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Siemens SIPROTEC 7SJ62, Manual

The Siemens SIPROTEC 7SJ62 is an advanced protection relay system designed to ensure optimal safety and reliable operation of electrical equipment. With our intuitive user-friendly interface, accessing the product manual is simple. Download the user manual for free from our website and maximize the potential of your SIPROTEC 7SJ62.

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Functions

2.3 Directional Overcurrent Protection 67, 67N

SIPROTEC, 7SJ62/64, Manual
C53000-G1140-C207-2, Release date 01.2008

111

Direction Characteristic

The direction characteristic, i.e. the position of the ranges „forward“ and „reverse“ is set for the phase directional 
elements under address 

1519

 

ROTATION ANGLE

 and for the ground directional element under address 

1619

 

ROTATION ANGLE

. The short-circuit angle is generally inductive in a range of 30° to 60°. This means that 

usually the default settings of +45° for the phase directional elements and -45° for the ground directional 
element can be maintained for the adjustment of the reference voltage, as they guarantee a safe direction 
result. 

Nevertheless, the following contains some setting examples for special applications (Table 2-8). The following 
must be observed: With the phase directional elements, the reference voltage (fault-free voltage) for phase-
ground-faults is vertical on the short-circuit voltage. For this reason, the resulting setting of the angle of rotation 
is (see also Section 2.3.8):  

With the ground directional element, the reference voltage is the short-circuit voltage itself. The resulting setting 
of the angle of rotation is then:  

It should also be noted for phase directional elements that with phase-to-phase faults, the reference voltage is 
rotated between 0° (remote fault) and 30° (close-up fault) depending on the collapse of the faulty voltage. This 
can be taken into account with a mean value of 15°:   

Table 2-8

Setting examples

1)

Power flow direction

2)

With the assumption that these are cable lines

     Ref. volt. angle of rotation  = 90 - 

ϕ

k

Phase directional element (phase-to-earth fault). 

     Ref. volt. angle of rotation  = -

ϕ

k

Directional ground element (phase-to-earth fault). 

     Ref. volt. angle of rotation  = 90 - 

ϕ

k

 -15° 

Phase directional element (phase-to-phase fault). 

Application

 

ϕ

sc

 

typical

Setting

 Directional Phase 

Element

1519 ROTATION 

ANGLE

Setting

 Directional Ground 

Element

1619 ROTATION 

ANGLE

60°

Range 30°..0.0°

→

 15°

–60°

30°

Range 60°...30°

→

 45°

–30°

30°

Range 60°...30°

→

 45°

–30°

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Summary of Contents for SIPROTEC 7SJ62

Page 1: ...y with Local Control 7SJ62 64 V4 7 Manual C53000 G1140 C207 2 Preface Contents Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Appendix A Literature Glossary Index w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 2: ...suggested improvements We reserve the right to make technical improvements without notice Document version V04 01 00 Release date 01 2008 Copyright Copyright Siemens AG 2007 All rights reserved Dissemination or reproduction of this document or evaluation and communication of its contents is not authorized except where ex pressly permitted Violations are liable for damages All rights re served part...

Page 3: ...ies and personnel of electrical facilities and power plants Applicability of this Manual This manual applies to SIPROTEC 4 Multi Functional Protective Relay with Local Control 7SJ62 64 firmware version V 4 7 Indication of Conformity This product complies with the directive of the Council of the European Communities on the approximation of the laws of the Member States relating to electromagnetic c...

Page 4: ...ntative Our Customer Support Center provides a 24 hour service Phone 01 80 5 24 70 00 Fax 01 80 5 24 24 71 e mail support energy siemens com Training Courses Enquiries regarding individual training courses should be addressed to our Training Center Siemens AG Power Transmission and Distribution Power Training Center Humboldt Street 59 90459 Nuremberg Telephone 0911 4 33 70 05 Fax 0911 4 33 79 29 I...

Page 5: ... of danger is illustrated as follows DANGER Danger indicates that death severe personal injury or substantial material damage will result if proper precau tions are not taken WARNING indicates that death severe personal injury or substantial property damage may result if proper precautions are not taken Caution indicates that minor personal injury or property damage may result if proper precaution...

Page 6: ...successful and safe operation of the device is dependent on proper handling storage installation opera tion and maintenance When operating an electrical equipment certain parts of the device are inevitably subject to dangerous voltage Severe personal injury or property damage may result if the device is not handled properly Before any connections are made the device must be grounded to the ground ...

Page 7: ... word in the display of the device or on the screen of a personal computer with operation software DIGSI are additionally written in italics The same applies to the options of the menus Messages Designators for information which may be output by the relay or required from other devices or from the switch gear are marked in a monospace type style in quotation marks Deviations may be permitted in dr...

Page 8: ...e equivalence output is active if both inputs are active or inactive at the same time Dynamic inputs edge triggered above with positive below with nega tive edge Formation of one analog output signal from a number of analog input signals Limit stage with setting address and parameter designator name Timer pickup delay T example adjustable with setting address and parameter designator name Timer dr...

Page 9: ...a 1 43 2 1 3 1 Description 43 2 1 3 2 Setting Notes 43 2 1 3 3 Settings 50 2 1 3 4 Information List 51 2 1 4 Oscillographic Fault Records 52 2 1 4 1 Description 52 2 1 4 2 Setting Notes 53 2 1 4 3 Settings 53 2 1 4 4 Information List 54 2 1 5 Settings Groups 54 2 1 5 1 Description 54 2 1 5 2 Setting Notes 54 2 1 5 3 Settings 55 2 1 5 4 Information List 55 2 1 6 Power System Data 2 55 2 1 6 1 Descr...

Page 10: ...n 67 67N 96 2 3 1 General 96 2 3 2 Definite Time Directional High set Elements 67 2 67N 2 98 2 3 3 Definite Time Directional Overcurrent Elements 67 1 67N 1 100 2 3 4 Inverse Time Directional Overcurrent Elements 67 TOC 67N TOC 102 2 3 5 Interaction with Fuse Failure Monitor FFM 104 2 3 6 Dynamic Cold Load Pickup Function 104 2 3 7 Inrush Restraint 104 2 3 8 Determination of Direction 104 2 3 9 Re...

Page 11: ...Motor Starting Protection 48 159 2 8 1 1 Description 159 2 8 1 2 Setting Notes 162 2 8 2 Motor Restart Inhibit 66 165 2 8 2 1 Description 165 2 8 2 2 Setting Notes 171 2 8 3 Load Jam Protection 51M 175 2 8 3 1 Mode of Operation 175 2 8 3 2 Setting Notes 178 2 8 4 Motorprotection Motor Starting Protection 48 Motor Restart Inhibit 66 LoadJam 180 2 8 4 1 Settings 180 2 8 4 2 Information List 181 2 9 ...

Page 12: ...tion 216 2 12 Ground Fault Protection 64 67N s 50N s 51N s 219 2 12 1 Ground Fault Detection for cos ϕ sin ϕ Measurement Standard Procedure 219 2 12 2 Ground Fault Detection for U0 I0 ϕ Measurement 226 2 12 3 Ground Fault Location 231 2 12 4 Setting Notes 232 2 12 5 Settings 239 2 12 6 Information List 242 2 13 Intermittent Ground Fault Protection 243 2 13 1 Description 243 2 13 2 Setting Notes 24...

Page 13: ...ion Function 305 2 19 1 SYNC Function group 1 305 2 19 1 1 General 305 2 19 1 2 Synchrocheck 309 2 19 1 3 Synchronous Asynchronous only 7SJ64 309 2 19 1 4 De energized Switching 310 2 19 1 5 Direct Command Blocking 311 2 19 1 6 SYNC Function Groups 312 2 19 1 7 Interaction with Control AR and External Control 312 2 19 1 8 Setting Notes 314 2 19 1 9 Settings 320 2 19 1 10 Information List 321 2 20 ...

Page 14: ...ion List 356 2 23 5 Min Max Measurement Setup 356 2 23 5 1 Description 356 2 23 5 2 Setting Notes 356 2 23 5 3 Settings 357 2 23 5 4 Information List 357 2 23 6 Set Points for Measured Values 359 2 23 6 1 Description 359 2 23 6 2 Setting Notes 359 2 23 6 3 Information List 360 2 23 7 Set Points for Statistic 361 2 23 7 1 Description 361 2 23 7 2 Setting Notes 361 2 23 7 3 Information List 361 2 23...

Page 15: ...3 4 Mounting with Detached Operator Panel 436 3 1 3 5 Mounting without Operator Panel 436 3 2 Checking Connections 438 3 2 1 Checking Data Connections of Interfaces 438 3 2 2 Checking System Connections 441 3 3 Commissioning 443 3 3 1 Test Mode and Transmission Block 444 3 3 2 Testing the System Interface 444 3 3 3 Checking the Status of Binary Inputs and Outputs 446 3 3 4 Tests for Circuit Breake...

Page 16: ...ynamiC Cold Load Pickup 495 4 7 Single phase Overcurrent Protection 496 4 8 Voltage Protection 27 59 497 4 9 Negative Sequence Protection 46 1 46 2 499 4 10 Negative Sequence Protection 46 TOC 500 4 11 Motor Starting Protection 48 506 4 12 Motor Restart Inhibit 66 507 4 13 Load Jam Protection 508 4 14 Frequency Protection 81 O U 509 4 15 Thermal Overload Protection 49 510 4 16 Ground Fault Protect...

Page 17: ...2 Housing for panel flush mounting or cubicle installation 561 A 2 2 7SJ62 Housing for Panel Surface Mounting 565 A 2 3 7SJ62 Interface assignment on housing for panel surface mounting 569 A 2 4 7SJ64 Housing for Panel Flush Mounting or Cubicle Installation 571 A 2 5 7SJ64 Housing for Panel Surface Mounting 578 A 2 6 7SJ64 Housing with Detached Operator Panel 585 A 2 7 7SJ64 Housing for Panel Surf...

Page 18: ... 3 Binary Output 616 A 5 4 Function Keys 617 A 5 5 Default Display 617 A 5 6 Pre defined CFC Charts 622 A 6 Protocol dependent Functions 625 A 7 Functional Scope 626 A 8 Settings 629 A 9 Information List 653 A 10 Group Alarms 682 A 11 Measured Values 683 Literature 687 Glossary 689 Index 701 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 19: ...ce family SIPROTEC 7SJ62 64 devices is introduced in this section An overview of the devices is pre sented in their application characteristics and scope of functions 1 1 Overall Operation 20 1 2 Application Scope 24 1 3 Characteristics 26 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 20: ...internal processing of the device The device provides four current inputs Depending on the model the device is also equipped with three or four voltage inputs Three current inputs serve for input of the phase currents Depending on the model the fourth current input IN may be used for measuring the ground fault current IN current transformer starpoint or for a separate ground current trans former f...

Page 21: ...lifiers IA The input amplifier IA element provides a high resistance termination for the input quantities It consists of filters that are optimized for measured value processing with regard to bandwidth and processing speed The analog to digital AD element consists of a multiplexor an analog to digital A D converter and of memory components for the transmission of digital signals to the microcompu...

Page 22: ...ts and outputs to and from the computer system are relayed via the input output modules The com puter system obtains the information from the system e g remote resetting or the external equipment e g blocking commands Outputs are in particular commands to the switchgear units and annunciations for remote signalling of important events and statuses Front Panel In devices with integrated or detached...

Page 23: ...l data can be transferred to a central control center or monitoring system via the serial System Interface This interface may be provided with various protocols and physical transmission schemes to suit the particular application A further interface is provided for the time synchronization of the internal clock via external synchronization sources A range of communication protocols are available f...

Page 24: ...rotection functions already mentioned other protective functions are available Some of them depend on the version of the device that is ordered These additional functions include frequency pro tection 81O U overvoltage protection 59 and undervoltage protection 27 negative sequence protection 46 and overload protection 49 with start inhibit for motors 66 68 motor starting protection 48 and step cha...

Page 25: ...They serve to establish extensive communication with other digital operating control and memory components The service interface can be operated via electrical data lines or fiber optics and also allows communication via modem For this reason remote operation is possible via personal computer and the DIGSI operating soft ware e g to operate several devices via a central PC The additional port only...

Page 26: ... Communication with SCADA or substation controller equipment via serial interfaces through the choice of data cable modem or optical fibers Battery buffered clock that can be synchronized with an IRIG B via satellite or DCF77 signal binary input signal or system interface command Motor Statistics Recording of important statistical motor data operation and startup information Switching statistics R...

Page 27: ...ck up Function 50C 50NC 51C 51NC 67C 67NC Dynamic changeover of time overcurrent protection settings e g when cold load conditions are anticipated Detection of cold load condition via circuit breaker position or current threshold Activation via automatic reclosure AR possible Start also possible via binary input Single Phase Overcurrent Protection Evaluation of the measured current via the sensiti...

Page 28: ...r Motors 51M Protection of motors during sudden rotor blocking Evaluation of the positive sequence system of phase currents Evaluation of the circuit breaker switching state Blocking of function during motor standstill and during motor startup Frequency Protection 81 O U Monitoring on undershooting f and or overshooting f with 4 frequency limits and delay times that are independently adjustable In...

Page 29: ...lable Direction determination with zero sequence quantities I0 V0 wattmetric ground fault direction determina tion Any element can be set as directional or non directional forward sensing directional or reverse sensing directional Directional characteristic can be adjustable Optionally applicable as additional ground fault protection Intermittent Ground Fault Protection Detects and accumulates int...

Page 30: ...ic function with definite time characteristic Internal and configurable pickup and dropout delay Modifiable message texts Synchrocheck only 7SJ623 7SJ624 and 7SJ64 Verification of the synchronous conditions before reclosing after three pole tripping Fast measurement of the voltage difference V the phase angle difference ϕ and the frequency difference f Alternatively check of the de energized state...

