pair cable is recommended Connector pin numbers functions names and signal directions are shown in Table 12 3 An RS 485 connection diagram is provided in Figure 12 31 Table 12 3 RS 485 Pinouts COM 2 Terminal Function Name Direction B8 A Send Receive A SDA RDA In Out B7 B Send Receive B SDB RDB In Out B6 C Signal Ground GND N A 12 26 BE1 CDS240 Installati...

Page 371: ...e maximum acceptable input voltage range is 10 volts or 10 volts a 20 volt range Input burden is nonlinear and rated at approximately 4 k at 3 5 Vdc and approximately 3 k at 20 Vdc IRIG connections are located on a terminal block shared with the RS 485 and input power terminals Terminal designations and functions are shown in Table 12 4 Table 12 4 IRIG Terminal Assignments Terminal Function A1 Sig...

Page 372: ...12 28 BE1 CDS240 Installation 9365200990 Rev F This page intentionally left blank ...

Page 373: ...erify Other Set Points as Appropriate 13 22 Digital I O Connection Verification 13 22 Virtual 43 Switches 13 23 Virtual 101 Switches 13 24 Reporting and Alarm Functions 13 24 In Service Current Circuit Verification 13 26 PERIODIC TESTING 13 30 Settings Verification 13 30 Digital I O Connection Verification 13 30 Analog Circuit Verification 13 30 MAINTENANCE OF BACKUP BATTERY FOR REAL TIME CLOCK 13...

Page 374: ... Timing Example 13 85 Tables Table 13 1 Voltage Input 13 5 Table 13 2 Contact Sensing Turn On Voltage 13 6 Table 13 3 Circuit 1 Metering Quantities 13 8 Table 13 4 Circuit 2 Metering Quantities 13 8 Table 13 5 Circuit 3 Metering Quantities 13 9 Table 13 6 Circuit 4 Metering Quantities 13 9 Table 13 7 Circuit 5 Metering Quantities Virtual Current 13 9 Table 13 8 Circuit 6 Metering Quantities Virtua...

Page 375: ... V Hz Alarm Integrating Time and Definite Time Test Commands 13 64 Table 13 59 Alarm Integrating Time and Definite Time Pickup Settings Step 2 13 64 Table 13 60 Alarm Integrating Time and Definite Time Pickup Settings Step 11 13 65 Table 13 61 V Hz Trip Time Settings 13 65 Table 13 62 V Hz Trip Times 13 65 Table 13 63 V Hz Reset Time Pickup Settings 13 66 Table 13 64 V Hz Reset Time 13 66 Table 13...

Page 376: ...4 x62 Mode 5 Test Commands 13 83 Table 13 105 x62 Mode 5 Timer Initiate Commands 13 83 Table 13 106 x62 Mode 6 Test Commands 13 84 Table 13 107 x62 Mode 6 Timer Initiate Commands 13 85 Table 13 108 Automatic Setting Group Change Function Test Commands 13 86 Table 13 109 Automatic Group Control Selection 13 87 Table 13 110 Time Overcurrent 51P Element Pickup Settings 13 87 Table 13 111 Automatic Se...

Page 377: ...ill remain intact and precise during shipping The BE1 CDS240 relay is a microprocessor based relay whose operating characteristics will not change over time The relay will not experience changes in operating characteristics during transit However it remains material that you perform these basic acceptance tests to verify the device has not suffered any degradation in transit Basler Electric warran...

Page 378: ... this application It is beyond the scope of this manual to develop performance tests for this device For assistance in developing these types of tests please consult Basler Electric and your test equipment manufacturer TESTING AND TROUBLESHOOTING AIDS Under test or in service the BE1 CDS240 provides several ways to check operations targets or events A continuous self test monitors the system healt...

Page 379: ...ion set in the SG TRIGGER command STAT TARGETS DETAILS Screen 1 1 1 Provides target data STAT ALARMS Screen 1 2 1 Provides alarm data including BKR FAIL REC FAIL and REC LO REPRT FAULT M_REC DETAILS Screen 4 1 1 1 Provides targets and fault summary data REPRT SEQ Screen 4 2 Provides the number of new events logged by the SER since the last new counter reset resettable only through ASCII command RS...

Page 380: ...Figure 13 1 Horizontal or Vertical Rear View Terminal Connections I O Option A Shown 13 4 BE1 CDS240 Testing and Maintenance 9365200990 Rev F ...

Page 381: ...cation default settings for terminal emulation are Baud Rate 9 600 bps Data Bits 8 Stop Bit 1 Parity none Flow Control Xon Xoff See Appendix C for more information on Terminal and HyperTerminal setups for Windows operating systems Note The preferred method to communicate is by using Basler Terminal which can be accessed through BESTCOMS by clicking on the Communications tab and then Terminal VT100...

Page 382: ...ontrol output changes Contact Sensing Inputs and Control Outputs Purpose To verify that the BE1 CDS240 relay senses hardware inputs and activates contact outputs Reference Commands ACCESS CO OUT CS OUT EXIT RG STAT NOTE Each BE1 CDS240 relay is delivered with the eight sensing jumpers installed for operation in the higher end of the control voltage range For contact sensing inputs at the lower end...

Page 383: ...separate events Step 8 Repeat Step 6 for all desired output 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 measure currents and polarities Reference Commands M I SG TARG SG TRIGGER RS For all tests in this section ASCII metering commands HMI Metering and the Metering Scree...

Page 384: ...0 0 0 A 1 1 A 1 0 A 1 0 o 3 0 A 1 0 0 0 A 1 Step 4 Transmit the command M2 I to the relay or navigate to the front panel HMI Screen METER CRNT CT_2 I_MEAS 3 2 2 1 and METER CRNT CT_2 I_CALC 3 2 2 2 and verify the values listed in Table 13 4 Table 13 4 Circuit 2 Metering Quantities CT Secondary IA2 IB2 and IC2 IN2 IQ2 5 A 5 0 A 1 180 o 15 0 A 1 180 0 0 A 1 1 A 1 0 A 1 180 o 3 0 A 1 180 0 0 A 1 Step...

Page 385: ... 60 0 A 1 0 0 0 A 1 Step 8 Transmit the command M6 I to the relay or navigate to the front panel HMI Screen METER CRNT CT_6 I_MEAS 3 2 6 1 and METER CRNT CT_2 I_CALC 3 2 6 2 and verify the values listed in Table 13 8 Table 13 8 Circuit 6 Metering Quantities Virtual Current CT Secondary CT CKT 3 4 IA6 IB6 and IC6 IN6 IQ2 5 A 5 0 A 1 180 o 15 0 A 1 180 0 0 A 1 1 A 1 0 A 1 180 o 3 0 A 1 180 0 0 A 1 S...

Page 386: ...Table 13 9 Voltage Circuit Verification Values Measured Voltage Applied Voltage Lower Limit Upper Limit 80 volts 79 2 V 80 8 V 100 volts 99 0 V 101 0 V 120 volts 118 8 V 121 2 V 140 volts 138 6 V 141 4 V 160 volts 156 8 V 163 2 V Power Reading Verification Use the same voltage connections as in the previous test polarity voltage jumpered to B9 B10 and B11 neutral tied to B12 Use the same current c...

Page 387: ...esting process begins When testing is complete the saved copy could then be loaded into the relay which would guarantee that no setting changes or testing modifications would remain in the relay To assist you in the commissioning testing of this relay refer to the previous paragraphs in this section on Testing and Troubleshooting Aids and Section 6 Reporting and Alarm Functions for various ways to...

Page 388: ...re starting the test You will refer to these settings throughout the test procedure Angle Compensation and Ground Source compensation can be determined by matching the SG CTP 1 2 3 or 4 settings or Screen 6 3 1 1 with Table 3 3 in Section 3 and reading the right two columns to determine what angle compensation is applied Tap Compensation settings in each setting group can be determined from Screen...

Page 389: ...alanced 180 out of phase single phase input currents that we apply to the two phase A connections will result in balanced currents in the 87A element However the 87C element will also see a compensating IA2 current that will cause it to operate Table 13 11 shows the compensated currents that with the various compensation settings will be applied to each 87 phase element The relay can also remove t...

Page 390: ...P 0 Return relay to Setting Group 0 CS GROUP L CO GROUP L Return setting group control to logic control E Exit Table 13 11 Phase and Zero 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 IA IA I0 IB IB I0 IC IC I0 WYE NONE DAB IA IA IB 3 IB IB IC 3 IC IC...

Page 391: ...Record the phases that will respond to the test Table 13 12 Differential Element Minpu Response to IA Test Current CT Input Compensation Element Angle Comp Ground Source 87A 87B 87C Wye None 0 No Minpu Tap N a N a Wye None 1 Yes 1 5 Minpu Tap 3 Minpu Tap 3 Minpu Tap DAB N a 3 Minpu Tap N a 3 Minpu Tap DAC N a 3 Minpu Tap 3 Minpu Tap N a Table 13 13 Differential Element Minpu Response to IB Test Cu...

Page 392: ... be applied to each input circuit of the relay Use the appropriate equation from Table 13 11 Test Current and record values before starting the test The equations provide a convenient starting balance point at two times tap Do this for each setting group Step 4 3 Check that the starting balanced test current at two times tap is not above the maximum continuous current rating of the relay If it is ...

Page 393: ...E G 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 13 8 A Y N Y DAB WYE 2 3 tap 2 tap 13 8 B Y Y N DAB WYE 2 3 tap 2 tap 13 8 C N Y Y DAB WYE G 2 3 tap 2 tap 13 8 A Y N Y DAB WYE G 2 3 tap 2 tap 13 8 B Y Y N DAB WYE G 2 3 tap 2 tap 13 8 C N Y Y D...

Page 394: ... IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 A B C D2857 26 vsd 05 05 00 Figure 13 4 Test Connection Diagrams for Table 13 15 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1...

Page 395: ...C2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 A B C Figure 13 7 Test Connection Diagrams for Table 13 15 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X...

Page 396: ...2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 A B C D2857 32 vsd 05 05 00 Figure 13 10 Test Connection Diagrams for Table 13 15 D2857 33 vsd 05 05 00 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X3 X4 IC2 X13 X14 IC1 X5 X6 IA2 X9 X10 IA1 X1 X2 IB2 X11 X12 IB1 X...

Page 397: ...s targeted and if the test was passed The accuracy should be 4 of the setting or 0 75 milliamperes whichever is greater for 5 ampere units and 4 or 25 milliamperes whichever is greater for 1 ampere units Step 7 Repeat for each set of input pairs CT1 CT3 CT1 CT4 CT2 CT3 CT2 CT4 and CT3 CT4 Phase Differential Unrestrained Trip The following test is similar to the restrained minimum pickup test For t...

Page 398: ...T to retrieve INPUT 12345678 information Or alternatively 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 Output Contacts Purpose To verify output settings and connections Reference Commands SN VO SL VO SG HOLD Step 1 Verify output settings Transmit the SN VOA command to verify th...

Page 399: ... OUT12 N O C28 and C29 CS OUT12 P CO OUT12 P OUT13 N O C30 and C31 CS OUT13 P CO OUT13 P OUT14 N O C32 and C33 CS OUT14 P CO OUT14 P Virtual 43 Switches Purpose To verify the operation labels and logic settings of the virtual 43 switches Reference Commands SN 43 SL 43 RG 43STAT RG STAT CS CO 43 NOTE If virtual 43 switches are not used skip the eight associated steps and go to the next test Step 1 ...

Page 400: ... command won t be executed Step 5 Verify the switch position change as you did in Step 3 Step 6 Repeat Step 4 to return the x101 Switch to the desired position for your application Step 7 Verify the x101 switch activity by viewing the sequence of events reports with the RS command Reporting and Alarm Functions Just prior to placing the relay in service the following reporting and alarm functions s...

Page 401: ...eset a relay Major Minor Logic alarm first gain write access to the reporting functions R password and then initiate the RA 0 or RA MAJ MIN LGC 0 commands or press the Reset key while the front panel HMI Screen 1 2 1 STAT ALARMS DETAILS is displayed Purpose To verify that all Major Minor Logic Programmable alarms are cleared and no alarms are active before initially loading the system Reference Co...

Page 402: ...ion for information on retrieving and resetting SER records In Service Current Circuit Verification To verify correct CT circuit connections internal phase zero sequence and tap compensation settings for the differential functions it is recommended 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 Func...

Page 403: ... the trip If it is not a fault re energize the transformer and pick up less of a load or block the differential trip re energize the transformer and pick up the load After the load is picked up trigger a differential check record Once the problem has been corrected unblock the differential element A Microsoft Excel spreadsheet template CDSFAULT xlt is available from the web site www basler com The...

Page 404: ...O NO 16 700 CT CKT4 DAB NO NO YES 2 000 ALARMS PHASE A PHASE B PHASE C DIFFERENTIAL OK OK OK LOW CURRENT NO NO NO POLARITY OK OK OK ANGLE COMP OK OK OK MISMATCH OK OK OK MEASUREMENTS PHASE A PHASE B PHASE C MEASURED PRI I CT CKT1 167 0 167 240 167 120 CT CKT2 201 180 201 60 201 300 CT CKT3 126 150 126 30 126 270 CT CKT4 54 180 54 60 54 300 MEASURED SEC I CT CKT1 0 84 0 0 84 240 0 84 120 CT CKT2 1 ...

Page 405: ...atch 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 Tap Comp I For each phase determine if the currents are approximately the same magnitude for each CT input circuit and approximately 180 degrees out of phase Some small amount of mismatch is expected due to excitation and possible LTC or other tap adj...

Page 406: ...ished in several ways depending upon the user s preferences and practices Repeating the digital I O connection verification commissioning tests Monitoring SER Status and Fault reports for proper sensing of digital signals and proper tripping during normal operation NOTE If protection systems are redundant such that multiple relays will trip a given breaker or device for a fault simply monitoring f...

Page 407: ...95 Ah battery Basler p n 9318700012 or Applied Power p n BM551902 Use the following instructions to replace the battery Step 1 Remove the unit from the case Step 2 Disconnect the battery cable Step 3 Locate the battery The battery is located on the bottom side of a horizontal unit or the left side of a vertical unit See Figures 13 12 and 13 13 for battery location Step 4 Using a 5 16 nut driver re...

Page 408: ...re the latest version of BESTCOMS software should also be obtained Updating Relay Firmware If a firmware upgrade is desired you may request a CD ROM containing the latest firmware or download the firmware from the Basler Electric website Direct your web browser to http www basler com BE1_Firm and complete the on line form to request a CD ROM containing the latest firmware or a password for downloa...

Page 409: ... output can be mapped to any hardware output For ease of testing map each Virtual Output VO1 through VO14 to hardware Outputs OUT1 through OUT14 prior to beginning tests This is accomplished by entering SL OUT1 VO1 SL OUT2 VO2 etc and entering exit E and Yes to save Phase Differential 87 The CDS240 is a four winding differential relay Testing the complete 87T scheme would require 12 controllable c...

Page 410: ...ess S TAP87 MANUAL 5 00 5 00 Set TAP 1 5 00 and TAP 2 5 00 E Exit Y Save settings Step 4 Apply current to phase A input 1 and slowly ramp up until OUT1 closes The relay should pickup at a value of minimum pickup x TAP see Figure 13 14 13 34 BE1 CDS240 Testing and Maintenance 9365200990 Rev F 1 2 3 4 5 RESTRAINT CURRENT IN MULTIPLES OF TAP OPERATING CURRENT IN MULTIPLES OF TAP 1 2 3 minimum pickup ...

Page 411: ...00 10 40 A1 A3 A4 0 10 1 00 1 00 0 10 0 075 0 125 B1 A5 A6 0 50 1 00 1 00 0 50 0 475 0 525 C1 A7 A8 1 00 1 00 1 00 1 00 0 960 1 040 A2 A9 A10 0 10 1 00 2 00 0 20 0 175 0 225 B2 A11 A12 0 50 1 00 2 00 1 00 0 960 1 040 C2 A13 A14 1 00 1 00 2 00 2 00 1 952 2 080 A3 A15 A16 0 10 1 00 2 00 0 20 0 175 0 225 B3 A17 A18 0 50 1 00 2 00 1 00 0 960 1 040 C3 A19 A20 1 00 1 00 2 00 2 00 1 952 2 080 A4 A21 A22 ...

Page 412: ...Input 1 and a second current source to terminals A9 and A10 A phase input 2 Ensure that the two current sources are 180o out of phase See Figure 13 15 for a connection diagram An ohmmeter or continuity tester may be used to monitor output contact status Step 2 Send the commands listed in Table 13 22 to the relay to prepare the 87 elements for pickup testing Table 13 22 Commands To Prepare For Pick...

Page 413: ...reater than or equal to the minimum pickup operate setting Beyond the knee of the curve the differential current operating characteristic is defined along the slope portion of the curve The BE1 CDS240 relay has two distinct operating principles for performing the restraint operation Maximum restraint uses the maximum of the two compensated currents as the restraint while average restraint uses the...

Page 414: ...RAINT CURRENT IN MULTIPLES OF TAP OPERATING CURRENT IN MULTIPLES OF TAP 1 2 3 Slope minimum pickup increasing current from balance decreasing current from balance D2857 13 vsd 10 14 99 In order to test the restrained pickup function of the BE1 CDS240 relay you may increase one of two currents initially applied in balance to create an operate imbalance In this narrative the Input 1 current will be ...

Page 415: ...e and four winding applications TAP 1 2 00 Minpu 0 30 TAP 2 3 80 Slope 15 Input 1 current at balance 3 per unit 6 amperes Input 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 per unit Irestraint at balance 3 0 3 1 15 0 1 1 70 per unit 9365200990 Re...

Page 416: ...creased the operate current plotted against the restraint current will be a vertical line on the operating 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 restraint operating characteristic Step 4 Send the commands listed in Table 13 24 to the relay Tabl...

Page 417: ...ecreasing Input 2 From Balance Pickup A 0 35 15 0 40 1 0 76 1 0 54 0 025 0 49 0 025 0 35 15 2 00 5 3 80 5 2 35 0 094 3 23 0 129 0 35 30 0 40 1 0 76 1 0 57 0 025 0 49 0 025 0 35 30 2 00 5 3 80 5 2 86 0 114 2 66 0 106 0 35 45 0 40 1 0 76 1 0 73 0 029 0 42 0 025 0 35 45 2 00 5 3 80 5 3 64 0 146 2 09 0 084 0 35 60 0 40 1 0 76 1 1 00 0 040 0 30 0 025 1 0 35 60 2 00 5 3 80 5 5 00 0 200 1 52 0 061 Step 8...

Page 418: ...AINT CURRENT IN MULTIPLES OF TAP OPERATING CURRENT IN MULTIPLES OF TAP 1 2 3 D2857 14 vsd 10 15 99 increasing current from balance decreasing current from balance 13 42 BE1 CDS240 Testing and Maintenance 9365200990 Rev F Slope minimum pickup Average Restraint Operating Characteristic Sidebar 13 6 Average Restraint when Increasing One Input from Balance In order to test the restrained pickup functi...