Page 31: ...ls can be logically combined to establish user defined logic functions All common Boolean operations are available for programming AND OR NOT Exclusive OR etc Time delays and limit value interrogation Processing of measured values including zero suppression adding a knee curve for a transducer input and live zero monitoring Breaker Control Circuit breakers can be opened and closed via specific pro...

Page 32: ...Introduction 1 3 Characteristics SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 32 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 33: ...rotection 129 2 6 Voltage Protection 27 59 140 2 7 Negative Sequence Protection 46 151 2 8 Motor Protection 159 2 9 Frequency Protection 81 O U 182 2 10 Thermal Overload Protection 49 187 2 11 Monitoring Functions 197 2 12 Ground Fault Protection 64 67N s 50N s 51N s 219 2 13 Intermittent Ground Fault Protection 243 2 14 Automatic Reclosing System 79 250 2 15 Fault Locator 274 2 16 Breaker Failure...

Page 34: ...guration procedure The interaction of functions may also be modified 2 1 1 1 Description Setting the Functional Scope Example for the configuration of the functional scope A protected system consists of overhead lines and underground cables Since automatic reclosing is only needed for the overhead lines the automatic reclosing function is not configured or disabled for the relays protecting the un...

Page 35: ...defined characteristic you can choose in address 112 and 113 whether to specify only the pickup characteristic User Defined PU or the pickup and the dropout characteristic User def Reset Additionally the superimposed high current elements 50 2 and 50 3 are available in all these cases Time over current protection may be set to Disabled during configuration For directional time overcurrent protecti...

Page 36: ...o consideration by the fault locator When using trip circuit supervision address 182 74 Trip Ct Supv allows you to select whether this function should work with two 2 Binary Inputs or only one binary input 1 Binary Input or if the function is Disabled If you want to detect an ambient temperature or a coolant temperature and send the information e g to the overload protection specify the port to wh...

Page 37: ...e 67 67 TOC 116 67N 67N TOC Disabled Definite Time TOC IEC TOC ANSI User Defined PU User def Reset Definite Time 67N 67N TOC 117 Coldload Pickup Disabled Enabled Disabled Cold Load Pickup 122 InrushRestraint Disabled Enabled Disabled 2nd Harmonic Inrush Restraint 127 50 1Ph Disabled Enabled Disabled 50 1Ph 130 S Gnd F Dir Ch cos ϕ sin ϕ V0 I0 ϕ mea cos ϕ sin ϕ sens Ground fault dir character istic...

Page 38: ... Function 3 Disabled ASYN SYNCHRON SYNCHROCHECK Disabled 25 Function group 3 164 25 Function 4 Disabled ASYN SYNCHRON SYNCHROCHECK Disabled 25 Function group 4 170 50BF Disabled Enabled enabled w 3I0 Disabled 50BF Breaker Failure Protection 171 79 Auto Recl Disabled Enabled Disabled 79 Auto Reclose Function 172 52 B WEAR MONIT Disabled Ix Method 2P Method I2t Method Disabled 52 Breaker Wear Monito...

Page 39: ...2 Flex Function 03 Flex Function 04 Flex Function 05 Flex Function 06 Flex Function 07 Flex Function 08 Flex Function 09 Flex Function 10 Flex Function 11 Flex Function 12 Flex Function 13 Flex Function 14 Flex Function 15 Flex Function 16 Flex Function 17 Flex Function 18 Flex Function 19 Flex Function 20 Please select Flexible Functions Addr Parameter Setting Options Default Setting Comments w w...

Page 40: ...o Trip decide whether the new fault will be stored or reset Figure 2 1 Creation of the reset command for the latched LED and LCD messages Spontaneous Messages on the Display You can determine whether or not the most important data of a fault event is displayed automatically after the fault has occurred see also Subsection Fault Messages in Section Auxiliary Functions 2 1 2 2 Setting Notes Fault Me...

Page 41: ...image 6 image 7 image 8 image 9 image 10 image 1 Start image Default Display No Information Type of In formation Comments Light on SP Back Light on Reset LED IntSP Reset LED DataStop IntSP Stop data transmission Test mode IntSP Test mode Feeder gnd IntSP Feeder GROUNDED Brk OPENED IntSP Breaker OPENED HWTestMod IntSP Hardware Test Mode SynchClock IntSP_Ev Clock Synchronization Error FMS1 OUT Error...

Page 42: ...or Board 2 185 Error Board 3 OUT Error Board 3 186 Error Board 4 OUT Error Board 4 187 Error Board 5 OUT Error Board 5 188 Error Board 6 OUT Error Board 6 189 Error Board 7 OUT Error Board 7 191 Error Offset OUT Error Offset 192 Error1A 5Awrong OUT Error 1A 5Ajumper different from setting 193 Alarm NO calibr OUT Alarm NO calibration data available 194 Error neutralCT OUT Error Neutral CT different...

Page 43: ...d then press the X key to navigate to the SETTINGS display To enter the Power System Data select the P System Data 1 in the SETTINGS menu In DIGSI doubleclick Settings to display the relevant selection A dialog box with tabs and Prot Op quant will open under P System Data 1 in which you can configure the individual parameters The following de scriptions are therefore structured accordingly Rated F...

Page 44: ...uts IN or INS Figure 2 2 Polarity of current transformers Current ConnectionI4 Power System Data Here the device is informed whether the ground current of the current transformer starpoint is connected to the fourth current input I4 This corresponds with the Holmgreen connection see connection example in Appen dix A 3 Figure A 37 In this case parameter 280 Holmgr for Σi is set to YES In all other ...

Page 45: ...Q7 Q8 the ground current IN or INS is connected as usual in this case the ground current of the line A second ground current in this case the transformer starpoint current is connected to the second current input IN2 terminals Q3 Q4 The settings A G2 C G G B or A G2 C G G2 B must be used here Both define the connection of a ground current IN2 at the second current input terminals Q3 Q4 The setting...

Page 46: ...round voltages under symmetrical conditions Parameter 240 VT Connect 1ph is set to specify that only one voltage transformer is connected to the de vices In this case the user defines which primary voltage is connected to which analog input If one of the avail able voltages is selected i e a setting unequal NO setting of address 213 is not relevant anymore Only the setting of parameter 240 is rele...

Page 47: ...condary current of the current transformer matches the rated current of the device otherwise the device will calculate incorrect primary data At addresses 217 Ignd CT PRIM and 218 Ignd CT SEC information is entered regarding the primary and secondary ampere rating of the current transformer In case of a normal connection starpoint current connected to IN transformer 217 Ignd CT PRIM and 204 CT PRI...

Page 48: ...ommand duration TMin TRIP CMD is set This setting applies to all protec tion functions that can initiate tripping In address 211 the maximum close command duration TMax CLOSE CMD is set It applies to the integrated reclosing function It must be set long enough to ensure that the circuit breaker has securely closed An exces sive duration causes no problem since the closing command is interrupted in...

Page 49: ...he quantities calculated from the three phase currents 3I0 calcul In the first case the measured quantity at the fourth current input is evaluated In the latter case the summation current is calculated from the three phase current inputs If the device features a sensitive ground current input measuring range starts at 1 mA the ground fault pro tection always uses the calculated variable 3I0 In thi...

Page 50: ... 3 00 1 73 Matching ratio Phase VT To Open Delta VT 209 PHASE SEQ A B C A C B A B C Phase Sequence 210A TMin TRIP CMD 0 01 32 00 sec 0 15 sec Minimum TRIP Command Duration 211A TMax CLOSE CMD 0 01 32 00 sec 1 00 sec Maximum Close Command Duration 212 BkrClosed I MIN 1A 0 04 1 00 A 0 04 A Closed Breaker Min Current Threshold 5A 0 20 5 00 A 0 20 A 213 VT Connect 3ph Van Vbn Vcn Vab Vbc VGnd Van Vbn ...

Page 51: ...onfiguration None 52 B Wear Open Cmd via Control Device 266 T 52 BREAKTIME 1 600 ms 80 ms Breaktime 52 Breaker 267 T 52 OPENING 1 500 ms 65 ms Opening Time 52 Break er 276 TEMP UNIT Celsius Fahrenheit Celsius Unit of temperature mea surement 280 Holmgr for Σi NO YES NO Holmgreen conn for fast sum i monit 613A 50N 51N 67N w Ignd measured 3I0 calcul Ignd measured 50N 51N 67N Ground Overcurrent with ...

Page 52: ...I and the graphic analysis software SIGRA 4 The latter graphically represents the data recorded during the system fault and also calculates additional information from the mea sured values Currents and voltages can be presented as desired as primary or secondary values Signals are additionally recorded as binary tracks marks e g pickup trip If the device has a serial system interface the fault rec...

Page 53: ...t history but also consumes storage capacity during the automatic reclosing dead time s The actual storage time begins at the pre fault time PRE TRIG TIME address 404 ahead of the reference instant and ends at the post fault time POST REC TIME address 405 after the storage criterion has reset The maximum storage time for each fault recording MAX LENGTH is entered in address 403 Recording per fault...

Page 54: ... 7SJ62 64 relays four independent setting groups A to D are available While setting values may vary the selected functions of each setting group remain the same 2 1 5 2 Setting Notes General If setting group change option is not required Group A is the default selection Then the rest of this section is not applicable If the changeover option is desired group changeover must be set to Grp Chge OPTI...

Page 55: ...onal measured value percentage For purposes of fault location a maximum of three different line sections can be considered For utilization in motors detection of the motor start represents an important feature Exceeding a configured current value serves as a criterion Addr Parameter Setting Options Default Setting Comments 302 CHANGE Group A Group B Group C Group D Binary Input Protocol Group A Ch...

Page 56: ...l faults that occur outside the defined line sections If several line sections are set the following shall apply for line section 1 addresses 6001 and 6002 for line section 2 addresses 6011 and 6012 for line section 3 the addresses 6021 and 6022 Resistance ratio RE RL and reactance ratio XE XL are calculated formally and do not correspond to the real and imaginary components of ZE ZL No complex ca...

Page 57: ...t length must be reconfigured in accordance with the new distance unit The values under address 1106 km or 1105 Miles apply if only one line section is available and to all faults that occur outside the defined line sections If several line sections are set the following shall apply for line section 1 addresses 6004 km or 6003 Miles for line section 2 addresses 6014 km or 6013 Miles for line secti...

Page 58: ...he ohmic resistance and XL being the reactance of the line The value under address 1109 applies if only one line section is available and to all faults that occur outside the defined line sections If several line sections are set the following shall apply for line section 1 address 6005 for line section 2 address 6015 for line section 3 address 6025 This data can be used for the entire line or lin...

Page 59: ... setting the following should be considered A setting must be selected that is lower than the actual motor start up current under all load and voltage conditions During motor start up the thermal replica of the overload protection is frozen i e kept at a constant level This threshold should not be set unnecessarily low since it limits the operating range of the overload protec tion for high curren...

Page 60: ...08 P Q sign not reversed reversed not reversed P Q operational measured values sign 1109 Line angle 10 89 85 Line angle 1110 Line length 0 1 1000 0 km 100 0 km Line length in kilometer 1111 Line length 0 1 650 0 Miles 62 1 Miles Line length in miles 6001 S1 RE RL 0 33 7 00 1 00 S1 Zero seq compensat ing factor RE RL 6002 S1 XE XL 0 33 7 00 1 00 S1 Zero seq compensat ing factor XE XL 6003 S1 x 0 00...

Page 61: ...les 6027 S3 Line length 0 1 1000 0 km 100 0 km S3 Line length in kilome ter No Information Type of In formation Comments 126 ProtON OFF IntSP Protection ON OFF via system port 356 Manual Close SP Manual close signal 501 Relay PICKUP OUT Relay PICKUP 511 Relay TRIP OUT Relay GENERAL TRIP command 533 Ia VI Primary fault current Ia 534 Ib VI Primary fault current Ib 535 Ic VI Primary fault current Ic...

Page 62: ...rallel to the process control integration of the device this interface can also be used for communication with DIGSI and for inter relay communication via GOOSE 2 1 7 2 Setting Notes Interface Selection No special settings are required for operating the Ethernet system interface module IEC 1850 EN100 Module If the ordered version of the device is equipped with such a module it is automatically all...

Page 63: ... calculated from the three phase currents Devices featuring a sensitive ground current input however generally use the calculated quantity 3I0 All overcurrent elements enabled in the device may be blocked via the automatic reclosing function depending on the cycle or via an external signal to the binary inputs of the device Removal of blocking during pickup will restart time delays The Manual Clos...

Page 64: ...tarted and maintains the pickup condition if the current falls below the threshold Therefore the function does not drop out at high speed The trip delay time 50 3 DELAY 50 2 DELAY or 50N 3 DELAY 50N 2 DELAY continues running in the meantime After the dropout delay time has elapsed the pickup is reported OFF and the trip delay time is reset unless the threshold 50 3 PICKUP 50 2 PICKUP or 50N 3 PICK...

Page 65: ... Figure 2 4 Logic diagram for 50 2 for phases If parameter MANUAL CLOSE is set to 50 2 instant or 50 3 instant and manual close detection is used a pickup causes instantaneous tripping even if the element is blocked via binary input The same applies to 79AR 50 2 inst w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 66: ...ure 2 5 Logic diagram for 50N 2 high set element If parameter MANUAL CLOSE is set to 50N 2 instant or 50N 3 instant and manual close detection is used a pickup causes instantaneous tripping even if the element is blocked via binary input The same applies to AR 50N 2 inst w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 67: ... can be stabilized by setting dropout times 1215 50 T DROP OUT or 1315 50N T DROP OUT This time is started and maintains the pickup condition if the current falls below the threshold Therefore the function does not drop out at high speed The trip command delay time 50 1 DELAY or 50N 1 DELAY continues running in the meantime After the dropout delay time has elapsed the pickup is reported OFF and th...