Page 419: ...xed Input 2 current Irestraint at balance 3 0 3 5 0 15 0 1 1 85 per unit Then I1trip I2balance 1 2 100 slope 2 100 slope 3 1 0 30 1 85 3 486 per unit Irestraint 2 2 I 1 I 3 0 3 486 2 6 486 2 3 243 per unit see the following figure 1 2 3 4 5 AVERAGE RESTRAINT CURRENT IN MULTIPLES OF TAP OPERATING CURRENT IN MULTIPLES OF TAP 1 2 3 Slope IOP 100 IRESTR 15 minimum pickup 0 30 x tap Differential curren...

Page 420: ...pu is the minimum pickup setting Under test and in service conditions the following equations determine whether the relay operates along the flat minimum pickup or slope of the operating characteristic If Irestraint at balance minpu x 2 1 100 1 slope in per unit use the 1st equation or if Irestraint at balance minpu x 2 1 100 1 slope in per unit use the 2nd equation Step 13 Send the commands liste...

Page 421: ... 0 63 0 025 0 481 0 025 1 0 35 45 2 00 5 3 80 5 3 16 0 126 2 406 0 096 1 0 35 60 0 40 1 0 76 1 0 74 0 030 0 408 0 025 1 0 35 60 2 00 5 3 80 5 3 71 0 148 2 046 0 082 Step 15 Repeat for all values and optionally reconnect to phases B and C inputs 1 and 2 when advancing through the set of test values in the table It is not necessary to test each phase at all the values listed to verify the response o...

Page 422: ...Irestraint at balance minpu x 1 100 slope 1 in per unit 1 0 35 1 0 15 1 0 35 5 67 1 98 per unit where the operating point is on the flat part of the curve Thus we use the following to derive the trip condition Notice the added multiples of tap variable that we know in this case is 1 5 times tap or 1 5 per unit I2trip min I2balance minpu multiples of tap in per unit I2trip min 1 0 35 1 5 1 53 per u...

Page 423: ...ange was initiated to the time OUT1 output contact closes the restrained trip 87RT Step 5 Reduce the current to Input 2 until OUT1 Contact opens Step 6 Apply 1 multiple of tap current 2 amperes to both A phase Input 1 and A phase Input 2 at 180o phase relation to Input 1 Step 7 To force a restrained trip at 5 times pickup you must apply a step change in the current on input 2 to 8 0 amperes This v...

Page 424: ...to the relay to setup a test of the pickup of the second harmonic restraint elements Table 13 34 Second Harmonic Restraint Elements 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 2HAR Sets 2HAR as custom logic name SL 87 1 0 Enables 87 SL VO1 87RT Enables OUT1 to close with 87 restrained trip SG CT2 ...

Page 425: ...or harmonic sharing in the S 87 command the last 1 in the string in Step 2 the harmonic content on all phases is shared or summed This magnitude is used by the second harmonic comparators for each phase Thus the same operation will occur regardless of which phase of the 120 hertz test current is applied Step 9 Optional Repeat Steps 2 through 8 for Setting Groups 1 through 3 using the CS CO GROUP c...

Page 426: ...function restrains operation at the expected value based on settings from Step 2 Step 8 Optional Repeat Steps 2 through 7 for phases B and C Step 9 Optional Repeat Steps 2 through 8 for Setting Groups 1 through 3 using the CS CO GROUP command to change setting groups Step 10 Optional Repeat for each pair of CT inputs CT1 CT3 CT1 CT4 CT2 CT3 CT2 CT4 and CT3 CT4 Unrestrained Pickup Verification Purp...

Page 427: ...ional Repeat Steps 1 through 5 for phases B and C Step 7 Optional Repeat Steps 2 through 6 for Setting Groups 1 through 3 using the CS CO GROUP command to change setting groups Step 8 Optional Repeat for each pair of CT Inputs CT1 CT3 CT1 CT4 CT2 CT3 CT2 CT4 and CT3 CT4 Unrestrained Time Verification A timing circuit or a contact monitor with timing algorithm must be used to time the output contac...

Page 428: ...een the time the step change was initiated to the time OUT1 output contact closes the unrestrained trip 87UT Step 9 Reduce the current to Input 2 until OUT1 contact opens Step 10 The time measured in Steps 4 and 8 should be less than those shown in Table 13 39 Table 13 39 Restrained Trip Operate Times Function Differential current Time Unrestrained trip 1 5 times pu Less than 2 cycles Unrestrained...

Page 429: ...und source SG CTG 1 Ground input ctr 1 SG TRIGGER 87NDT 87NDPU 0 Enable 87NDT to log and trigger fault recording S 87ND 0 1 15 50m Minpu 0 1 slope 15 50 ms minimum time delay E Exit Y Save settings NOTE With the relay in service it is necessary to view the 87ND tap factors by accessing the HMI Screen PROT SGn 87ND 87ND Step 3 The relay auto tap compensation logic will calculate TAPN and TAPG value...

Page 430: ...that pickup occurred within the specified accuracy of the relay Step 6 Decrease the current to the ground input until the relay drops out Step 7 Repeat for all other values shown in Table 13 41 by substituting for minpu in the S x87ND command or by navigating to Screen PROT SGn 87ND 87ND and editing the MIN PICKUP value Table 13 41 Minimum Pickup Accuracy Limits 87ND Sensing Type MINPU X TAP Calcu...

Page 431: ...ip SG CT2 1 WYE NA 0 Input 2 ctr 1 ct wye xfmr na no grd source SG TRIGGER x87NDT x87NDPU 0 Enable 87NDT to log and trigger fault recording S x87ND 0 35 15 50m Minpu 0 35 slope 15 minimum time delay E Exit Y Save settings NOTE The ground differential function always uses the maximum restraint principle as its operating characteristic Thus the slope setting is simply a number between 15 and 60 Step...

Page 432: ...th methods are shown for convenience and either method may be used For differences in measurement of the two methods refer to the paragraphs in this section Functional Testing Restrained Pickup and Sidebar 13 3 Maximum Restraint Operating Characteristic Table 13 43 Restraint Pickup Test Points 87ND 5 Ampere Sensing Input Neutral Input 2 Ground Calc Tap 2 00 Calc Tap 2 00 Sensing Input Type Minimum...

Page 433: ... 550T 650T 750T SL GROUP SL VO Step 1 Connect a current source to Terminals A3 and A4 A phase Input 1 Step 2 To initially prepare the 50T 150T 250T 350T 450T 550T 650T 750T elements for testing transmit the commands in Table 13 45 to the relay Table 13 45 50T 150T 250T Overcurrent Test Commands Command Purpose A Gain access SL N NONE Zero out custom logic settings overwrite with logic None setting...

Page 434: ... nominal systems 2 of setting or 10 milliamperes D E or F 5 ampere nominal systems 2 of setting or 50 milliamperes Step 5 After pickup occurs slowly ramp the current down until OUT1 OUT2 and OUT3 open Verify that dropout occurred as specified 95 2 Step 6 Repeat Steps 3 4 and 5 for all values in Table 13 47 Optionally reconnect the current source to B phase A5 A6 and C phase A7 A8 inputs to test th...

Page 435: ...he basic information in Table 13 46 program the pickup of the elements for Setting Group 1 and optionally proceed with Group 1 testing Sidebar 13 10 Negative Sequence Overcurrent Element Pickup A three phase electric power system can be modeled using a set of balanced equations known as symmetrical components These components provide a practical method of analyzing power system operation during un...

Page 436: ... 2 To initially prepare the x51 elements for pickup and dropout testing send the commands in Table 13 50 to the relay Table 13 50 51 151 251 Time Overcurrent Test Commands Command Purpose A Gain access SL N NONE Zero out custom logic settings overwrite with logic None settings Y Confirm overwrite SL N 51 Name custom logic for this test SL 51 1 0 Enables 51P 51N 51Q CT Input 1 SL VO1 51PT Enables O...

Page 437: ...ests SL 51 1 0 SL 151 1 0 SL VO1 51PT SL VO1 151PT SL VO2 51NT SL VO2 151NT SL VO3 51QT SL VO3 151QT SG TARG 51 SG TARG 151 SG TRIGGER 51PT 51NT 51QT 51PPU 51NPU 51QPU 0 SG TRIGGER 151PT 151NT 151QT 151PPU 151NPU 151QTPU 0 Table 13 54 Time Overcurrent 251 351 451 Element Test Logic Replace These Commands With These Commands For x51 Element Tests where x 2 3 4 SL 51 1 0 SL x51 1 0 SL VO1 51PT SL VO...

Page 438: ...T1 to close for 50P trip SL VO2 51NT Enables OUT2 to close for 51N trip SL VO3 51QT Enables OUT3 to close for 51Q trip SG CT1 1 WYE NA 0 Input 1 ctr 1 ct wye xfmr n a no ground source SG 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 commands S0 51P fr...

Page 439: ...eat Steps 1 through 8 for the 51 151 251 351 and 451 elements in Setting Groups 1 2 and 3 Use the following information as a guide to program the 51 151 251 351 451 elements in higher order setting groups In order to program the pickup of the elements in a higher order setting group you would replace the 0 in the S0 51P S0 51N and S0 51Q commands in Table 13 50 with either a 1 2 or 3 for Setting G...

Page 440: ...t 24 Integrating PU at 1 05 of nominal 2 10 V Hz Trip Time Dial 0 Reset Time Dial 0 time curve exponent 2 S0 24D 0 0 50ms 0 0 50ms Sets 24 definite pickups at 0 and time definite time delay at minimum Step 3 Prepare to monitor the operation of the 24 Alarm and Trip functions Alarm operation can be verified by monitoring the Major Alarm LED on the relay s front panel Operation of 24T by can be veri...