Page 68: ...tes if no inrush was detected An incoming inrush will reset a running dropout delay time If parameter MANUAL CLOSE is set to 50 1 instant and manual close detection is used a pickup causes instantaneous tripping even if blocking of the element via binary input is present The same applies to 79AR 50 1 inst Figure 2 7 Logic diagram of the dropout delay for 50 1 w w w E l e c t r i c a l P a r t M a ...

Page 69: ...conditions arrive even if the element is blocked via a binary input The same applies to 79 AR 50N 1 inst The pickup values of each 50 1 50 2 element for the phase currents and 50N 1 50N 2 element for the ground current and the valid delay times for each element can be set individually The dropout delay only functions if no inrush was detected An incoming inrush will reset a running dropout time de...

Page 70: ...t exceeds 1 1 times the setting value the corresponding element picks up and is signaled individually If the inrush restraint feature is used either the normal pickup signals or the corresponding inrush signals are issued as long as inrush current is detected If the 51 element picks up the tripping time is calculated from the actual fault current flowing using an integrating method of measurement ...

Page 71: ...am of the inverse time overcurrent protection element for phases If parameter MANUAL CLOSE is set to 51 instant and manual close detection applies the trip is initiated as soon as the pickup conditions arrive even if the element is blocked via a binary input The same applies to 79AR 51 inst w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 72: ...lue is undershot For a new pickup the time delay starts at zero The disk emulation evokes a dropout process timer counter is decrementing which begins after de energiza tion This process corresponds to the reset of a Ferraris disk explaining its denomination disk emulation In case several faults occur in succession the history is taken into consideration due to the inertia of the Fer raris disk an...

Page 73: ...ime overcurrent protection is provided with an undervoltage detection that can be disabled ad dress 1223 VOLT INFLUENCE This function can influence overcurrent detection by means of two different methods Voltage controlled If a set voltage threshold is undershot the overcurrent element is released Voltage restraint The pickup threshold of the overcurrent element depends on the voltage magnitude A ...

Page 74: ...s in relation to the fault currents In order to avoid an unwanted operation in case of a voltage transformer fault a function blocking is implement ed via a binary input controlled by the voltage transformer protection breaker as well as via the device internal measuring voltage failure detection Fuse Failure Monitor The following two figures show the logic diagrams for the inverse time overcurren...

Page 75: ...ection 50 51 50N 51N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 75 Figure 2 13 Logic diagram of the voltage controlled inverse time overcurrent protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 76: ...tection 50 51 50N 51N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 76 Figure 2 14 Logic diagram of the voltage restraint inverse time overcurrent protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 77: ...re generated These signals also initiate fault annunciations and start the associated trip delay time If inrush conditions are still present after the tripping time delay has elapsed a corresponding message Timeout is output but the overcurrent tripping is blocked see also logic diagrams of time overcurrent elements Figures 2 6 to 2 11 Inrush current contains a relatively large second harmonic com...

Page 78: ... exceeded for only one phase Please take into consideration that inrush currents flowing in the ground path will not cross block tripping by the phase elements Cross blocking is reset if there is no more inrush in any phase Furthermore the cross blocking function may also be limited to a particular time interval address 2204 CROSS BLK TIMER After expiry of this time interval the cross blocking fun...

Page 79: ... 2 2 Overcurrent Protection 50 51 50N 51N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 79 Figure 2 15 Logic diagram for inrush restraint w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 80: ...n Figure Output Annunciation FNo 50 3 A PU 50 2 A PU 50 1 A PU 51 A PU 2 4 2 6 2 10 50 51 Ph A PU 1762 50 3 B PU 50 2 B PU 50 1 B PU 51 B PU 2 4 2 6 2 10 50 51 Ph B PU 1763 50 3 C PU 50 2 C PU 50 1 C PU 51 B PU 2 4 2 6 2 10 50 51 Ph C PU 1764 50N 3 PU 50N 2 PU 50N 1 PU 51N PU 2 5 2 8 2 11 50N 51NPickedup 1765 50 3 A PU 50 3 B PU 50 3 C PU 50N 3 PU 50 3 picked up 1767 50 2 A PU 50 2 B PU 50 2 C PU ...

Page 81: ...tection Using Reverse Interlocking Application Example Each of the overcurrent elements can be blocked via binary inputs of the relay A setting parameter determines whether the binary input operates in the normally open i e actuated when energized or the normally closed i e actuated when de energized mode This allows for example the busbar protection to take immediate effect in star systems or loo...

Page 82: ...imposed high set elements 50 2 50 3 and 50N 2 50N 3 are available in all these cases Parameter 250 50 51 2 ph prot can also be set to activate two phase overcurrent protection Under address 1201 FCT 50 51 overcurrent protection for phases and under address 1301 FCT 50N 51N the ground overcurrent protection can be switched ON or OFF Pickup values time delays and characteristics for ground protectio...

Page 83: ...ata The type of the comparison values can be set under the following addresses 50 3 element Address 1219 50 3 measurem 50 2 element Address 1220 50 2 measurem 50 1 element Address 1221 50 1 measurem 51 element Address 1222 51 measurem 50N 3 element Address 1319 50N 3 measurem 50N 2 element Address 1320 50N 2 measurem 50N 1 element Address 1321 50N 1 measurem 51N element Address 1322 51N measurem H...

Page 84: ...is applied as a fast busbar protection with a shorter safety delay time 50 2 DELAY e g 100 ms For faults at the outgoing feeders element 50 2 is blocked Both element 50 1 or 51 serve as backup protection The pickup values of both elements 50 1 PICKUP or 51 PICKUP and 50 2 PICKUP are set equal Delay time 50 1 DELAY or 51 TIME DIAL is set in such manner that it overgrades the delay for the outgoing ...

Page 85: ...opout time The delay can be also be set to In this case the element will not trip after pickup However pickup will be signaled If the 50N 1 element is not required at all the pickup threshold 50N 1 PICKUP should be set to This setting prevents tripping and the generation of a pickup message Pickup Stabilization Definite Time The configurable dropout times 1215 50 T DROP OUT or 1315 50N T DROP OUT ...

Page 86: ...The current value is set in address 1307 51N PICKUP The setting is mainly determined by the minimum an ticipated ground fault current The corresponding time multiplier for an IEC characteristic is set at address 1308 51N TIME DIAL and in address 1309 51N TIME DIAL for an ANSI characteristic This has to be coordinated with the grading coor dination chart of the network For ground currents with grou...

Page 87: ... the smallest curve point will not lead to an extension of the tripping time The pickup curve see Figure 2 17 right side runs parallel to the current axis up to the smallest current value point Currents larger than the largest current value entered will not lead to a reduction of the tripping time The pickup curve see Figure 2 17 right side runs parallel to the current axis beginning with the grea...

Page 88: ... pairs measured quantity and trip time see Figure 2 18 In order to represent the characteristic graphically the user should click on characteristic The previously entered characteristic will appear as shown in Figure 2 18 The characteristic curve shown in the graph can be modified later on Placing the mouse cursor over a point on the characteristic the cursor changes to the shape of a hand Press a...

Page 89: ...nt of a phase blocks also the other phases for the specified duration If the current exceeds the value set in address 2205 I Max no further restraint will take place for the 2nd har monic Manual Close Mode phases ground When a circuit breaker is closed onto a faulted line a high speed trip by the circuit breaker is usually desired For overcurrent or high set element the delay may be bypassed via a...

Page 90: ...ted automatic reclosing function of 7SJ62 64 also provides the option to individually determine for each overcurrent element whether tripping or blocking is to be carried out instantaneously unaffected by the AR with the set time delay see Section 2 14 Interaction with the Automatic Reclosing Function ground When reclosing occurs it is desirable to have high speed protection against faults with 50...

Page 91: ...me Delay 1207 51 PICKUP 1A 0 10 4 00 A 1 00 A 51 Pickup 5A 0 50 20 00 A 5 00 A 1208 51 TIME DIAL 0 05 3 20 sec 0 50 sec 51 Time Dial 1209 51 TIME DIAL 0 50 15 00 5 00 51 Time Dial 1210 51 Drop out Instantaneous Disk Emulation Disk Emulation Drop out characteristic 1211 51 IEC CURVE Normal Inverse Very Inverse Extremely Inv Long Inverse Normal Inverse IEC Curve 1212 51 ANSI CURVE Very Inverse Inver...

Page 92: ... 50N 51N Ground Time Overcurrent 1302 50N 2 PICKUP 1A 0 05 35 00 A 0 50 A 50N 2 Pickup 5A 0 25 175 00 A 2 50 A 1303 50N 2 DELAY 0 00 60 00 sec 0 10 sec 50N 2 Time Delay 1304 50N 1 PICKUP 1A 0 05 35 00 A 0 20 A 50N 1 Pickup 5A 0 25 175 00 A 1 00 A 1305 50N 1 DELAY 0 00 60 00 sec 0 50 sec 50N 1 Time Delay 1307 51N PICKUP 1A 0 05 4 00 A 0 20 A 51N Pickup 5A 0 25 20 00 A 1 00 A 1308 51N TIME DIAL 0 05...

Page 93: ...amental 50N 3 measurement of 1320A 50N 2 measurem Fundamental True RMS Fundamental 50N 2 measurement of 1321A 50N 1 measurem Fundamental True RMS Fundamental 50N 1 measurement of 1322A 51N measurem Fundamental True RMS Fundamental 51N measurement of 1330 50N 51N 1 00 20 00 I Ip 0 01 999 00 TD 50N 51N 1331 MofPU Res T TEp 0 05 0 95 I Ip 0 01 999 00 TD Multiple of Pickup T TEp 2201 INRUSH REST OFF O...

Page 94: ...se A picked up 1763 50 51 Ph B PU OUT 50 51 Phase B picked up 1764 50 51 Ph C PU OUT 50 51 Phase C picked up 1765 50N 51NPickedup OUT 50N 51N picked up 1767 50 3 picked up OUT 50 3 picked up 1768 50N 3 picked up OUT 50N 3 picked up 1769 50 3 TRIP OUT 50 3 TRIP 1770 50N 3 TRIP OUT 50N 3 TRIP 1787 50 3 TimeOut OUT 50 3 TimeOut 1788 50N 3 TimeOut OUT 50N 3 TimeOut 1791 50 N 51 N TRIP OUT 50 N 51 N TR...

Page 95: ...ed up 7551 50 1 InRushPU OUT 50 1 InRush picked up 7552 50N 1 InRushPU OUT 50N 1 InRush picked up 7553 51 InRushPU OUT 51 InRush picked up 7554 51N InRushPU OUT 51N InRush picked up 7556 InRush OFF OUT InRush OFF 7557 InRush BLK OUT InRush BLOCKED 7558 InRush Gnd Det OUT InRush Ground detected 7559 67 1 InRushPU OUT 67 1 InRush picked up 7560 67N 1 InRushPU OUT 67N 1 InRush picked up 7561 67 TOC I...

Page 96: ...r may be disabled Additionally individual elements e g 67 2 and or 67N 2 may be interconnected with the directional overcurrent protection For parallel lines or transformers supplied from a single source only directional overcurrent protection allows selective fault detection For line sections supplied from two sources or in ring operated lines the overcurrent protection has to be supplemented by ...

Page 97: ...Manual Close signal is an exception If a circuit breaker is manually closed onto a fault it can be re opened immediately For over current elements or high set elements the delay may be bypassed via a Manual Close pulse thus resulting in high speed tripping Furthermore immediate tripping may be initiated in conjunction with the automatic reclosing function cycle de pendant Pickup stabilization for ...

Page 98: ...ondition if the current falls below the threshold Therefore the function does not drop out at high speed The trip command delay time 50 2 DELAY or 50N 2 DELAY continues in the meantime After the dropout delay time has elapsed the pickup is reported OFF and the trip delay time is reset unless the threshold 50 2 PICKUP or 50N 2 PICKUP has been exceeded again If the threshold is ex ceeded again durin...

Page 99: ...re 2 22 Logic diagram for directional high set element 67 2 for phases If parameter MANUAL CLOSE is set to 67 2 instant and manual close detection applies the pickup is tripped instantaneously also if the element is blocked via binary input The same applies to 79 AR 67 2 inst w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 100: ...d by setting dropout times 1518 67 T DROP OUT or 1618 67N T DROP OUT This time is started and maintains the pickup condition if the current falls below the threshold Therefore the function does not drop out at high speed The trip command delay time 50 1 DELAY or 50N 1 DELAY continues in the meantime After the dropout delay time has elapsed the pickup is reported OFF and the trip delay time is rese...

Page 101: ...0 C207 2 Release date 01 2008 101 Figure 2 23 Logic diagram for the directional relay element 67 1 for phases The dropout delay does only function if no inrush was detected An approaching inrush resets an already running dropout time delay w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 102: ...sued assuming that no inrush current is detected or inrush restraint is disabled If the inrush restraint feature is enabled and an inrush condi tion exists no tripping takes place but a message is recorded and displayed indicating when the overcurrent element time delay elapses For ground current element 67N TOC the characteristic may be selected independently of the characteristic used for phase ...

Page 103: ... the overcurrent protection must be coordinated with conventional electromechanical overcurrent relays located towards the source If no user defined dropout curve is required the element drops out as soon as the measured signal is less than approx 95 of the pickup setting When a new pickup is evoked the timer starts at zero again The following figure shows by way of an example the logic diagram fo...

Page 104: ...up function After detection of inrush currents above a pickup value special inrush signals are generated These signals also initiate fault annunciations and start the associated trip delay time If inrush conditions are still present after the tripping time delay has elapsed a corresponding message TimeOut is output but the overcurrent tripping is blocked for further information see Inrush Restrain...