Page 441: ...me curve exponent 2 Step 2 Connect a 120 Vac three phase 50 or 60 hertz voltage source depending on user s nominal frequency to Terminals B9 A phase B10 B phase B11 C phase and B12 neutral Refer to Figure 13 1 for terminal locations Step 3 All integrating timing tests are based on of nominal Volts Hertz 1 PU value Refer to Appendix C of the BE1 CDS240 instruction manual for time curves Apply A pha...

Page 442: ...e Dial 1 0 Time Dial 2 0 120 12 5 seconds 25 seconds 50 seconds Step 4 Repeat Step 3 for Trip Time Dial 1 0 and 2 0 trip time is approximately 12 5 seconds for Time Dial 1 0 and 25 seconds for Time Dial 2 0 Still reapply voltage after 5 seconds as reset time dial is still 0 2 Step 5 Optional Repeat Steps 2 through 4 for the B phase and C phase voltage inputs Step 6 Optional Repeat Steps 2 through ...

Page 443: ...with logic None settings Y Confirm overwrite SL N 27_59 Sets 27_59 as custom logic name SG VT 1 4W PN PN Set VT phase voltage parameters SA MAJ 0 Disables major Alarm SL 27 1 0 Enables 27P disables blocking SL 59 1 0 Enables 59P disables blocking SL VO1 27T 59T Enables OUT1 to close for 27 or 59 trip SG TRIG 27T 59TU 27PU 59PU 0 Enables 27 and 59 to log and trigger fault record EXIT Y Exit and sav...

Page 444: ...t 156 V Sets 27 TD 59P TD at 2 seconds S0 27 5s S0 59 5s Sets 27 TD 59P TD at 5 seconds S0 27 10s S0 59 10s Sets 27 TD 59P TD at 10 seconds Step 2 Prepare to monitor the 27 and 59 timings Timing accuracy is verified by measuring the elapsed time between a sensing voltage change and OUT1 closing Step 3 Connect and apply a 120 Vac three phase voltage source to terminals B9 A phase B10 B phase B11 C ...

Page 445: ...s Pickup should occur within 2 percent or 1 volt of the pickup setting Slowly decrease the A phase voltage until OUT1 opens Dropout should occur between 97 and 98 percent of the actual pickup value Verify the 47 target on the HMI Step 6 Verify the pickup and dropout accuracy of the middle and upper 47 pickup settings Step 7 Optional Repeat Steps 2 through 6 for the B phase and C phase voltage inpu...

Page 446: ...ing SL 481 1 0 Enables 481 disables blocking SL 581 1 0 Enables 581 disables blocking SL VO1 81T 581T Enables OUT1 to close for 81 or 581 trip SL VO2 181T Enables OUT2 to close for 181 trip SL VO3 281T Enables OUT3 to close for 281 trip SL VO4 381T Enables OUT4 to close for 381 trip SL VO5 481T Enables OUT5 to close for 481 trip EXIT Y Exit and save settings Step 2 Transmit the commands in Table 1...

Page 447: ... 581 TD Step 2 Prepare to monitor the x81 timings Timing accuracy is verified by measuring the elapsed time between a frequency change and programmed output closing Step 3 Connect and apply a 120 Vac 60 hertz voltage source to terminals B9 A phase and B12 Neutral Step 4 Step the frequency of the applied voltage down from 60 hertz to a value below the 281 underfrequency setting Measure the time del...

Page 448: ...ailure Timer This input is also used to start the test set timer and OUT1 of the relay is used to stop the test set timer OUT2 should be monitored to verify operation of the re trip circuit upon breaker failure initiate Step 3 With no wetting voltage to relay Input IN1 switch on the wetting voltage to IN2 and measure the operate time Timer Accuracy 0 5 or cycles whichever is greater Step 4 Apply w...

Page 449: ... range fault current must be above the 50TP pickup setting to get a BFI 50 initiate and all must occur within the set Control Time including Breaker Failure Time Delay If the Control Timer expires before BFT1 goes TRUE BFT is blocked and the Breaker Failure alarm becomes TRUE Step 9 Connect a current source to terminals A3 and A4 A phase input Current Circuit 1 Apply 50 of nominal current to the r...

Page 450: ...and A4 A phase input Current Circuit 1 Apply nominal current to the relay and note operation of OUT3 and no operation of OUT1 and 2 To verify control time apply nominal current and start the test set timer Use OUT3 to stop the timer Timer Accuracy 0 5 or cycles whichever is greater Step 16 Optional Repeat Steps 3 through 9 for the phase B and phase C elements Step 17 Repeat Steps 1 through 10 for ...

Page 451: ...ate Step 4 Transmit the commands in Table 13 84 to the relay or navigate to Screen CTRL 43 43 to set the mode of the 43 Switch to the FALSE state logic 0 It is not necessary to gain access for the following steps unless access times out Result OUT1 contact opens and remains open Table 13 84 Mode 1 Test Commands Command Purpose CS 43 0 Selects Virtual Switch 43 for change to open False state CO 43 ...

Page 452: ...S 143 1 Selects Virtual Switch 143 for change to closed True state CO 143 1 Executes Virtual Switch 143 for change to closed True state Step 4 Send the commands in Table 13 88 to the relay or navigate to Screen CTRL 43 143 to set the mode of the 143 Switch to the FALSE state logic 0 It is not necessary to gain access for the following step unless access times out Result OUT1 contact opens and rema...

Page 453: ...are for 101 Virtual Breaker Control Switch testing by sending the commands in Table 13 91 to the relay Table 13 91 101 Virtual Breaker Control Switch Test Commands Command Purpose A Gains write access SL N NONE Zero out custom logic settings Overwrite with logic None settings Y Confirm overwrite SL N S101 Sets S101 as custom logic name SL 101 1 Enables 101 Switch SL VO1 101T Enables OUT1 to close ...

Page 454: ...y Table 13 94 x101 Virtual Breaker Control Switch Test Commands Command Purpose A Gains write access SL N NONE Zero out custom logic settings Overwrite with logic None settings Y Confirm overwrite SL N Sx101 Sets Sx101 as custom logic name SL x101 1 Enables x101 Switch SL VO1 x101T Enables OUT1 to close for x101T TRUE SL VO2 x101C Enables OUT2 to close for x101C TRUE SL VO3 x101SC Enables OUT3 to ...

Page 455: ...itches Logic Timer Verification 62 162 262 362 Mode 1 Pickup Dropout Purpose To verify the operation of the 62 timer elements Reference Commands SL 62 162 262 362 S g 62 162 262 362 Step 1 Prepare for Mode 1 logic timer verification testing by sending the commands in Table 13 97 to the relay Table 13 97 x62 Mode 1 Test Commands Command Purpose A Gains write access SL N NONE Zero out custom logic s...

Page 456: ...pped out approximately 2 000 milliseconds later The state of the 43 switches in the SER report use the programmable name parameters applied to the switch Figure 13 19 illustrates the timing relationship of the 43 Switch and 62 Timer 400 ms 43 D2595 02 vsd 08 10 00 PU DO 1 0 x62 400 ms 2 000 ms Figure 13 19 x62 Mode 1 Pickup Dropout Timing Example Mode 2 One Shot Nonretriggerable Step 1 Prepare for...

Page 457: ... command to retrieve logic variable data from the SER Verify that a 143 pulse action FALSE TRUE FALSE was logged and that approximately 400 milliseconds after the initial 143 FALSE TRUE FALSE initiate signal action the 162 Timer output went TRUE Then approximately 20 seconds later duration timer T2 expired and the timer output went FALSE despite a second 143 FALSE to TRUE initiate signal while the...

Page 458: ...ty is encountered with repeating the 343 Switch actions Table 13 103 x62 Mode 3 Timer Initiate Commands Command Purpose A Gains write access CS 343 P Selects 343 for pulse operation CO 343 P Executes 343 for pulse operation CS 343 P Selects 343 for pulse operation CO 343 P Executes 343 for pulse operation Wait at least 15 seconds but no longer than 35 seconds to execute the next commands CS 343 P ...

Page 459: ...de SN 43 62_INI PU DO Name switch to make SER easier to read SL 62 5 43 0 Enables 62 integrating mode 43 initiate no blocking S0 62 15s 5s Sets T1 at 15 seconds T2 at 5 seconds EXIT Exit Y Save settings NOTE The CS and CO commands of Table 13 100 are performed three times Follow the timing sequence to illustrate timer mode action The time delay settings may be increased if difficulty is encountere...

Page 460: ... FALSE state 15 s 5 s 5 s 43 BLK Timer x62 1 1 1 100 0 0 0 0 D2595 05 cdr 07 19 00 Figure 13 22 x62 Mode 5 Integrating Timing Example Step 4 Optional Repeat the 62 Timer tests for Modes 1 2 3 and 5 for Setting Groups 1 2 and 3 Mode 6 Latch Timer Step 1 Prepare for mode 6 logic timer verification testing by sending the commands in Table 13 106 to the relay Table 13 106 x62 Mode 6 Test Commands Comm...

Page 461: ...ing Execute the following commands in less than 30 seconds CS 43 P Selects 43 for pulse operation CO 43 P Executes 43 for pulse operation no effect Wait at least 30 seconds total elapsed time to initiate the latch reset block command this allows timer T1 to time out output goes TRUE and latch until the BLK input goes TRUE CS 143 P Selects 143 for pulse operation CO 143 P Executes 143 for pulse ope...

Page 462: ...t SL GROUP 1 43 143 243 343 443 Sets logic mode to discrete selection with virtual switches to control SL 51P 1 0 Enables 51P CT Input 1 SG SGCON 1 Sets SGC alarm 1 sec and anti pump 2 sec SL VO1 SG1 Enables OUT1 to close when SG1 active SL VO2 SG2 Enables OUT2 to close when SG2 active SL VO3 SG3 Enables OUT3 to close when SG3 active SG CT1 1 WYE NA 0 Input 1 ctr 1 ct wye xfmr na no ground source ...

Page 463: ...ng Input Type Command Comments S0 51P 1 0 5 0 I2 pu 1 0 td 5 curve I2 S1 51P 1 5 5 0 I2 pu 1 5 td 5 curve I2 S2 51P 1 8 5 0 I2 pu 1 8 td 5 curve I2 1 A S3 51P 2 2 5 0 I2 pu 2 2 td 5 curve I2 S0 51P 5 0 5 0 I2 pu 5 0 td 5 curve I2 S1 51P 7 5 5 0 I2 pu 7 5 td 5 curve I2 S2 51P 9 0 5 0 I2 pu 9 0 td 5 curve I2 5 A S3 51P 11 0 5 0 I2 pu 10 5 td 5 curve I2 Step 5 Using the values listed in Table 13 111 ...

Page 464: ...CS 143 1 Selects 143 for TRUE operation CO 143 1 Executes 143 TRUE operation Setting Group 1 E Exit Step 8 Verify that the relay did not change to Setting Group 1 SG1 by transmitting the RG GRPACTIVE to the relay It should echo back that the SG3 is still the active group This verifies that the relay will not make any setting group changes from logic inputs while the AUTO input logic is TRUE Step 9...

Page 465: ... events that occurred in reverse order when the current was being stepped down Manual Change Mode 1 Manual Change Mode 1 test procedures are a continuation of the automatic test procedures Do not change the logic or settings except for those in Step 1 and subsequent Step 1 Transmit to the relay the commands in Table 13 114 Table 13 114 Manual Group Control Selection Command Purpose A Gain access C...

Page 466: ... 13 116 Table 13 116 Binary Group Control Selection Setup Command Purpose A Gain access SL GROUP 2 Sets setting group control function to binary coded selection AUTO logic is unchanged from Table 13 80 E Exit Y Save settings Step 2 Verify that relay Outputs OUT3 opened when the commands in Table 13 113 were completed and OUT1 and OUT2 remained open With the existing logic and discrete select enabl...

Page 467: ...Executes Setting Group 2 for operation D1 1 CS 43 1 Selects Setting Group 3 for operation CO 43 1 Executes Setting Group 3 for operation D0 1 and D1 1 E Exit Step 5 Verify that the appropriate setting groups became active and relay outputs OUT1 through OUT3 closed in accordance with the discrete inputs of Table 13 114 Refer to Step 3 for more information on verifying active setting groups ...

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Page 469: ...GROUP 14 36 DOWNLOADING OSCILLOGRAPHY FILES 14 37 View Fault Details 14 38 View Fault Sequence of Events 14 38 Download Oscillography File 14 38 METERING 14 38 FILE MANAGEMENT 14 39 Saving a Settings File 14 39 Opening a Settings File 14 39 Uploading a Settings File 14 39 Downloading a Settings File 14 39 Printing a Settings File 14 39 SETTINGS COMPARE 14 40 BESTPrint 14 41 Figures Figure 14 1 Typ...

Page 470: ...arms Screen Bkr Status Tab 14 24 Figure 14 34 Reporting and Alarms Screen Bkr Alarms Tab 14 25 Figure 14 35 Reporting and Alarms Screen Transformer Monitoring Tab 14 26 Figure 14 36 Reporting and Alarms Screen Alarms Tab 14 26 Figure 14 37 Reporting and Alarms Screen Fault Recording Tab 14 27 Figure 14 38 Inputs and Outputs Screen Inputs 1 6 Tab 14 28 Figure 14 39 Inputs and Outputs Screen Outputs...

Page 471: ...the same 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 logic scheme or building a unique scheme from scratch Files may be exported from the GUI to a text editor where they can be reviewed or modified The modified text file may then be uploaded to ...

Page 472: ... Using Microsoft Windows 1 Insert the CD in the PC CD ROM drive 2 When the Setup and Documentation CD menu appears click the install button for the BESTCOMS PC Program The setup utility automatically installs BESTCOMS for BE1 CDS240 on your PC When BESTCOMS installation is complete a Basler Electric folder is added to the Windows program menu This folder is accessed by clicking the Start button an...

Page 473: ... 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 like paper file folder tabs to the screen see Figure 14 3 The first tab is Protection and Control and the second tab is Reporting and Alarms This screen gives you an overview of the system setup When the screen is first displayed the Protection and Control tab ...

Page 474: ...reen 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 relay status is provided in the lower right side of the screen Figure 14 4 System Setup Summary Screen Reporting and Alarms Tab 14 4 BE1 CDS240 BESTCOMS Software 9365200990 Rev F ...

Page 475: ...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 Toolbar row To select a preprogrammed scheme pull down this menu and click on the desired scheme When you do the selected logic name is displayed in the Logic window and the System Setup Summary screen displays what results would be if that sche...

Page 476: ... various software and firmware application version information Additionally you may enter the name of the relay substation identification and other installation specific identification This information will become useful when reports are generated Figure 14 6 General Operation Screen Identification Tab 14 6 BE1 CDS240 BESTCOMS Software 9365200990 Rev F ...

Page 477: ...power metering the Power Flow Polarity setting should be set to Reverse when the input voltage polarity is reversed Set Power Flow Polarity to Normal when the input voltage is correct Figure 14 7 General Operation Screen Power System VT Setup Tab CT Setup This screen Figure 14 8 allows you to enter the CT ratios and setup the CT parameters These entries affect every function that relies on current...

Page 478: ...ferential circuit and transformer phase relationships can be set using pull down menus IEC transformer setup can be accessed by clicking the IEC Setup button For more information on IEC Setup refer to Section 3 Input and Output Functions Power System Inputs Measurement Functions Setup IEC Transformer Setup Figure 14 9 General Operation Screen Transformer Setup Tab 14 8 BE1 CDS240 BESTCOMS Software...

Page 479: ... 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 communications port zero are combined and considered as one Figure 14 10 General Operation Screen Global Security Tab Communication This screen Figure 14 11 allows the user to set or change additional communication parameters that cannot be s...

Page 480: ...s 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 General Operation screen you can select a screen scroll item in BESTCOMS that is not available in the relay If you do you will get an error code immediately Figure 14 12 General Operation Screen HMI Display Tab 14 10 BE1 CDS240 BESTCOMS Softw...

Page 481: ...ng the coordination settings to optimize them for a predictable situation Sensitivity and time coordination settings can be adjusted to optimize sensitivity or clearing time based upon source conditions or to improve security during overload conditions Near the bottom of Figure 14 14 there is a Monitor Setting window for Groups 1 2 and 3 This field in each group allows you to select which element ...

Page 482: ...ges 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 be set using the drop down menu The 87 Phase can be adjusted from 0 10 times tap to 1 00 times tap using the Up Down arrows Restraint Slope is likewise adjustable from 15 to 60 with 45 being the default The 2nd Harmonic Restraint lop can be s...

Page 483: ... with Times Tap as the default Other options include Input 1 4 amps and Input 1 to 3 Full Load The allowed range for Times Tap is 0 010 times tap to 1 000 times tap using the Up Down arrows Restraint Slope can be set for 15 to 60 degrees Time can be set for milliseconds minutes or cycles using the drop down menu Figure 14 16 Percentage Differential Screen 87ND 187ND Tab 9365200990 Rev F BE1 CDS240...

Page 484: ...antity BE1 CDS240 relays measure the current input in secondary amperes If you want to use per unit percent amperes or primary current you must coordinate the settings in CT VT Setup and Conversions Do this also for the 27R Threshold setting If you want to use the voltage control mode instead of voltage restraint pull down the menu for Restraint default setting and select Control Settings for Time...

Page 485: ...us overcurrent elements with settable time delay The screens for the instantaneous elements are almost identical to the 51 screen The settable time delay is the primary difference See Figure 14 19 To change the time delay pull down the Time menu select your preferred unit of measure and then change the time for the appropriate phase neutral or negative sequence element Figure 14 19 Overcurrent Scr...

Page 486: ...in 1 increments The Alarm Threshold percent of pickup can be adjusted from 0 to 120 Select the BESTlogic button at the bottom of the 24 column The status of the logic is shown above the BESTlogic button A dialog box BESTlogic Function Element opens showing the status of the element logic and the logic scheme name If you have a custom logic scheme active you may change the status of the element log...

Page 487: ... the menu and selecting from the available choices Figure 14 21 Voltage Protection Screen 27P 127P Tab 47 This tab Figure 4 22 is the Negative Sequence Overvoltage With Settable Time Delay Changing the settings for this element is similar to those of the 27P 127P elements above Figure 14 22 Voltage Protection Screen 47 Tab 9365200990 Rev F BE1 CDS240 BESTCOMS Software 14 17 ...

Page 488: ... 127P elements above Figure 14 23 Voltage Protection Screen 59P 159P Tab 59X This tab Figure 4 24 is the Auxiliary Overvoltage Protection With Settable Time Delay Changing the settings for this element is similar to those settings of the 27P 127P elements above Figure 14 24 Voltage Protection Screen 59X Tab 14 18 BE1 CDS240 BESTCOMS Software 9365200990 Rev F ...