Page 105: ...ence voltage the negative sequence voltage are used for the direction determination This is advantageous if the zero sequence is influenced via a parallel line or if the zero voltage becomes very small due to unfavorable zero impedances The negative sequence system is calculated from the individual voltages and currents As with the use of the zero sequence values a direction determina tion is carr...

Page 106: ...r the di rection determination Figure 2 27 clearly shows the relationship for the directional phase element based on a single pole ground fault in Phase A The fault current IscA follows the fault voltage by fault angle ϕsc The refer ence voltage in this case VBC for the directional phase element A is rotated by the setting value 1519 ROTATION ANGLE positively counter clockwise In this case a rotat...

Page 107: ...l ground element also based on a single pole ground fault in Phase A Contrary to the directional phase elements which work with the unfaulted voltage as reference voltage the fault voltage itself is the reference voltage for the directional ground element Depending on the connection of the voltage transformer this is the voltage 3V0 as shown in Figure 2 29 or VN The fault current 3I0 is phase offs...

Page 108: ...orm reverse interlock ing also on double end fed lines using relay element 67 1 It is designed to selectively isolate a faulty line section e g sections of rings in high speed i e no long graded times will slow down the process This scheme is feasible when the distance between protective relays is not too great and when pilot wires are available for signal transfer via an auxiliary voltage loop Fo...

Page 109: ...end of the same feeder In addition a Reverse message is generated and transmitted via the auxiliary voltage loop to the relay located at the opposite end of the line Figure 2 31 Reverse interlocking using directional elements The directional overcurrent element providing normal time grading operates as selective backup protection The following figure shows the logic diagram for the generation of f...

Page 110: ...pendent of the directional phase time overcurrent protection Depending on the parameter 613 50N 51N 67N w the device can either operate using measured values IN or the quantities 3I0 calculated from the three phase currents Devices featuring a sensitive ground current input generally use the calculated quantity 3I0 The directional orientation of the function is influenced by parameter 201 CT Starp...

Page 111: ... the short circuit voltage For this reason the resulting setting of the angle of rotation is see also Section 2 3 8 With the ground directional element the reference voltage is the short circuit voltage itself The resulting setting of the angle of rotation is then It should also be noted for phase directional elements that with phase to phase faults the reference voltage is rotated between 0 remot...

Page 112: ...ing the latter is to be selected in case of danger that the zero voltage be too small due to unfavourable zero impedance or that a parallel line influences the zero system 67 2 Directional High set Element phases The pickup and delay of element 67 2 are set at addresses 1502 and 1503 For setting the same consider ations apply as did for the non directional time overcurrent protection in Section 2 ...

Page 113: ...ed to protect transformers or motors with large inrush currents the inrush restraint feature of 7SJ62 64 may be used for the 67N 1 relay element for more information see margin heading Inrush Re straint The delay is set at address 1605 67N 1 DELAY and should be based on system coordination requirements for directional tripping For ground currents in a grounded system a separate coordination chart ...

Page 114: ... value 67N TOC PICKUP This means that a pickup will only occur if a current of about 1 1 times the setting value is present If Disk Emulation was selected at address 1610 67N TOC DropOut reset will occur in accordance with the reset curve as for the existing non directional time overcurrent protection described in Section 2 2 The current value is set at address 1607 67N TOC PICKUP The minimum appe...

Page 115: ...r defined tripping curves The value pairs are entered at address 1531 MofPU Res T Tp to recreate the reset curve The following must be observed The current values entered should be those from Table 2 9 along with the matching times Deviating values I Ip are rounded This however will not be indicated Current flows greater than the highest current value entered will not lead to a prolongation of the...

Page 116: ...rent or high set element the delay may be bypassed via a Manual Close pulse thus resulting in instan taneous tripping This pulse is prolonged by at least 300 ms To enable the device to react properly on occur rence of a fault in the phase elements after manual close address 1513 MANUAL CLOSE has to be set accord ingly Accordingly address 1613 MANUAL CLOSE is considered for the ground path address ...

Page 117: ...blocked If this is not desired the setting always is selected so that the 67 2 elements are always active as configured The integrated automatic reclosing function of 7SJ62 64 also provides the option to individually determine for each time overcurrent element whether instantaneous tripping i e normal time delayed tripping unaffected by the automatic reclosing or blocking shall take place see Sect...

Page 118: ...00 A 67 TOC Pickup 5A 0 50 20 00 A 5 00 A 1508 67 TIME DIAL 0 05 3 20 sec 0 50 sec 67 TOC Time Dial 1509 67 TIME DIAL 0 50 15 00 5 00 67 TOC Time Dial 1510 67 TOC Drop out Instantaneous Disk Emulation Disk Emulation Drop Out Characteristic 1511 67 IEC CURVE Normal Inverse Very Inverse Extremely Inv Long Inverse Normal Inverse IEC Curve 1512 67 ANSI CURVE Very Inverse Inverse Short Inverse Long Inv...

Page 119: ...9 67N TOC T DIAL 0 50 15 00 5 00 67N TOC Time Dial 1610 67N TOC DropOut Instantaneous Disk Emulation Disk Emulation Drop Out Characteristic 1611 67N TOC IEC Normal Inverse Very Inverse Extremely Inv Long Inverse Normal Inverse IEC Curve 1612 67N TOC ANSI Very Inverse Inverse Short Inverse Long Inverse Moderately Inv Extremely Inv Definite Inv Very Inverse ANSI Curve 1613A MANUAL CLOSE 67N 2 instan...

Page 120: ...ward OUT Phase B forward 2630 Phase C forward OUT Phase C forward 2632 Phase A reverse OUT Phase A reverse 2633 Phase B reverse OUT Phase B reverse 2634 Phase C reverse OUT Phase C reverse 2635 Ground forward OUT Ground forward 2636 Ground reverse OUT Ground reverse 2637 67 1 BLOCKED OUT 67 1 is BLOCKED 2642 67 2 picked up OUT 67 2 picked up 2646 67N 2 picked up OUT 67N 2 picked up 2647 67 2 Time ...

Page 121: ...67N 2 TRIP 2681 67N 1 picked up OUT 67N 1 picked up 2682 67N 1 Time Out OUT 67N 1 Time Out 2683 67N 1 TRIP OUT 67N 1 TRIP 2684 67N TOCPickedup OUT 67N TOC picked up 2685 67N TOC TimeOut OUT 67N TOC Time Out 2686 67N TOC TRIP OUT 67N TOC TRIP 2687 67N TOC Disk PU OUT 67N TOC disk emulation is ACTIVE 2691 67 67N pickedup OUT 67 67N picked up 2692 67 A picked up OUT 67 67 TOC Phase A picked up 2693 6...

Page 122: ...d after its expiration the increased thresholds take effect In addition switching between parameters can be triggered by two further events by signal 79M Auto Reclosing ready of the internal automatic reclosure function address 1702 Start Condition 79 ready Thus the protection thresholds and the tripping times can be changed if auto matic reclosure is ready for reclosing see also Section 2 14 Irre...

Page 123: ...red timers are reset and as a consequence all normal settings are immediately restored If blocking occurs during an on going fault with dynamic cold load pickup functions enabled the timers of all non directional overcurrent relay elements are stopped and may then be restarted based on their normal duration During power up of the protective relay with an open circuit breaker the time delay CB Open...

Page 124: ...Load Pickup SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 124 Figure 2 36 Logic diagram of the dynamic cold load pickup function 50c 50Nc 51c 51Nc 67c 67Nc w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 125: ... based on the specific loading characteristics of the equipment being protected and should be set to allow for brief overloads associated with dynamic cold load conditions Non Directional 50 51 Elements phases The dynamic pickup values and tripping times associated with the time overcurrent protection functions are set at address block 18 for the phase currents The dynamic pickup and delay setting...

Page 126: ...re set at addresses 2103 67Nc 1 PICKUP and 2104 67Nc 1 DELAY respectively and the pickup time mul tiplier for IEC curves or user defined curves and time dial for ANSI curves settings for the 67N TOC element are set at addresses 2105 67Nc TOC PICKUP 2106 67Nc TOC T DIAL 2107 67Nc TOC T DIAL respec tively 2 4 3 Settings The table indicates region specific default settings Column C configuration indi...

Page 127: ...0 35 00 A 10 00 A 67c 2 Pickup 5A 0 50 175 00 A 50 00 A 2002 67c 2 DELAY 0 00 60 00 sec 0 00 sec 67c 2 Time Delay 2003 67c 1 PICKUP 1A 0 10 35 00 A 2 00 A 67c 1 Pickup 5A 0 50 175 00 A 10 00 A 2004 67c 1 DELAY 0 00 60 00 sec 0 30 sec 67c 1 Time Delay 2005 67c TOC PICKUP 1A 0 10 4 00 A 1 50 A 67c Pickup 5A 0 50 20 00 A 7 50 A 2006 67c TOC T DIAL 0 05 3 20 sec 0 50 sec 67c Time Dial 2007 67c TOC T D...

Page 128: ...CK CLP SP BLOCK Cold Load Pickup 1731 BLK CLP stpTim SP BLOCK Cold Load Pickup stop timer 1732 ACTIVATE CLP SP ACTIVATE Cold Load Pickup 1994 CLP OFF OUT Cold Load Pickup switched OFF 1995 CLP BLOCKED OUT Cold Load Pickup is BLOCKED 1996 CLP running OUT Cold Load Pickup is RUNNING 1997 Dyn set ACTIVE OUT Dynamic settings are ACTIVE w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 129: ... of the high sen sitivity a particularly narrow band filter is used The current pickup thresholds and tripping times can be set The detected current is compared to the pickup value 50 1Ph 1 PICKUP or 50 1Ph 2 PICKUP and reported if this is violated After expiry of the respective delay time 50 1Ph 1 DELAY or 50 1Ph 2 DELAY the trip command is issued The two elements together form a two stage protec...

Page 130: ...ual C53000 G1140 C207 2 Release date 01 2008 130 The following figure shows the logic diagram of the single phase overcurrent protection function Figure 2 38 Logic diagram of the single phase time overcurrent protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 131: ...where else Figure 2 39 Ground fault protection according to the high impedance principle Function of the High Impedance Principle The high impedance principle is explained on the basis of a grounded transformer winding No zero sequence current will flow during normal operation i e the starpoint current is ISP 0 and the phase currents are 3 I0 IA IB IC 0 In case of an external ground fault left in ...

Page 132: ...very lowest ground fault current to be detected it gen erates a secondary voltage which is equal to half the saturation voltage of current transformers see also notes on Dimensioning in Subsection 2 5 4 High impedance Protection with 7SJ62 64 With 7SJ62 64 the sensitive measurement input INs or alternatively the insensitive measurement input IN is used for high impedance protection As this is a cu...

Page 133: ...e is connected to the parallel connection of all feeder current transformers via the resistor 2 5 3 Tank Leakage Protection Application Example The tank leakage protection has the task to detect ground leakage even high ohmic between a phase and the frame of a power transformer The tank must be isolated from ground A conductor links the tank to ground and the current through this conductor is fed ...

Page 134: ...notes are given in the following for the use as high impedance unit protection and tank leakage protec tion Application as High impedance Protection The application as high impedance protection requires that starpoint current detection is possible in the system in addition to phase current detection see example in Figure 2 41 Furthermore a sensitive input transformer must be available at device in...

Page 135: ...nts In theory this is the most unfavorable case Since in practice it is also the saturated transformer which supplies current an automatic safety margin is guaranteed Figure 2 43 shows a simplified equivalent circuit CT1 and CT2 are assumed as ideal transformers with their inner resistances R i1 and R i2 Ra are the resistances of the connecting cables between current transformers and resistor R Th...

Page 136: ...mm2 cross section results in Ra 0 75 Ω that is 27 rated current or 21 6 kA primary Sensitivity with High impedance Protection The voltage present at the CT set is forwarded to the protective relay across a series resistor R as proportional current for evaluation The following considerations are relevant for dimensioning the resistor As already mentioned it is desired that the high impedance protec...

Page 137: ...iod of time the rated power can be smaller by approx factor 5 Please bear in mind that when choosing a higher pickup value Ipu the resistance must be decreased and in doing so power loss will increase significantly The varistor B see following figure must be dimensioned such that it remains high resistive until reaching knee point voltage e g approx 100 V for 5 A CT approx 500 V for 1 A CT Figure ...

Page 138: ...currents at half the knee point voltage corresponds to the setting value have to be summed up These magnetizing currents reduce the current through the resistor R Therefore the actual pickup value will be cor respondingly higher Application as Tank Leakage Protection The use as tank leakage protection requires that a sensitive input transformer is available at the device input IN INS In this case ...

Page 139: ...5 00 A 0 20 A 50 1Ph 1 Pickup 5A 0 25 175 00 A 1 00 A 2706 50 1Ph 1 PICKUP 0 003 1 500 A 0 100 A 50 1Ph 1 Pickup 2707 50 1Ph 1 DELAY 0 00 60 00 sec 0 50 sec 50 1Ph 1 Time Delay No Information Type of In formation Comments 5951 BLK 50 1Ph SP BLOCK 50 1Ph 5952 BLK 50 1Ph 1 SP BLOCK 50 1Ph 1 5953 BLK 50 1Ph 2 SP BLOCK 50 1Ph 2 5961 50 1Ph OFF OUT 50 1Ph is OFF 5962 50 1Ph BLOCKED OUT 50 1Ph is BLOCKE...

Page 140: ...onnection the connection type was specified during configuration in address 213 VT Connect 3ph If there is only one voltage transformer the device has to be informed of this fact during configuration via address 240 VT Connect 1ph see also Section 2 24 The following table indicates which voltages can be evaluated by the function The settings for this are carried out in the P System Data 1 see Sect...