Page 489: ... is received and the trip output is asserted first pull down the Time menu and set the units for time measurement i e milliseconds seconds minutes or cycle See Figure 14 26 Then set the Pickup secondary amps primary amps per unit amps or percent amps Phase and Neutral Fault Detector Pickup PU can then be set in the range of 25 to 10 0 The BF150 Control Timer can be set using the Up Down arrows wit...

Page 490: ...settings for these elements are identical to those of the 50BF element above Logic Timers Pull down the Screens menu and select Logic Timers or click on the Logic Timers icon that is shown at the right margin of this paragraph This screen see Figure 14 27 configures four logic timers and has no folder tabs Figure 14 27 Logic Timers Screen 14 20 BE1 CDS240 BESTCOMS Software 9365200990 Rev F ...

Page 491: ...erred format See Figure 14 28 Figure 14 28 Reporting and Alarms Screen Clock Display Mode Tab I Demand The long title for this screen is Current Demand Metering and Alarms Figure 14 29 Demand intervals can be set independently for the phase neutral and negative sequence demand calculations Click in the Phase Neutral or Neg Sequence fields and enter the time in minutes or adjust the time by using t...

Page 492: ...by using the Up Down arrows set the Max and Min Phase values in the range of 10 0 to 300 secondary volts Likewise Max Neutral and Min Neutral can be set in the range of 10 0 to 150 secondary volts Watt Demands and Var Demands can be set in a similar fashion after establishing the unit of measure The permissible range is 0 0 to 8 500 secondary watts or vars as appropriate Figure 14 30 Reporting and...

Page 493: ...tion is detected all functions that use the negative sequence voltage are blocked Figure 14 31 Reporting and Alarms Screen VT Monitor Tab Bkr Duty The long title for this screen is Circuit x Breaker Duty Monitoring Figure 14 32 where x equals Circuits 1 through 4 Every time the breaker trips the breaker duty monitor updates two sets of registers for each pole of the breaker This function selects w...

Page 494: ...n be tailored to meet user defined needs by entering the new label in the Breaker Name box If desired the Enable Trip Coil Monitor may be enabled by selecting the appropriate box for each of the four possible circuits being monitored Breaker status logic is TRUE when the breaker is closed Figure 14 33 Reporting and Alarms Screen Bkr Status Tab 14 24 BE1 CDS240 BESTCOMS Software 9365200990 Rev F ...

Page 495: ... Transformer Monitoring The long title for this screen is Transformer Duty Monitoring Transformer Alarms Figure 14 35 Four transformer duty monitors are provided with the BE1 CDS240 Monitor 1 4 Each one has settings for Mode Disabled Enabled I and Enabled I2 circuit number Circuit 1 6 and 100 Duty Maximum in primary amps In addition eight transformer alarms are provided Alarm 1 8 The pull down arr...

Page 496: ...r Logic Alarm when an alarm point is activated To program an alarm point find the point in the Alarm Priority list and then click on the appropriate field under the Major Minor or Logic Alarm Logic settings for the Alarm Reset Logic can be made by clicking on the Logic button and then clicking on the Reset input Other logic blocks shown under the BESTlogic panel are shown for reference only There ...

Page 497: ...han 15 cycles of data per record total of 480 cycles To select the number of cycles of data and number of records click on the Oscillographic Records Select button and click on the number of records that you want to record Logic settings for the Target Reset Logic can be made by clicking on the Target Reset Logic button and then clicking on the Reset input Other logic blocks shown under BESTlogic ...

Page 498: ...e appropriate Up or Down arrow buttons to set the new value You can assign a meaningful name to each input This makes sequential events reports easier to analyze To assign a meaningful name to Input 1 click in the Name field and enter the new name To change the label for the Energized State click on the Energized State field and enter the new name To change the label for the De Energized State cli...

Page 499: ...to each virtual switch Figure 14 40 This makes sequential events reports easier to analyze To assign a meaningful label to Virtual Switch 43 click in the Label field and enter the new name 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 State field and enter the new name The 143 243 and 343 switc...

Page 500: ... 1101 2101 3101 Tab DNP If the CDS 240 is DNP equipped you can pull down the Screens menu and select DNP Settings or click on the DNP Settings icon which is shown at the right margin of this paragraph This screen has three folder tabs and the first tab Figure 14 42 is labeled DNP Settings For additional information refer to Basler Electric Instruction Manual 9365200991 Distributed Network Protocol...

Page 501: ... This tab Figure 14 43 allows the user to edit Analog DNP Points Using normal Windows techniques place a bullet next to the Point Range you wish to edit Now using the pull down menus for Class select 0 1 2 or 3 Finally enter a value in the Dead Band box from 0 to 4294967295 Figure 14 43 DNP Settings Screen Analog Class Dead Band Tab 9365200990 Rev F BE1 CDS240 BESTCOMS Software 14 31 ...

Page 502: ...ch is shown at the right margin of this paragraph This screen has four folder tabs and the first tab is Logic Select Logic Select This screen Figure 14 45 allows you to select one of the preprogrammed logic schemes and copy that nothing in the scheme You must rename that logic to a custom name and then make changes as you desire Click on the logic to be copied to the active logic and a dialog box ...

Page 503: ...are 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 State field and enter the new name To change the logic associated with VO6 click on the BESTlogic button associated with VO6 Click on the logic input and program the logic variables that define VO6 You may clear the existing prog...

Page 504: ...ck on the logic input and program the logic variables that define OUTA and OUT1 through OUT14 Note The CDS 240 relay can have either 10 or 14 hardware output contacts depending on the Contact I O Options in the style number Figure 14 47 BESTlogic Screen Physical Outputs Tab 14 34 BE1 CDS240 BESTCOMS Software 9365200990 Rev F ...

Page 505: ...aker 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 Element dialog box opens see Figure 14 49 with the available programming If the Mode pull down menu is available select the appropriate mode Click on the logic inputs and program the appropriate logic Figure 14 48 BESTlogic Screen Function Elements...

Page 506: ...ferent 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 50 There is only one choice Copy From Group to Group When you select this choice a dialog box opens Figure 14 51 allowing you to select the Copy to Group After you OK the copy routine another dialog box opens to inform you that the copy routine is complete Figure 14 50 From Gr...

Page 507: ...ured to an actual relay If you have communication with the relay a dialog box opens Figure 14 53 allowing you to View Download Relay Fault Files If there have been no fault events triggered you may create one by clicking on the Trigger button in the View Download Relay Fault Files dialog box Figure 14 52 Oscillography Download from Reports Pull down Menu Figure 14 53 View Download Relay Fault File...

Page 508: ... 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 BESTwave software METERING To observe the system metering pull down the Reports menu from the pull down menu and select Metering When the Metering dialog box Figure 14 54 opens click on the Start Polling button If BESTCOMS is not configured to the...

Page 509: ...n 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 loading bar is shown At upload completion you are asked if you want to save the settings and make them active After replying you are informed of the status Yes settings are saved or No settings are discarded If you would like to view the file name...

Page 510: ...rst 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 Settings file on disk click on the folder box and browse for the file If you wish to Download settings from unit to compare click on the RS 232 box to setup the Com Port and Baud Rate Click on the Compare box to compare the settings files that you ...

Page 511: ...y read the 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 particular device New and updated profiles will be available from Basler Electric One new set of profiles and their support files will be the optimum way to acquire additional printing of more ...

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Page 513: ...BB CO 7 A 11 Figure A 7 Time Characteristic Curve I I1 Inverse Time Similar to ABB CO 8 A 12 Figure A 8 Time Characteristic Curve I2 Inverse Time Similar to GE IAC 51 A 13 Figure A 9 Time Characteristic Curve V V1 Very Inverse Similar to ABB CO 9 A 14 Figure A 10 Time Characteristic Curve V2 Very Inverse Similar to GE IAC 53 A 15 Figure A 11 Time Characteristic Curve E E1 Extremely Inverse Similar...

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Page 515: ...er 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 function can be selected Characteristic curves for the inverse and definite time functions are defined by the following equations and comply with IEEE C37 112 1996 K D B C M D A T N T Equation A 1 1 M D R T 2 R Equation A 2 TT Time to trip when M 1 TR Time to reset if...

Page 516: ...2 A A Standard Inverse 0 01414 0 00000 1 0000 0 0200 0 0280 2 0000 B B Very Inverse I2 t 1 4636 0 00000 1 0000 1 0469 0 0280 3 2500 C C Extremely Inverse I2 t 8 2506 0 00000 1 0000 2 0469 0 0280 8 0000 G G Long Time Inverse I2 t 12 1212 0 00000 1 0000 1 0000 0 0280 29 0000 F Fixed Time 0 0000 1 00000 0 0000 0 0000 0 0280 1 0000 P Programmable 0 to 600 0 to 25 0 to 1 0 5 to 2 5 0 0280 0 to 30 46 Ne...

Page 517: ...ens PROT SG 51 51P PROT SG 51 51N or PROT SG 51 51Q For more information refer to Section 4 Protection and Control Overcurrent Protection 51P Time Overcurrent Protection Using Table A 3 Cross reference table values were obtained by inspection of published electromechanical time current characteristic curves The time delay for a current of five times tap was entered into the time dial calculator fu...

Page 518: ...GE IAC 77 0 5 1 0 1 9 2 7 3 5 4 3 5 2 6 2 7 4 8 2 9 9 N A THE 46 CURVE The 46 curve Figure A 17 is a special curve designed to emulate the I2 2 t withstand ratings of generators using what is frequently referred to as the generator K factor The 46 Curve Characteristics 46 Pickup Current Generators have a maximum continuous rating for negative sequence current This is typically expressed as a perce...