Page 141: ...imum current level BkrClosed I MIN are exceeded Here the largest of the three phase currents is used When the current decreases below the minimum current setting after the circuit breaker has opened undervoltage protection drops out Note If parameter CURRENT SUPERV is set to disabled in address 5120 the device picks up immediately without measurement voltage and the undervoltage protection functio...

Page 142: ...e switchoff is performed with a longer time delay When one of the adjustable settings is exceeded the 59 element picks up and trips after an adjustable time delay has elapsed The time delay is not dependent on the magnitude of the overvoltage The dropout ratio for the two overvoltage elements Vdropout value Vpickup value can be set The following figure shows the logic diagram of the overcurrent pr...

Page 143: ... been opened current supervision CS described above is not necessary in this case After the voltage has dropped below the pickup setting tripping is initiated after time delay 27 1 DELAY As long as the voltage remains below the dropout setting reclosing is blocked Only after the fault has been cleared i e when the voltage increases above the dropout level the element drops out and allows reclosing...

Page 144: ... for a short period of time If the voltage cri terion drops out during this time period about 60 ms the protection function does not pick up Thereby no fault record is created when voltage protection is activated in a healthy system It is important to understand how ever that if a low voltage condition exists on the load after the circuit breaker is closed unlike Figure 2 47 the desired pickup of ...

Page 145: ...62 64 Manual C53000 G1140 C207 2 Release date 01 2008 145 The following Figure shows the logic diagram of the undercurrent protection function Figure 2 48 Logic diagram of the undervoltage protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 146: ... 5006 59 2 PICKUP a shorter address 5007 59 2 DELAY time delay There are no specific procedures on how the pickup values are set However as the function is mainly used to prevent high insulation damage to system components and users the threshold value 5002 5003 59 1 PICKUP lies generally between 110 and 115 of the nominal voltage and setting value 5005 5006 59 2 PICKUP at approximately 130 The ti...

Page 147: ...0 V with connection of phase to phase voltages and phase to ground voltages or r configured pickup threshold 260 V with calculation of the measured values from the connected voltages e g phase to phase voltages calculated from the connected phase to ground voltages The minimum hysteresis is 0 6 V Undervoltage Protection Positive Sequence System V1 The positive sequence component V1 can be evaluate...

Page 148: ...lected such that tripping occurs in response to voltage dips that lead to unstable operating conditions On the other hand the time delay should be long enough to avoid tripping on short term voltage dips Note During configuration of a single phase voltage transformer connection parameter 240 VT Connect 1ph not equal to NO parameters 213 VT Connect 3ph and 615 OP QUANTITY 27 are not evaluated In th...

Page 149: ...GSI and via communication from the control center by means of a tagging command for blocking the voltage protection This causes the dropout of the pickup and parameterization can be resumed Please note that pickup threshold BkrClosed I MIN is used in other protective functions as well including overload protection restart inhibit for motors dynamic cold load pickup and circuit breaker maintenance ...

Page 150: ... 27 2 SP BLOCK 27 2 Undervoltage protection 6513 BLOCK 59 SP BLOCK 59 overvoltage protection 6530 27 OFF OUT 27 Undervoltage protection switched OFF 6531 27 BLOCKED OUT 27 Undervoltage protection is BLOCKED 6532 27 ACTIVE OUT 27 Undervoltage protection is ACTIVE 6533 27 1 picked up OUT 27 1 Undervoltage picked up 6534 27 1 PU CS OUT 27 1 Undervoltage PICKUP w curr superv 6537 27 2 picked up OUT 27...

Page 151: ...upply voltage it is endangered by thermal overload Due to the small negative sequence reactance even small voltage asymmetries lead to negative sequence currents In addition this protection function may be used to detect interruptions short circuits and polarity problems with current transformers It is also useful in detecting single pole and two pole faults with fault currents lower than the maxi...

Page 152: ...ates with IEC or ANSI character istic tripping curves The curves and associated formulas are given in the Technical Data When programming the inverse time characteristic also definite time elements 46 2 PICKUP and 46 1 PICKUP are available see aforegoing paragraph Pickup and Tripping The negative sequence current I2 is compared to the setting value 46 TOC PICKUP When the negative se quence current...

Page 153: ...se is adapted This ensures a proper simulation of the temperature rise of the protected object even for extremely fluctuating unbalanced load values Reset begins as soon as 90 of the setting value is undershot in accordance with the dropout curve of the selected characteristic In the range between the dropout value 95 of the pickup value and 90 of the setting value the incrementing and the decre m...

Page 154: ...ess the threshold has been exceeded again If the threshold is exceeded again during the dropout delay time the time is cancelled The trip command delay time continues running Should the threshold value be exceeded after its expiry the trip command is issued immediately If the threshold value is not exceeded at this time there will be no reaction If the threshold value is exceeded again after expir...

Page 155: ...ne current For the setting values at the protection device this information is con verted to the secondary inverse current The following applies with I2 perm prim permissible thermal inverse current of the motor INom Motor Nominal Motor Current ICT sec Secondary Nominal Current of the Current Transformer ICT prim Primary nominal current of the current transformer Definite Time Elements The unbalan...

Page 156: ... delta wye transform ers where low side phase to ground faults do not generate high side zero sequence currents e g vector group Dy Since transformers transform symmetrical currents according to the transformation ratio CTR the relationship between negative sequence currents and total fault current for phase to phase faults and phase to ground faults are valid for the transformer as long as the tu...

Page 157: ...ting value 46 TOC PICKUP is present address 4008 The dropout is performed as soon as the value falls below 95 of the pickup value The associated time multiplier is entered at address 4010 46 TOC TIMEDIAL The time multiplier can also be set to After pickup the element will then not trip Pickup however will be signaled If the inverse time element is not required at all address 140 46 should be set t...

Page 158: ...50 sec 46 2 Time Delay 4006 46 IEC CURVE Normal Inverse Very Inverse Extremely Inv Extremely Inv 46 IEC Curve 4007 46 ANSI CURVE Extremely Inv Inverse Moderately Inv Very Inverse Extremely Inv 46 ANSI Curve 4008 46 TOC PICKUP 1A 0 10 2 00 A 0 90 A 46 TOC Pickup 5A 0 50 10 00 A 4 50 A 4009 46 TOC TIMEDIAL 0 50 15 00 5 00 46 TOC Time Dial 4010 46 TOC TIMEDIAL 0 05 3 20 sec 0 50 sec 46 TOC Time Dial ...

Page 159: ...of these starting attempts are lengthened e g by excessive voltage surges during motor starting by excessive load moments or by blocked rotor conditions a trip signal will be initiated by the protective relay Motor starting is detected when a settable current threshold I MOTOR START is exceeded Calculation of the tripping time is then initiated It should be noted that this timer starts every time ...

Page 160: ...102 then the actual tripping time tTrip is prolonged or shortened ac cordingly see Figure 2 52 Definite Time Overcurrent Tripping Characteristic Locked Rotor Time Tripping must be executed when the actual motor starting time exceeds the maximum allowable locked rotor time if the rotor is locked The device can be informed about the locked rotor condition via the binary input Rotor locked e g from a...

Page 161: ...ckup annunciations The following figure illustrates the logic of motor starting protection A pickup does not create messages in the trip log buffer Fault recording is not started until a trip command has been issued When the function drops out all timers are reset The annunciations disap pear and a trip log is terminated should it have been created Figure 2 53 Logic diagram of the Motor Starting P...

Page 162: ...r address 4101 48 Startup Parameter The device is informed of the startup current values under normal conditions at address 4102 STARTUP CURRENT the startup time at address 4103 STARTUP TIME At all times this enables timely tripping if the value I2t calculated in the protection device is exceeded If the startup time is longer than the permissible blocked rotor time an external rpm counter can init...

Page 163: ...loads the value for motor startup I MOTOR START set at address 1107 may be an average value Based on the Long Term Current Rating For ratios deviating from nominal conditions the motor tripping time changes At 80 of nominal voltage which corresponds to 80 of nominal starting current the tripping time is After the time delay 4104 LOCK ROTOR TIME has elapsed the binary input becomes effective and ge...

Page 164: ... MOTOR 25 Should the technical data of the motor make reference to four cold and two warm startups ncold 4 nwarm 2 the following limit value can be determined The setting value should fall below the limit value A value of 40 is recommended for that purpose Note Overload protection curves are also effective during motor starting conditions However the thermal profile during motor starting is consta...

Page 165: ... Therefore the 7SJ62 64 relays feature the motor restart inhibit which outputs a blocking command until a new motor startup is permitted for the deactivated motor restarting limit The blocking signal must be configured to a binary output relay of the device whose contact is inserted in the motor starting circuit Determining the Rotor Overtemperature Since the rotor current cannot be measured direc...

Page 166: ...different maximum temperatures in the the rotor are not pertinant for motor restart inhibit see Figure 2 54 It is much more impor tant to establish a thermal replica after a complete motor start that is appropriate for the protection of the motor s thermal condition Figure 2 54 shows as an example the heating processes during repeated motor starts three starts from cold operating condition as well...

Page 167: ...estart to ensure that the rotor has cooled off operational measured value 661 Equilibrium Time This thermal behavior is provided for in the protection as follows Each time the motor is shut down the timer starts address 4304 T Equal It takes into account the different thermal conditions of the motor parts at the moment of shutdown During the equilibrium time the thermal replica of the rotor is not...

Page 168: ...alue for the waiting time has reached zero Extension of Cool Down Time Constants In order to properly account for the reduced heat exchange when a self ventilated motor is stopped the cool down time constants can be increased relative to the time constants for a running machine with the factor Kτ at STOP address 4308 The criterion for the motor stop is the undershooting of a set current threshold ...

Page 169: ...l can be removed via a binary input 66 emer start thus allowing a new starting attempt The thermal rotor profile however continues to function and the maximum allowable rotor temperature will be exceeded No motor shutdown will be initiated by the motor restart inhibit but the cal culated excessive temperature of the rotor can be observed for risk assessment Blocking If the motor restart inhibit fu...

Page 170: ...unctions 2 8 Motor Protection SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 170 Figure 2 55 Logic diagram for the restart inhibit w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 171: ...al lowable starting time T START MAX address 4303 the number of allowable starts from cold conditions ncold and the number of allowable starts from warm conditions nwarm The starting current is entered at address 4302 IStart IMOTnom expressed as a multiple of nominal motor current In contrast the nominal motor current is entered as a secondary value directly in amperes at address 4305 I MOTOR NOMI...

Page 172: ...IBIT 6 0 min The motor manufacturer s or the requirements also determine also the extension factor for the time constant during cool down especially with the motor stopped Where no other specifications are made the following settings are recommended Kτ at STOP 5 and Kτ at RUNNING 2 For a proper functioning it is also important that the CT values and the current threshold for distinction between st...

Page 173: ...e range below the thermal restarting limit and the machine is stopped The stop launches the equilibrium time 4304 T Equal and generates the message 66 TRIP The equilibrium time expires and the message 66 TRIP is cleared During the time T Equal the thermal replica remains frozen see Figure 2 56 on the left 2 A normal startup brings the machine into a temperature range below the thermal restarting l...

Page 174: ...falls below the tem perature limit is the decisive factor for clearing the message 66 TRIP The thermal replica remains fro zen while the equilibrium time expires see Figure 2 57 to the left 2 A startup brings the machine from load operation into a temperature range just above the thermal restarting limit and the machine is stopped The minimum inhibit time and the equilibrium time are started and 6...

Page 175: ...ocked rotor quicker thus reducing possible damage to the motor and powered equipment 2 8 3 1 Mode of Operation Principle of Operation Figure 2 58 illustrates the feature of an asynchronous cage motor Nominal current is flowing at normal load If the load is increased the current flow also increases and the speed decreases Above a certain load however the motor is no longer able to adjust the speed ...

Page 176: ... The threshold value comparison is blocked during the motor startup phase as the startup currents usually move in a size similar to the occurring currents when a rotor is locked The algorithm verifies the motor standstill according to currents and if available the message 52 a As soon as a current increase is applied after detection of the motor standstill the load jam protection is tempo rarily b...

Page 177: ...ctions 2 8 Motor Protection SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 177 Figure 2 60 Logic diagram of the load jam protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 178: ... circuit breaker is detected during current flow measurement motor standstill In this condition the load change protection is blocked After having closed the circuit breaker the blocking is maintained during motor startup by the setting 4406 T Start Blk In order to avoid malfunctioning the T Start Blk is set to the double startup time Motor Protection Example Figure 2 61 illustrates an example of ...

Page 179: ...ault setting of 1 s The warning threshold is set to 75 of the trip ping element 4404 I Alarm 0 95 A sec The tripping delay time can remain at the default setting of 2 s In order to block the function during motor startup the parameter 4406 T Start Blk is set to double startup time T Start Blk 2 8 5 s 17 s Nominal voltage VNom 6600 V Nominal current INom 126 A Long term current rating Imax 135 A St...

Page 180: ...ec Startup Time 4104 LOCK ROTOR TIME 0 5 180 0 sec 2 0 sec Permissible Locked Rotor Time 4105 STARTUP T WARM 0 5 180 0 sec 10 0 sec Startup Time for warm motor 4106 TEMP COLD MOTOR 0 80 25 Temperature limit for cold motor 4301 FCT 66 OFF ON OFF 66 Startup Counter for Motors 4302 IStart IMOTnom 1 10 10 00 4 90 I Start I Motor nominal 4303 T START MAX 1 320 sec 10 sec Maximum Permissible Starting Ti...

Page 181: ...6 Motor start protection TRIP 4828 66 RM th repl SP 66 Reset thermal memory 4829 66 RM th repl OUT 66 Reset thermal memory 4834 66 OVERL TRIP OUT 66 Rotor overload TRIP 4835 66 OVERL ALARM OUT 66 Rotor Overload Alarm 6801 BLK START SUP SP BLOCK Startup Supervision 6805 Rotor locked SP Rotor locked 6811 START SUP OFF OUT Startup supervision OFF 6812 START SUP BLK OUT Startup supervision is BLOCKED ...

Page 182: ...ncy is derived from the phase to phase voltages VA B applied to the device If the amplitude of this voltage is too low one of the other phase to phase voltages is used instead Through the use of filters and repeated measurements the frequency evaluation is free from harmonic influ ences and very accurate Frequency Increase and Decrease Frequency protection consists of four frequency elements To ma...

Page 183: ... 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 183 The following figure shows the logic diagram for the frequency protection function Figure 2 62 Logic diagram of the frequency protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 184: ...o the frequency values to be set mainly depend on the specifications of the power system power station operator The underfrequency protection safe guards the power station s own demand by disconnecting it from the power system on time The turbo governor regulates the machine set to the nominal speed Consequently the station s own demands can be continuously supplied at nominal frequency Under the ...

Page 185: ...ICKUP 50 00 70 00 Hz 59 00 Hz 81 2 Pickup 5408 81 2 DELAY 0 00 100 00 sec 30 00 sec 81 2 Time Delay 5409 81 3 PICKUP 40 00 60 00 Hz 47 50 Hz 81 3 Pickup 5410 81 3 PICKUP 50 00 70 00 Hz 57 50 Hz 81 3 Pickup 5411 81 3 DELAY 0 00 100 00 sec 3 00 sec 81 3 Time delay 5412 81 4 PICKUP 40 00 60 00 Hz 51 00 Hz 81 4 Pickup 5413 81 4 PICKUP 50 00 70 00 Hz 61 00 Hz 81 4 Pickup 5414 81 4 DELAY 0 00 100 00 sec...

Page 186: ...OCK 81 3 5209 BLOCK 81 4 SP BLOCK 81 4 5211 81 OFF OUT 81 OFF 5212 81 BLOCKED OUT 81 BLOCKED 5213 81 ACTIVE OUT 81 ACTIVE 5214 81 Under V Blk OUT 81 Under Voltage Block 5232 81 1 picked up OUT 81 1 picked up 5233 81 2 picked up OUT 81 2 picked up 5234 81 3 picked up OUT 81 3 picked up 5235 81 4 picked up OUT 81 4 picked up 5236 81 1 TRIP OUT 81 1 TRIP 5237 81 2 TRIP OUT 81 2 TRIP 5238 81 3 TRIP OU...

Page 187: ...replica may take the actual ambient or coolant tem perature into account 2 10 1 Description Thermal Replica The device calculates the overtemperature in accordance with a single body thermal replica based on the fol lowing differential equation with Θ Present overtemperature related to the final overtemperature at maximum allowed phase current k INom Obj τth Thermal time constant of the protected ...

Page 188: ...For this purpose the required temperature detector is connected to detector input 1 of the first RTD box corre sponds to RTD 1 If incorrect temperature values are measured or there are disturbances between the RTD box and the device an alarm will be issued and the standard temperature of Θu 40 C is used for calculation with the ambient temperature detection simply being ignored When detecting the ...

Page 189: ...n on time interval T EMERGENCY which is started when the binary input drops out and continues suppressing a trip signal Tripping via the overload pro tection is suppressed until this time interval has elapsed The binary input affects only the trip command There is no effect on the trip log nor does the thermal replica reset Behavior in Case of Power Supply Failure Depending on the setting in addre...

Page 190: ...2 10 Thermal Overload Protection 49 SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 190 Figure 2 63 Logic diagram of the overload protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 191: ...ON tripping trip log and fault recording is possible When setting Alarm Only no trip command is given no trip log is initiated and no spontaneous fault annun ciation is shown on the display Note Changing the function parameters resets the thermal replica The thermal model is frozen kept constant as soon as the current exceeds the setting value 1107 I MOTOR START Overload Parameter k factor The ove...

Page 192: ...heat gain time constant τ is determined by cable specifications and by the cable en vironment If no time constant specification is available it may be determined from the short term load capa bility of the cable The 1 sec current i e the maximum current permissible for a one second period of time is often known or available from tables Then the time constant may be calculated with the formula If t...

Page 193: ...t k IN sec It can be used instead of the thermal warning element by setting the thermal warning element to 100 thus virtually disabling it Extension of Time Constants TIME CONSTANT set in address 4203 is valid for a running motor When a motor without external cooling is running down or at standstill the motor cools down more slowly This behavior can be modeled by increasing the time constant by fa...

Page 194: ... current the temperature must be adapted according to the formula following In address 4209 or 4210 49 TEMP RISE I the temperature adapted to the nominal transformer current is set This setting value is used as standardization quantity for the ambient temperature input with ΘNomsec Machine temperatur at secondary nominal current setting at the protection device address 4209 or 4210 ΘNom Mach Machi...

Page 195: ...perature at INom Mach τth 600 s thermal time constant of the machine Current transformer 500 A 1 A Motor Starting Recognition The motor starting is detected when setting I MOTOR START at address 1107 is exceeded Information on how to perform the configuration is given under Recognition of Running Condition only for motors in Subsection2 1 3 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 196: ... 0 50 20 00 A 5 00 A 4207A Kτ FACTOR 1 0 10 0 1 0 Kt FACTOR when motor stops 4208A T EMERGENCY 10 15000 sec 100 sec Emergency time 4209 49 TEMP RISE I 40 200 C 100 C 49 Temperature rise at rated sec curr 4210 49 TEMP RISE I 104 392 F 212 F 49 Temperature rise at rated sec curr No Information Type of In formation Comments 1503 BLOCK 49 O L SP BLOCK 49 Overload Protection 1507 EmergencyStart SP Emer...

Page 197: ...s immediately generated by a normally closed contact Brief auxiliary voltage interruptions of less than 50 ms do not disturb the readiness of the device for nominal auxiliary voltage 110 VDC The processor monitors the offset and reference voltage of the ADC analog digital converter The protection is suspended if the voltages deviate outside an allowable range and lengthy deviations are reported Bu...

Page 198: ...the permissible current proportional ratio errors of the input transformer which are par ticularly prevalent during large short circuit currents Figure 2 64 The dropout ratio is about 97 Figure 2 64 Current Sum Monitoring An error in the current sum results in the message Failure Σ I No 162 and blocking of the protection function Furthermore a fault log is initiated for a period of 100 ms The moni...

Page 199: ...gic Diagram of the fast current sum monitoring AD Transformer Monitoring The digitized sampled values are being monitored in respect of their plausibility If the result is not plausible message 181 Error A D conv is issued The protection is blocked thus preventing unwanted operation Furthermore a fault record is generated for recording of the internal fault w w w E l e c t r i c a l P a r t M a n ...

Page 200: ...rt an additional restart attempt is begun After three unsuccess ful restarts within a 30 second window of time the device automatically removes itself from service and the red Error LED lights up The readiness relay drops out and indicates device malfunction with its normally closed contact Offset Monitoring This monitoring function checks all ring buffer data channels for corrupt offset replicati...

Page 201: ...lue 8105 address 8104 is the lower limit of the operating range of this monitoring see Figure 2 66 Both param eters can be set The dropout ratio is about 97 This malfunction is reported as Fail I balance Figure 2 66 Current symmetry monitoring Voltage Symmetry During normal system operation i e the absence of a fault balance among the input voltages is expected Because the phase to phase voltages ...

Page 202: ... and negative sequence detection all assume a phase sequence of abc Phase rotation of measurement quantities is checked by verifying the phase sequences For that purpose the phase sequence monitoring uses the phase to phase voltages VAB VBC VCA Voltages VAB before VBC before VCA and Currents IA beforeIB beforeIC Verification of the voltage phase rotation is done when each measured voltage is at le...

Page 203: ...of the sensitive ground fault detection the directional overcurrent protection phase and ground function the voltage con trolled inverse time non directional overcurrent protection the undervoltage protection and the synchronization function are blocked if parameter 5310 BLOCK PROT is set to YES The FFM picks up if the ground voltage VN is higher than the set limit value under address 5302 FUSE FA...

Page 204: ...lease date 01 2008 204 The generation of an internal signal Alarm FFM isol N for the mode of operation in an isolated system is illustrated in Figure 2 69 Figure 2 68 Logic diagram of the Fuse Failure Monitor for grounded networks w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 205: ...SE FAIL MON The logic diagram on the mode of operation in an isolated system is illustrated in Figure 2 69 The following is a description of the principles for single two and three pole faults in a voltage transformer secondary system If this part of the FFM logic picks up the internal signal Alarm FFM isol N is initiated which further processing is indicated in Figure 2 68 Figure 2 69 Logic diagr...

Page 206: ...respond since no voltage transformer fault can be present In order to avoid occurrence of an overfunctioning of the measuring voltage failure detection due to inaccuracy the function is blocked below a minimum threshold of the positive sequence systems of voltage V1 0 1 VNom and current I1 0 1 INom Three pole Faults in Voltage Transformer Circuits A three pole failure in the voltage transformer se...

Page 207: ...n wire monitoring function monitors the voltage transformer circuits of the secondary system with regard to failure One distinguishes between single pole two pole and three pole failures Mode of Operation Logic All three phase to ground voltages the displacement voltage and the three phase currents are measured The required values are calculated for the respective criteria and eventually a decisio...

Page 208: ...TEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 208 The following logic diagram shows how broken wire monitoring functions Figure 2 70 Logic diagram for broken wire monitoring w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 209: ...may not be sensitive Note The connections of the ground paths and their adaption factors were set when configuring the general Power System Data These settings must be correct for the measured values monitoring to function properly Measured value monitoring can be set to ON or OFF at address 8101 MEASURE SUPERV Fuse Failure Monitor FFM Via the address 5301 FUSE FAIL MON you select under which syst...

Page 210: ... 16 0 V Minimum phase to phase voltage 5205 Vph ph max min 10 0 200 0 V 16 0 V Symmetry phase to phase voltages 5206 I min 1A 0 04 1 00 A 0 04 A Minimum line current 5A 0 20 5 00 A 0 20 A 5208 T DELAY ALARM 0 00 32 00 sec 1 25 sec Alarm delay time 5301 FUSE FAIL MON OFF Solid grounded Coil gnd isol OFF Fuse Fail Monitor 5302 FUSE FAIL 3Vo 10 100 V 30 V Zero Sequence Voltage 5303 FUSE FAIL RESID 1A...

Page 211: ...Voltage Balance 169 VT FuseFail 10s OUT VT Fuse Failure alarm 10s 170 VT FuseFail OUT VT Fuse Failure alarm instantaneous 171 Fail Ph Seq OUT Failure Phase Sequence 175 Fail Ph Seq I OUT Failure Phase Sequence Current 176 Fail Ph Seq V OUT Failure Phase Sequence Voltage 197 MeasSup OFF OUT Measurement Supervision is switched OFF 253 VT brk wire OUT Failure VT circuit broken wire 255 Fail VT circui...

Page 212: ...uit breaker con ditions When only one binary input is used malfunctions in the circuit breaker itself cannot be detected Prerequisites A requirement for the use of trip circuit supervision is that the control voltage for the circuit breaker is at least twice the voltage drop across the binary input Vct 2 VBImin Since at least 19 V are needed for the binary input the supervision can only be used wi...

Page 213: ... the trip circuit a loss of battery voltage occurs or malfunctions occur with the circuit breaker mechanism Therefore it is used as supervision criterion Table 2 13 Condition table for binary inputs depending on RTC and CB position The conditions of the two binary inputs are checked periodically A check takes place about every 600 ms If three consecutive conditional checks detect an abnormality af...

Page 214: ...aker auxiliary contact Only as long as the trip contact is closed the binary input is short circuited and thereby deactivated logical condition L If the binary input is continuously deactivated during operation this leads to the conclusion that there is an in terruption in the trip circuit or loss of control voltage As the trip circuit supervision does not operate during system faults the closed t...

Page 215: ...ica tion is generated in case of an actual fault in the trip circuit the indication regarding a trip circuit interruption is delayed The time delay is set under address 8202 Alarm Delay Supervision with One Binary Input Note When using only one binary input BI for the trip circuit monitor malfunctions such as interruption of the trip circuit or loss of battery voltage are detected in general but t...

Page 216: ...nternal auxiliary voltage is present and the green RUN LED goes out If the internal auxiliary voltage fails all LEDs are dark Table 2 14 provides a summary of the monitoring functions and the malfunction responses of the relay Addr Parameter Setting Options Default Setting Comments 8201 FCT 74TC ON OFF ON 74TC TRIP Circuit Supervision 8202 Alarm Delay 1 30 sec 2 sec Delay Time for alarm No Informa...

Page 217: ... Blocking by the protec tion function Error A D conv 181 LED ERROR DOK2 drops out Error in the I O board Internal hardware Device shutdown I O Board error 178 LED ERROR DOK2 drops out Module error Internal hardware Device shutdown Error Board 1 to Error Board 7 178 to 189 LED ERROR DOK2 drops out Internal auxiliary voltage 5 V Internal hardware Device shutdown Error 5V 144 LED ERROR DOK2 drops out...

Page 218: ... that message 160 Alarm Sum Event is only issued when the measured value monitoring functions 8101 MEASURE SUPERV are activated Fuse Failure Monitor External voltage transformer Message VT FuseFail 10s 169 VT FuseFail 170 As allocated Trip circuit monitoring External trip circuit or control voltage Message 74TC Trip cir 6865 As allocated Secondary voltage transform er circuit monitoring External v...

Page 219: ...faults This function can also be used as supplementary ground fault protection 2 12 1 Ground Fault Detection for cos ϕ sin ϕ Measurement Standard Method Voltage Element The voltage element relies on a pickup initiated by the displacement voltage V0 or 3 V0 Additionally the faulty phase is determined The displacement voltage V0 can be directly applied to the device or the summary voltage 3 V0 can b...