Page 519: ...ses the K factor i e 46 time dial setting 46 minimum pickup setting and generator full load current to create a constant Z see Equation A 4 2 Setting Pickup 46 Setting Nom I Dial Time 46 Z Equation A 4 The time to trip equation used in the relay is seconds 0 028 M Z T 2 T Equation A 5 where Setting Pickup 46 I Measured M 2 Equation A 6 which when M 1 reduces to 2 Measured 2 I Setting Nom I Dial Ti...

Page 520: ...Figure A 1 Time Characteristic Curve S S1 Short Inverse Similar to ABB CO 2 A 6 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F ...

Page 521: ...9365200990 Rev F BE1 CDS240 Time Overcurrent Characteristic Curves A 7 Figure A 2 Time Characteristic Curve S2 Short Inverse Similar To GE IAC 55 ...

Page 522: ...A 8 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F Figure A 3 Time Characteristic Curve L L1 Long Inverse Similar to ABB CO 5 ...

Page 523: ...Figure A 4 Time Characteristic Curve L2 Long Inverse Similar To GE IAC 66 9365200990 Rev F BE1 CDS240 Time Overcurrent Characteristic Curves A 9 ...

Page 524: ...Figure A 5 Time Characteristic Curve D Definite Time Similar To ABB CO 6 A 10 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F ...

Page 525: ...Figure A 6 Time Characteristic Curve M Moderately Inverse Similar to ABB CO 7 9365200990 Rev F BE1 CDS240 Time Overcurrent Characteristic Curves A 11 ...

Page 526: ...Figure A 7 Time Characteristic Curve I I1 Inverse Time Similar to ABB CO 8 A 12 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F ...

Page 527: ...Figure A 8 Time Characteristic Curve I2 Inverse Time Similar to GE IAC 51 9365200990 Rev F BE1 CDS240 Time Overcurrent Characteristic Curves A 13 ...

Page 528: ...Figure A 9 Time Characteristic Curve V V1 Very Inverse Similar to ABB CO 9 A 14 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F ...

Page 529: ...Figure A 10 Time Characteristic Curve V2 Very Inverse Similar to GE IAC 53 9365200990 Rev F BE1 CDS240 Time Overcurrent Characteristic Curves A 15 ...

Page 530: ...Figure A 11 Time Characteristic Curve E E1 Extremely Inverse Similar to ABB CO 11 A 16 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F ...

Page 531: ...Figure A 12 Time Characteristic Curve E2 Extremely Inverse Similar to GE IAC 77 9365200990 Rev F BE1 CDS240 Time Overcurrent Characteristic Curves A 17 ...

Page 532: ...Figure A 13 Time Characteristic Curve A Standard Inverse A 18 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F ...

Page 533: ...Figure A 14 Time Characteristic Curve B Very Inverse 9365200990 Rev F BE1 CDS240 Time Overcurrent Characteristic Curves A 19 ...

Page 534: ...Figure A 15 Time Characteristic Curve C Extremely Inverse A 20 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F ...

Page 535: ...Figure A 16 Time Characteristic Curve G Long Time Inverse 9365200990 Rev F BE1 CDS240 Time Overcurrent Characteristic Curves A 21 ...

Page 536: ...ft than they will in practice Curves stop at pickup level For example if the user selects 5A FLC and a pickup setting of 0 5A the per unit pickup is 0 1A The relay will not pick up at less than 0 1 pu I2 for these settings A 22 BE1 CDS240 Time Overcurrent Characteristic Curves 9365200990 Rev F ...

Page 537: ...NS B 1 Figures Figure B 1 Volt Hz Characteristic M 1 0 5 Time on Vertical Axis B 2 Figure B 2 Volt Hz Characteristic M 1 0 5 Time on Horizontal Axis B 2 Figure B 3 Volt Hz Characteristic M 1 1 Time on Vertical Axis B 3 Figure B 4 Volt Hz Characteristic M 1 1 Time on Horizontal Axis B 3 Figure B 5 Volt Hz Characteristic M 1 2 Time on Vertical Axis B 4 Figure B 6 Volt Hz Characteristic M 1 2 Time on...

Page 538: ...ii BE1 CDS240 Overexcitation 24 Inverse Time Curves 9365200990 Rev F This page intentionally left blank ...

Page 539: ... B 1 Time to Trip FST E D T T R R X 100 Equation B 2 Time to Reset where TT Time to trip TR Time to reset DT Time dial trip DR Time dial reset ET Elapsed time n Curve exponent 0 5 1 2 FST Full scale trip time TT ET FST Fraction of total travel toward trip that integration had progressed to After a trip this value will be equal to one When the measured volts hertz rises above a pickup threshold the...

Page 540: ...4 Figure B 1 Volt Hz Characteristic M 1 0 5 Time on Vertical Axis 100 110 120 130 140 150 160 170 180 190 200 0 1 1 0 10 0 100 0 1000 0 Trip Time in Seconds Percen t of N o minal V Hz 9 9 5 0 2 0 1 0 0 5 0 2 0 1 D1089 13 03 03 04 Figure B 2 Volt Hz Characteristic M 1 0 5 Time on Horizontal Axis B 2 BE1 CDS240 Overexcitation 24 Inverse Time Curves 9365200990 Rev F ...

Page 541: ...4 Figure B 3 Volt Hz Characteristic M 1 1 Time on Vertical Axis 100 110 120 130 140 150 160 170 180 190 200 0 1 1 0 10 0 100 0 1000 0 Trip Time in Seconds Perc e n t of N o min a l V H z 9 9 5 0 2 0 1 0 0 5 0 2 0 1 D1089 15 03 03 04 Figure B 4 Volt Hz Characteristic M 1 1 Time on Horizontal Axis 9365200990 Rev F BE1 CDS240 Overexcitation 24 Inverse Time Curves B 3 ...

Page 542: ...04 Figure B 5 Volt Hz Characteristic M 1 2 Time on Vertical Axis 100 110 120 130 140 150 160 170 180 190 200 0 1 1 0 10 0 100 0 1000 0 Trip Time in Seconds Perc e n t of N omin a l V Hz 9 9 5 0 2 0 1 0 0 5 0 2 0 1 D1089 17 03 03 04 Figure B 6 Volt Hz Characteristic M 1 2 Time on Horizontal Axis B 4 BE1 CDS240 Overexcitation 24 Inverse Time Curves 9365200990 Rev F ...

Page 543: ...MINAL COMMUNICATION C 1 WINDOWS 2000 XP C 1 Windows Vista C 4 Figures Figure C 1 Connection Description Dialog Box C 1 Figure C 2 Connect To Dialog Box C 2 Figure C 3 COM Properties Dialog Box C 2 Figure C 4 Properties Settings Tab C 3 Figure C 5 ASCII Setup Dialog Box C 4 Tables Table C 1 RS 232 Communication Ports C 4 ...

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Page 545: ...ssories Communication HyperTerminal Step 2 Click HyperTerminal to open the folder Step 3 Select the file or icon labeled Hypertrm or Hypertrm exe Once the program has started you will be presented with a series of dialog boxes Step 4 Dialog Box Connection Description a Type the desired file name for example BE1 CDS240 See Figure C 1 b Click OK Figure C 1 Connection Description Dialog Box Step 5 Di...

Page 546: ... baud rate of the relay is 9 600 Set the Data bits at 8 Set the Parity to None Set the Stop bits at 1 Set Flow control to Xon Xoff b Click OK This creates an icon with the file name entered in Step 4 and places it in the HyperTerminal folder Future communication sessions can then be started by clicking the appropriate icon Figure C 3 COM Properties Dialog Box C 2 BE1 CDS240 Terminal Communication ...

Page 547: ...ng Figure C 5 as a guide ASCII Sending Place a check at Send line ends Place a check at Echo typed characters Select a Line delay setting of 100 to 200 milliseconds Set the Character delay setting to 0 milliseconds ASCII Receiving Disable Append line feeds by leaving the box unchecked Disable Force incoming by leaving the box unchecked Place a check at Wrap lines c Click OK d Click OK Step 8 Click...

Page 548: ...Front Port 9 pin female DCE PC to Front RS 232 port cable Straight Rear Port 9 pin female DCE PC to Rear RS 232 port cable Straight WINDOWS VISTA HyperTerminal is not provided with Windows Vista Stand alone software from other vendors can be used to communicate with a BE1 CDS240 relay The configuration of stand alone software is similar to that of HyperTerminal C 4 BE1 CDS240 Terminal Communicatio...

Page 549: ... Curve and V IC 10 A exc D 24 Saturation Factor SF vs SF Definitions Compared D 25 Saturation Factor Defined from the CT C Class and Including CT Impedance D 26 Conclusion D 27 Setting Note 4 Slope Setting when CT Saturation Factor SF 0 5 D 27 Figures Figure D 1 Auto Transformer with Tertiary Winding Relay Setting Calculation Example D 1 Figure D 2 Slope and Operating Margin D 10 Figure D 3 Two Wi...

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Page 551: ...ettings Calculate Minimum Pickup Restraint Setting Select Unrestrained Pickup Setting Calculate Slope Select Harmonic Restraint Settings For additional information on selected examples see the associated Setting Notes EXAMPLE 1 THREE WINDING TRANSFORMER VERIFY CT PERFORMANCE Refer to Figure D 1 and Table D 1 for the application parameters used in this example Figure D 1 Auto Transformer with Terti...

Page 552: ...perform this more involved approach Another aspect of CT performance is how well it will reproduce current during an internal fault If a CT will adequately perform during an external fault it is typically assumed that it will adequately perform during an internal fault One reason is that internal faults of a level that will cause CT saturation will also tend to cause high levels of tripping curren...

Page 553: ...he cu ring the external fault For brevity this check is not done in these calculations Step 2 Determine the worst case CT burden voltage for a three phase fault VB3 For wye connected CTs VB3 IF3 RC RL RR elta connected CTs for three phase fault 3 IF3 RCT RL RR N e th Setting Note 1 where R one way lead resistance in ohms wire from CT to Relay L TERTIARY Step 3 Determine the worst case burden volta...

Page 554: ...is the largest of the burden voltages calculated in Steps 2 and 3 HIGH LOW TERTIARY D 4 BE1 CDS240 Settings Calculations 9365200990 Rev F Determine the saturation factor SF 135 0 400 SF 1 54 116 0 300 SF 7 34 144 0 320 SF 2 64 NOTE Maximum Recommended SF 0 5 Larger saturation factors will make the relay insecure for external faults especially during high DC offset conditions Possible solutions are...

Page 555: ...nput current higher taps will yield a less sensitive relay because the same current level will be a lower percentage of tap NOTE Reduced MVA Winding CT Ratios and Tap Settings When one winding has a gre windings the calculation for atly reduced MVA rating compared to other the tap setting on the low rated winding will result in a very high tap setting and sometimes it will be necessary to set the ...

Page 556: ...ble limits For instance if TAP3 had been calculated to some value above 20 sensitivity of the relay In non numerical relays g Basler Electric BE1 87T the minpu was fixed at a typical value of 0 35 of the relay tap In the BE1 DS240 relay the user can choose lower or higher values to optimize the protection in each particular pplication Selecting a lower minpu setting will tend to raise the slope se...

Page 557: ...es by this equation Step 4 Convert pickup setting to primary ampere p COMPn CTRn TAPn Minpu Ipri A Ipri 176 1 160 39 4 25 0 230 kV A Ipri 252 300 69 4 25 0 115 kV 1 A 2930 1 800 6 14 25 0 Ipri 3 8 kV Choose Unrestrained Pickup Setting This two step process selects the unrestraint element setting to provide security for both inrush and external fault conditions Step 1 Calculate the expected inrush ...

Page 558: ... 8 9 39 4 160 16900 IE 3 6 69 4 300 8900 1 2 64 14 800 24600 IE IE Step 2 The transient monitor function provides security from tripping for external through faults by doubling the u s detected Calculate the unrestrained pic greater than 70 of the nrestrained unit pickup setting when saturation i kup such that 2 times the unrestrained pickup is maximum external through fault in times tap This calc...

Page 559: ...ithout the relay taps being reset Load tap changer Relay tap mismatch assumed to negligible due to the fine tap adjustment available in the relay Quality of the CTs If the saturation factor calculated previously is greater than 0 5 additional margin is recommended For SF 0 5 we assume that the CTs perform within the 10 limit defined in the ANSI Accuracy Class on a steady state ba saturation will n...

Page 560: ...sed by excitation current and unmonitored loads does not vary with through current loading so it tends to offset the operating slope Si up ward from the origin Thus it decreases the safety margin at the differential tripping characteristic knee point intersection of the minimum pickup tripping characteristic and the slope tripping characteristic The offset current is calculated as unmon Exc Offset...

Page 561: ... D 7 A Ipri 69 1 160 39 4 098 0 230 kV A Ipri 138 1 300 69 4 098 0 115 kV Harmonic Restraint Settings The recommended harmonic restraint settings have been in effect successfully for many years Most applications should use these settings When second harmonic sharing is enabled restraint for the A phase differential element is determined by Setting Restraint 2 IA IC IB IA 100 nd st 1 op nd 2 op nd ...

Page 562: ...725 kV 2 5 5 12 47 Kv 10 Auto MVA SC FA 12 20 12 20 XFMR connection Delta Wye CT connection Wye Wye CT ratio 600 5 1200 5 CT tap 300 5 800 5 CT accuracy class 400 800 One way lead burden ohms 0 7 0 7 Input 1 2 Fault current three phase 1 916 10 603 Fault current single phase 1 171 11 231 Standard connection High voltage leads the low voltage by 30 LT resistance at tap and lead resistance RL RCT NO...

Page 563: ... e fa l t ree p s u t VB3 3 IF3 RCT RL RR Note that the wye connection produces a lower burden on the CTs see Setting Note 1 where IF3 determined in Step 1 RL one way lead resistance in ohms including CT resistance RR relay resistance in ohms 0 05 ohm RCT CT internal resistance Neglecting RR use R from Table D 3 HIGH LOW V 4 22 7 0 32 V 3 B V 22 7 0 32 V 3 B 4 Step 3 Determine the worst case burde...

Page 564: ...E Maximum Recommended SF 0 5 Larger saturation factors will make the relay insecure for external faults especially during high DC offset Possible solutions are to increase the CT quality adjust the CT tap connections to increase effective accuracy class or to use internal phase compensation instead of delta connecting CTs DETERMINE TAP SETTINGS Calculate Ideal Taps Step 1 Use the following two equ...

Page 565: ... brings all taps to within acceptable limits For instance if TAP2 had been calculated to some value above 20 then reset TAP2 to 20 and reset TAP1 to a lower value using the equation Step 3 If the calculated TAP1 and TAP2 are in range 2 00 20 0 for 5 ampere sensing input types or 0 40 4 00 for 1 ampere sensing input types proceed to Calculate Minpu If they range proceed with Step 4 S Calculate spre...

Page 566: ...erate current for use by inrush with a sensitive setting Choose Unrestrained Pickup Setting This two step process selects the unrestraint element setting to provide security for both inrush and external fault conditions Step 1 Calculate the expected inrush current based upon the self cooled rating of the transformer Asymmetrical CT saturation during a heavy internal fault generates 2 harmonics tha...

Page 567: ... 70 tep 2 of the maximum external through fault in times tap This calculation assumes that the CTs carrying the maximum fault saturate severely yielding only 30 of the expected ratio current This leaves 70 of the fault current as false differential current 02 4 2 URO 5 11 70 0 99 3 2 URO Step 3 Select the unrestrained pickup setting Choose the larger 4 11 70 0 of the unrestrained pickup values and...

Page 568: ...ith through current so they affect the minpu setting only Transformer excitation current IE assumed to be less than 4 of the self cooled rating This mismatch does not vary with through current load so it tends to not add to the slope mismatch line restraint characteristic see Figure D 10 Unmonitored loads Iunmon such as station service or small capacitor banks in the differential zone add to the c...

Page 569: ...pu M 1 S The conservative calculation of margin at the knee point uses Si as calculated in Calculate Slope Step 1 For this example Mo in times tap is the following equation tap times 040 0 024 0 39 1 25 0 Mo 29 The above calculation of margin is conservative For the low current level where the margin at the tripping characteristic knee point is of interest the CT error will typically be less than ...

Page 570: ... Services Department Step 1 If second harmonic sharing is enabled set the second harmonic restraint unit setting at 18 If second harmonic sharing is disabled set the second harmonic restraint unit at 12 Step 2 Set the fifth harmonic restraint unit setting 5th 35 EXAMPLE 3 DUAL BREAKERS If a two winding transformer has two high side or low side breakers brought into two independent inputs on the re...

Page 571: ...Phase Fault IA IB IC 0 IA IB IC VS IARW IA IC RL RR IB IA RL RR I R A RW RL RR RL RR IB RL RR IC RL R 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 B D2857 22 vsd 11 09 99 A RW VS RW IA IB IC C RW RL IC IB RL IA IC RL IB IA RR RR RR VT RELAY ...

Page 572: ...gs Calculations 9365200990 Rev F Figure D 6 Phase To Phase Fault Delta Connected CTs Assuming Z1 Z2 3 2 3 I I Phase 2 carries twice the fault current returning from the relay to the CTs Therefore the maximum current is 3 2 1 I 2 I I I 0 IB IA D2779 01 11 09 99 3 MAX 3 MAX I 3 I I 2 3 2 I 2 I ...

Page 573: ...designed The definition mainly tells a manufacturer how to design a CT and is not easily translated into assessing whether a CT will saturate for another burden and current level An alternate and understand The I R voltage approximately equal to I Z the CT will see in a worst case fault where R includes the entire CT loop inclu relaying and metering on the CT Two simple methods for determining the...

Page 574: ... CT internal resistance is ignored Figure D 8 CT Terminal and Excitation Voltages This first definition of saturation relates the CT terminal voltage to the accuracy class of the CT effective class in the case of multi ratio CTs It is practical and easy to calculate since it requires only readily available data An application is considered reasonably secure when SF is less than 0 5 Saturation Fact...

Page 575: ...SF Definitions Compared Using the equivalent circuit in Figure Zc able to source 20 times nominal current into a standard burden 9365200990 Rev F BE1 CDS240 Settings Calculations D 25 T take the ratio SF SF Since this expression varies with the ratio of the actual relay circuit burden ZB to the accuracy class burden Zc and the CT internal resistance Rs it is best visualized with a surface plot Fig...

Page 576: ...falls somewhere between the 45O knee point voltage and the excitation voltage at Ie 10 A i e V10 herein Further including the CT internal impedance in the voltage drop analysis ensures that the CT internal resistance is not overlooked as a source of saturation In some inexpensive CTs or old installations the internal resistance is not readily found in published data But if this is a transformer th...

Page 577: ...on 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 verify the security of the protection The effect of this setting is illustrated in the following hypothetical case where it can be seen that the slope based on the linear operation may be too low when...

Page 578: ...D 28 BE1 CDS240 Settings Calculations 9365200990 Rev F This page intentionally left blank ...

Page 579: ......

Page 580: ...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 ...

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