Page 220: ...d fault the machine supplies only a negligible ground fault current across the measurement location which must be situated between the machine terminals and the network whereas in case of a machine ground fault the higher ground fault current produced by the total network is available Ground current protection is mostly used as backup protection for high resistance ground faults in solid or low re...

Page 221: ... part 3I0real of current 3I0 is calculated with reference to the displacement voltage V0 and compared with setting value RELEASE DIRECT The example is therefore suitable for ground fault direction in grounded systems where quantity 3I0 cos ϕ is relevant The directional limit lines are perpendicular to axis 3I0real Figure 2 77 Directional characteristic for cos ϕ measurement The directional limit l...

Page 222: ...relevant for pickup current compo nents are calculated from the power components When determining the ground fault direction the active or reactive components of the ground current in reference to the displacement voltage as well as the direction of the active and reactive power are evaluated For measurements of sin ϕ for isolated systems the following applies Ground fault forward direction if Q0 ...

Page 223: ... elements can be blocked individually via binary inputs In this case pickup and if possible direction and grounded phase will still be reported however tripping does not take place since the time elements are blocked Figure 2 79 Activation of the sensitive ground fault detection for cos ϕ sin ϕ measurement Generation of a pickup message for both current elements is dependent on the direction selec...

Page 224: ... Protection 64 67N s 50N s 51N s SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 224 Figure 2 80 Logic diagram of the VN element for cos ϕ sin ϕ measurement w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 225: ...Protection 64 67N s 50N s 51N s SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 225 Figure 2 81 Logic diagram of the 51Ns elements for cos ϕ sin ϕ measurement w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 226: ...hen 3 V0 VA VB VC If the displacement voltage is directly applied to the device then V0 is the voltage at the device terminals It is not affected by parameter Vph Vdelta address 206 Pickup performed by the displacement voltage can be delayed 64 1 DELAY for tripping It is important to note that the total trip command time then consists of the displacement voltage measurement time about 50 ms plus t...

Page 227: ...OUT Tripping Area The U0 I0 ϕ characteristic is illustrated as a sector in the U0 I0 phasor diagram see Figure 2 83 This sector corresponds to the tripping area If the cursor of the ground current is in this sector the function picks up The tripping area is defined via several parameters Via the angle ϕ parameter 3154 50Ns 1 Phi or 3151 50Ns 2 Phi the center of the zone with reference to the displ...

Page 228: ... element or pickup of the 50Ns 1 or 51Ns element start the ground fault recording As the pickup of the element drops out fault recording is terminated see logic diagrams 2 85 and 2 86 The entire function can be blocked under the following conditions A binary input is set the Fuse Failure Monitor or the voltage transformer protection breaker pick up Switching off or blocking means that measurement ...

Page 229: ...nd Fault Protection 64 67N s 50N s 51N s SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 229 Figure 2 85 Logic diagram for U0 I0 ϕ measurement part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 230: ...nd Fault Protection 64 67N s 50N s 51N s SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 230 Figure 2 86 Logic diagram for U0 I0 ϕ measurement part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 231: ... Therefore on the faulty cables a clear forward decision is made whereas in other feeders either reverse direction is sent back or no measurement is carried out in case ground current is too low Definitely the faulty line can be determined clearly Figure 2 87 Location of ground faults in a radial network In meshed or looped systems the measuring points of the faulty line also receive the maximum g...

Page 232: ...ion characteristic The ground fault is detected and reported when the displacement voltage was sustained a certain time T DELAY Pickup Address 3130 PU CRITERIA specifies whether ground fault detection is enabled only for pickups of VN and INS Vgnd AND INs or as soon as one of the two has picked up Vgnd OR INs The pickup can be stabilized for ground fault protection with definite time curve by a se...

Page 233: ...verse time ground fault protection with logarithmic inverse charac teristic Logarithmic inverse t 51Ns MAX TIME DIAL 51Ns TIME DIAL ln I 51Ns PICKUP Note For I 51Ns PICKUP 35 the time applies for I 51Ns PICKUP 35 Logarithmic Inverse characteristic with Knee Point inverse time The logarithmic inverse curve with knee point is only used for the standard measurement method cos ϕ sin ϕ address 130 S Gn...

Page 234: ...rent values is They are therefore not enabled and no pickup or tripping of these protective functions will occur Up to 20 value pairs current and time may be entered at address 3131 M of PU TD The device then approximates the characteristic using linear interpolation The following must be observed The value pairs should be entered in increasing sequence If desired fewer than 20 pairs can be entere...

Page 235: ... expected operational phase to phase voltage For VNom 100 V approxi mately 75 V is a typical setting These settings have no significance in a grounded system Displacement Voltage Element V0 The displacement voltage 64 1 VGND address 3108 or 3109 or 64 1 VGND address 3110 is used to pick up ground fault detection At the same time pickup of the voltage element is a condition for initiation of direct...

Page 236: ...es With the following configuration the following applies when switching to primary values With regard to a ground fault in a ungrounded or resonant grounded system nearly the entire displacement voltage appears at the device terminals therefore the pickup setting is not critical and typically lies between 30 V and 60 V for 64 1 VGND with a standard V0 connection or 50 V and 100 V for 64 1 VGND La...

Page 237: ...ro voked by asymmetrical currents in the system and by current transformers especially in the Holmgreen con nection If direction determination is used in conjunction with one of the current elements discussed above 50Ns 1 PICKUP addresses 3117 ff or 51Ns PICKUP addresses 3119 ff it is sensible to select a value for address RELEASE DIRECT that is lower than or equal to the above pickup value A corr...

Page 238: ...rrent CT Err I1 as well as another operating point CT Err F2 CT Err I2 are set for the actually connected burden The device thus approximates the transformation characteristic of the transformer with considerable accuracy In ungrounded or grounded systems angle compensation is not required Ungrounded System In an ungrounded system with a ground fault on a cable capacitive ground currents of the ga...

Page 239: ...ces with sensitive ground fault input generally settings may be entered in primary values with consid eration given to the ratio of the applicable current transformer However problems related to the resolution of the pickup currents can occur when very small settings and small nominal primary currents are involved The user is therefore encouraged to enter settings for the sensitive ground fault de...

Page 240: ... 1 DELAY 0 00 320 00 sec 2 00 sec 50Ns 1 Time delay 3119 51Ns PICKUP 0 001 1 400 A 0 100 A 51Ns Pickup 3119 51Ns PICKUP 0 003 0 500 A 0 004 A 51Ns Pickup 3119 51Ns PICKUP 1A 0 05 4 00 A 1 00 A 51Ns Pickup 5A 0 25 20 00 A 5 00 A 3120 51NsTIME DIAL 0 10 4 00 sec 1 00 sec 51Ns Time Dial 3121A 50Ns T DROP OUT 0 00 60 00 sec 0 00 sec 50Ns Drop Out Time Delay 3122 67Ns 1 DIRECT Forward Reverse Non Direc...

Page 241: ...0 00 sec 5 80 sec 51Ns Maximum Time Delay 3141 51Ns T max 0 50 200 00 sec 93 00 sec 51Ns Maximum Time Delay at 51Ns PU 3142 51Ns TIME DIAL 0 05 15 00 sec 1 35 sec 51Ns Time Dial 3143 51Ns Startpoint 1 0 4 0 1 1 51Ns Start Point of Inverse Charac 3150 50Ns 2 Vmin 0 4 50 0 V 2 0 V 50Ns 2 minimum voltage 3150 50Ns 2 Vmin 1 8 50 0 V 2 0 V 50Ns 2 minimum voltage 3150 50Ns 2 Vmin 10 0 90 0 V 10 0 V 50Ns...

Page 242: ...Pickup OUT 51Ns picked up 1229 51Ns TRIP OUT 51Ns TRIP 1230 Sens Gnd block OUT Sensitive ground fault detection BLOCKED 1264 IEEa VI Corr Resistive Earth current 1265 IEEr VI Corr Reactive Earth current 1266 IEE VI Earth current absolute Value 1267 VGND 3Vo VI Displacement Voltage VGND 3Vo 1271 Sens Gnd Pickup OUT Sensitive Ground fault pick up 1272 Sens Gnd Ph A OUT Sensitive Ground fault picked ...

Page 243: ...r insulation or water ingress in cable joints 2 13 1 Description Acquisition of Measured Quantities The intermittent ground fault can either be detected via the ordinary ground current input IN the sensitive ground current input INS or it is calculated from the sum of the three phase currents 3 I0 Unlike the over current protection which uses the fundamental wave the intermittent ground fault prot...

Page 244: ...sage is allocated to an LED or a relay this limitation does not apply This is accomplished by doubling the message message numbers 6924 6926 Interaction with the Automatic Reclosure Function Automatic reclosure is not an effective measure against intermittent ground faults as the function only trips after repeated detection of a fault or after expiration of the summation monitoring time T sum det ...

Page 245: ...rameter Nos det When this happens the message Intermitt EF is issued and IIE Fault det is blocked for the fault log and the system interface This method accounts for the fact that the IiE element may also pick up for a normal short circuit In this case the pickup does not launch the alarm Intermitt EF Intermittent ground faults may cause other overcurrent elements to pick up e g 50 1 50N 1 50Ns 1 ...

Page 246: ...picked up FNo Message Explanation 1761 50 N 51 N PU 50 N 51 N picked up 1762 50 51 Ph A PU 50 51 Phase A picked up 1763 50 51 Ph B PU 50 51 Phase B picked up 1764 50 51 Ph C PU 50 51 Phase C picked up 1810 50 1 picked up 50 1 picked up 1820 51 picked up 51 picked up 1765 50N 51NPickedup 50N 51N picked up 1831 50N 2 picked up 50N 2 picked up 1834 50N 1 picked up 50N 1 picked up 1837 51N picked up 5...

Page 247: ...me T reset that keeps the fault event opened and not the pickup 2 13 2 Setting Notes General The protection function for intermittent ground faults can only take effect and is only accessible if the current to be evaluated 133 INTERM EF or with Ignd was configured in address with 3I0 with Ignd sens If not required this function is set to Disabled The function can be turned ON or OFF under address ...

Page 248: ...n C configuration indicates the corresponding sec ondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 3301 INTERM EF OFF ON OFF Intermittent earth fault pro tection 3302 Iie 1A 0 05 35 00 A 1 00 A Pick up value of interm E F stage 5A 0 25 175 00 A 5 00 A 3302 Iie 1A 0 05 35 00 A 1 00 A Pick up value of interm E F stage 5A 0 25 175 00 A 5 00 A...

Page 249: ...3 IEF enabled OUT Interm E F prot is active 6924 IIE Fault det OUT Interm E F detection stage Iie 6925 IIE stab Flt OUT Interm E F stab detection 6926 IIE Flt det FE OUT Interm E F det stage Iie f Flt ev Prot 6927 Intermitt EF OUT Interm E F detected 6928 IEF Tsum exp OUT Counter of det times elapsed 6929 IEF Tres run OUT Interm E F reset time running 6930 IEF Trip OUT Interm E F trip 6931 Iie In ...

Page 250: ...n some systems several reclosing attempts are performed Applications The automatic reclosure system integrated in the 7SJ62 64 can also be controlled by an external protection device e g backup protection For this application a signal exchange must occur between 7SJ62 64 and the external protection device via binary inputs and outputs It is also possible to allow the relay 7SJ62 64 to work in conj...

Page 251: ...d reclosure Figure 2 95 Timing diagram showing two reclosing shots first cycle unsuccessful second cycle successful The following figure shows an example of a timing diagram showing for two unsuccessful reclosing shots with no additional reclosing of the circuit breaker The number of reclose commands initiated by the automatic reclosure function are counted A statistical counter is available for t...

Page 252: ...e 2 18 Initiating automatic reclosure On initiation the automatic reclosure function is informed that a trip command was issued and the respective reclosing program is now being executed The binary input messages 2715 Start 79 Gnd and 2716 Start 79 Ph for starting an automatic reclosure program can also be activated via CFC fast PLC task processing Automatic reclosure can thus be initiated via any...

Page 253: ...type of fault two different reclosing programs can be used Here the following applies The single phase fault ground fault reclosing program applies if all fault protection functions that initiate automatic reclosure detected a phase to ground fault The following conditions must apply only one phase only one phase and ground or only ground have picked up This program can also be started via a binar...

Page 254: ... The number can be set differently for the phase fault reclosing program and the ground fault reclosing program The first reclose cycle is in principle the same as the single shot auto reclosing If the first reclosing attempt is unsuccessful this does not result in a final trip but in a reset of the restraint time interval and start of the next reclose cycle with the next dead time This can be rep...

Page 255: ...ndition that has been fulfilled After the blocking time has elapsed the device checks whether or not the blocking condition can be reset If the blocking condition is still present or if a new blocking condition is fulfilled the blocking time is restarted If however the blocking condi tion no longer holds after the blocking time has elapsed the dynamic blocking will be reset Dynamic blocking is ini...

Page 256: ...to static blocking If the binary input is no longer active when the time has elapsed and if no new blocking con ditions apply the automatic reclosure system resumes normal state 2 14 3 Status Recognition and Monitoring of the Circuit Breaker Circuit Breaker Status The detection of the actual circuit breaker status is necessary for the correct functionality of the auto reclose function The breaker ...

Page 257: ...t A reclosing attempt will be blocked until the binary input indicates that the circuit breaker is ready to complete another CLOSE TRIP cycle The time needed by the circuit breaker to regain the ready state can be monitored by the 7SJ62 64 The monitoring time CB TIME OUT expires for as long as the circuit breaker does not indicate that it is ready via binary input CB Ready FNo 2730 Meaning that as...

Page 258: ...delays 3 The time overcurrent protection parameter 1X14A 50 N 2 ACTIVE or 1X16A 50 N 3 ACTIVE defines whether the elements 50 N 2 or 50 N 3 are to operate always or only with 79M Auto Reclosing ready see Section 2 2 Cyclic Control Control of the time overcurrent protection elements takes effect by releasing the cycle marked by the corre sponding parameter The cycle zone release is indicated by the...

Page 259: ...sing After the second reclosing however elements 50 2 or 50N 2 are to be blocked so the fault can be eliminated by applying elements 50 1 or 50N 1 according to the grading coordination chart of the system giving priority to selectivity concerns Addresses 7202 bef 1 Cy 50 2 7214 bef 2 Cy 50 2 7203 bef 1 Cy 50N 2 and 7215 bef 2 Cy 50N 2 are set to instant T 0 to enable the elements after the first r...

Page 260: ... breaker will clear the fault before the fuse at feeder 5 is damaged If the fault is cleared all functions are reset after the restraint time has expired and the fault is terminated The fuse has therefore also been protected If the fault continues to exist a second reclosing cycle is performed in the same way High speed element 50 2 is now being blocked at relay protecting Feeder 3 If the fault st...

Page 261: ...sure system will not respond to a manual close signal Restraint Time and Dynamic Blocking The blocking time TIME RESTRAINT address 7105 defines the time that must elapse after a successful re closing attempt before the automatic reclosing function is reset If a protective function configured for initiation of the auto reclosure function provokes a new trip before this time elapses the next reclosi...

Page 262: ... in undefined state when the synchronism check fails to check back If the synchronization is used as synchronism check for synchronous systems the monitoring time may be configured quite short e g to some seconds In this case the synchronizing function merely checks the syn chronism of the power systems If synchronism prevails it switches in instantaneously otherwise it will not If the synchroniza...

Page 263: ...eclose command The example in the section 2 2 11 of a MANUAL CLOSE for commands via the integrated control function has to be extended in this case see Figure 2 99 The mes sages 2878 79 L N Sequence and 2879 79 L L Sequence indicate that the AR has been started and wants to carry out a reclosure after the dead time The annunciations set the flipflop and suspend the manual signal until the AR has f...

Page 264: ...time Initiation and Blocking of Automatic Reclosure by Protective Elements configuration At addresses 7150 to 7167 reclosing can be initiated or blocked for various types of protection functions They constitute the interconnection between protection elements and auto reclose function Each address desig nates a protection function together with its ANSI synonym e g 50 2 for the high set element of ...

Page 265: ...e as for the first cycle For the 2nd cycle For the 3rd cycle For the 4th cycle Fifth to Ninth Reclosing Attempt If more than four cycles are configured the dead times set for the fourth cycle also apply to the fifth through to ninth cycle Blocking Three Phase Faults Regardless of which reclosing program is executed automatic reclosing can be blocked for trips following three phase faults address 7...

Page 266: ...closure the 50 2 elements also applicable to the 50 3 elements must be blocked i e address 7214 bef 2 Cy 50 2 must be set to blocked T The zone sequencing of the feeder relays is switched off but the 50 2 elements must also be blocked after the second reclosing attempt Moreover it must be ensured that the 50 2 elements start the automatic reclosing function Set address 7152 50 2 to Starts 79 Contr...

Page 267: ...ension 7117 T ACTION 0 01 320 00 sec sec Action time 7118 T DEAD DELAY 0 0 1800 0 sec 1 0 sec Maximum Time Delay of Dead Time Start 7127 DEADTIME 1 PH 0 01 320 00 sec 0 50 sec Dead Time 1 Phase Fault 7128 DEADTIME 1 G 0 01 320 00 sec 0 50 sec Dead Time 1 Ground Fault 7129 DEADTIME 2 PH 0 01 320 00 sec 0 50 sec Dead Time 2 Phase Fault 7130 DEADTIME 2 G 0 01 320 00 sec 0 50 sec Dead Time 2 Ground Fa...

Page 268: ...o influence Starts 79 Stops 79 No influence 67N 1 7158 67 2 No influence Starts 79 Stops 79 No influence 67 2 7159 67N 2 No influence Starts 79 Stops 79 No influence 67N 2 7160 67 TOC No influence Starts 79 Stops 79 No influence 67 TOC 7161 67N TOC No influence Starts 79 Stops 79 No influence 67N TOC 7162 sens Ground Flt No influence Starts 79 Stops 79 No influence Sensitive Ground Fault 7163 46 N...

Page 269: ...f 1 Cy 67 1 Set value T T instant T 0 blocked T Set value T T before 1 Cycle 67 1 7207 bef 1 Cy 67N 1 Set value T T instant T 0 blocked T Set value T T before 1 Cycle 67N 1 7208 bef 1 Cy 67 2 Set value T T instant T 0 blocked T Set value T T before 1 Cycle 67 2 7209 bef 1 Cy 67N 2 Set value T T instant T 0 blocked T Set value T T before 1 Cycle 67N 2 7210 bef 1 Cy 67 TOC Set value T T instant T 0 ...

Page 270: ...ycle 67N 2 7222 bef 2 Cy 67 TOC Set value T T instant T 0 blocked T Set value T T before 2 Cycle 67 TOC 7223 bef 2 Cy 67NTOC Set value T T instant T 0 blocked T Set value T T before 2 Cycle 67N TOC 7224 bef 3 Cy 50 1 Set value T T instant T 0 blocked T Set value T T before 3 Cycle 50 1 7225 bef 3 Cy 50N 1 Set value T T instant T 0 blocked T Set value T T before 3 Cycle 50N 1 7226 bef 3 Cy 50 2 Set...

Page 271: ...efore 4 Cycle 50N 1 7238 bef 4 Cy 50 2 Set value T T instant T 0 blocked T Set value T T before 4 Cycle 50 2 7239 bef 4 Cy 50N 2 Set value T T instant T 0 blocked T Set value T T before 4 Cycle 50N 2 7240 bef 4 Cy 51 Set value T T instant T 0 blocked T Set value T T before 4 Cycle 51 7241 bef 4 Cy 51N Set value T T instant T 0 blocked T Set value T T before 4 Cycle 51N 7242 bef 4 Cy 67 1 Set value...

Page 272: ... Set value T T instant T 0 blocked T Set value T T before 4 Cycle 50 3 7255 bef 4 Cy 50N 3 Set value T T instant T 0 blocked T Set value T T before 4 Cycle 50N 3 No Information Type of In formation Comments 127 79 ON OFF IntSP 79 ON OFF via system port 2701 79 ON SP 79 ON 2702 79 OFF SP 79 OFF 2703 BLOCK 79 SP BLOCK 79 2711 79 Start SP 79 External start of internal A R 2715 Start 79 Gnd SP Start 7...

Page 273: ...yc run OUT 79 1st cycle running 2845 79 2ndCyc run OUT 79 2nd cycle running 2846 79 3rdCyc run OUT 79 3rd cycle running 2847 79 4thCyc run OUT 79 4th or higher cycle running 2851 79 Close OUT 79 Close command 2862 79 Successful OUT 79 cycle successful 2863 79 Lockout OUT 79 Lockout 2865 79 Sync Request OUT 79 Synchro check request 2878 79 L N Sequence OUT 79 A R single phase reclosing sequence 287...

Page 274: ...etection In the latter case fault location calculations is even possible if another pro tection relay cleared the fault Additionally the fault location can be initiated via a binary input However it is a prerequisite that pickup of the time overcurrent protection is performed at the same time directional or non directional Fault Location Determination The measurement principle of the fault locator...

Page 275: ...ength calculated on the basis of the set reactance per unit length and the set line length Line Sections The line type is determined by the line section settings If for instance the line includes a cable and an over head line two different sections must be configured The system can distinguish between up to three different line types When configuring this line data please note that the different t...

Page 276: ...or Ω mile Furthermore the line length in km or miles the angle of the line impedance and resis tance and reactance ratios are required These parameters have already been set in the Power System Data 2 for a maximum of 3 line sections see Section 2 1 6 2 under Ground Impedance Ratios and Reactance per Unit Length Initiation of Measurement Normally the fault location calculation is started when a di...

Page 277: ...t Locator primary REACTANCE 1117 Rsec VI Flt Locator secondary RESISTANCE 1118 Xsec VI Flt Locator secondary REACTANCE 1119 dist VI Flt Locator Distance to fault 1120 d VI Flt Locator Distance to fault 1122 dist VI Flt Locator Distance to fault 1123 FL Loop AG OUT Fault Locator Loop AG 1124 FL Loop BG OUT Fault Locator Loop BG 1125 FL Loop CG OUT Fault Locator Loop CG 1126 FL Loop AB OUT Fault Loc...

Page 278: ...reaker failure protection Initiation The breaker failure protection function can be initiated by two different sources Trip signals of internal protective functions of the 7SJ62 64 external trip signals via binary inputs 50BF ext SRC For each of the two sources a unique pickup message is generated a unique time delay is initiated and a unique trip signal is generated The setting values of current ...

Page 279: ...ss 170 50BF can be set in such a way that either the current criterion can already be met by a single phase current setting Enabled or that another current is taken into consideration in order to check the plau sibility setting enabled w 3I0 see Figure 2 102 The currents are filtered through numerical filters to evaluate the fundamental harmonic They are monitored and compared to the set limit val...

Page 280: ...llustrates the monitoring of the circuit breaker s auxiliary contacts Figure 2 103 Logic diagram for breaker failure protection monitoring of the circuit breaker auxiliary contacts Logic If breaker failure protection is initiated an alarm message is generated and a settable delay time is started If once the time delay has elapsed criteria for a pickup are still met a trip signal is issued to a sup...

Page 281: ...Breaker Failure Protection 50BF SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 281 Figure 2 104 Logic diagram of the breaker failure protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 282: ...on for detection of an open circuit breaker e g voltage protection Time Delay The time delay is entered at address 7005 TRIP Timer This setting should be based on the maximum circuit breaker operating time plus the dropout time of the current flow monitoring element plus a safety margin which takes into consideration the tolerance of the time delay Figure 2 105 illustrates the time sequences Figur...

Page 283: ... sec 0 25 sec TRIP Timer 7006 50BF PICKUP 1A 0 05 20 00 A 0 10 A 50BF Pickup current threshold 5A 0 25 100 00 A 0 50 A 7007 50BF PICKUP IE 1A 0 05 20 00 A 0 10 A 50BF Pickup earth current threshold 5A 0 25 100 00 A 0 50 A No Information Type of In formation Comments 1403 BLOCK 50BF SP BLOCK 50BF 1431 50BF ext SRC SP 50BF initiated externally 1451 50BF OFF OUT 50BF is switched OFF 1452 50BF BLOCK O...

Page 284: ... flexible functions The logic diagram 2 106 illustrates the description Characteristic Group Characteristic Measured Quantity Protective Function ANSI No Operating Mode 3 phase 1 phase Current I RMS value of fundamental component Time overcurrent protection 50 50G X X Irms True RMS r m s value Time overcurrent protection Overload protection 50 50G X X 3I0 Zero sequence system Time overcurrent prot...

Page 285: ... be blocked if currents fall below 0 03 INom Operating Mode Measured Quantity Measurement Method The flexible function can be tailored to assume a specific protective function for a concrete application in pa rameters OPERRAT MODE MEAS QUANTITY MEAS METHOD and PICKUP WITH Parameter OPERRAT MODE can be set to specify whether the function works 3 phase 1 phase or no reference i e without a fixed pha...

Page 286: ...Logic Figure 2 106 shows the logic diagram of a three phase function If the function operates on one phase or without phase reference phase selectivity and phase specific indications are not relevant Figure 2 106 Logic diagram of the flexible protection functions w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 287: ... no 235 2111 00 instant The trip will be launched immediately when the pickup is present and the binary input has been activated The trip command can be blocked via binary inputs no 235 2115 00 BL TripA and no 235 2114 00 BLK TRIP The phase selective blocking of the trip command is required for interaction with the inrush restraint see Interaction with other functions The function s dropout ratio ...

Page 288: ...sible In order to block a flexible function by the inrush restraint the blocking must be carried out in CFC The flexible function provides three binary inputs for block ing trip commands selectively for each phase no 235 2115 to 235 2117 They have to be linked with the phase selective indications for detecting the inrush no 1840 to 1842 Activating a crossblock function re quires the phase selectiv...

Page 289: ... only the individual measuring value This can be an individual phase value e g VB or a ground variable VN or IN Setting no reference determines the evaluation of measured variables irrespective of a single or three phase connection of current and voltage Table 2 20 provides an overview regarding which variables can be used in which mode of operation Measured Variable In the setting dialog Measured...

Page 290: ...ystem can be configured as measurement procedure Examples are I2 tripping monitoring system U2 voltage asymmetry Via the selection zero sequence system additional zero se quence current or zero sequence voltage functions can be re alized that operate independent of the ground variables IE and UE which are measured directly via transformers Important The voltage threshold value is always parameteri...

Page 291: ...surement procedure of the protection functions True RMS The True RMS value is determined i e higher harmonics are evaluated This procedure is applied for example if an over load protection element must be realized on the basis of a current measurement as the higher harmonics contribute to thermal heating Current Parameter CURRENT Setting Options IA IB IC IN INS IN2 It is determined which current m...

Page 292: ...d via parameter T DROPOUT DELAY This setting is also set to zero by default standard setting A setting deviating from zero may be required if the device is utilized together with electro magnetic devices with considerably longer dropout ratios than the digital protection device see Chapter 2 2 for more information When utilizing the dropout time delay it is recommended to set it to a shorter time ...

Page 293: ...nt of the current transformer Addr Parameter C Setting Options Default Setting Comments 0 FLEXIBLE FUNC OFF ON Alarm Only OFF Flexible Function 0 OPERRAT MODE 3 phase 1 phase no reference 3 phase Mode of Operation 0 MEAS QUANTITY Please select Current Voltage P forward P reverse Q forward Q reverse Power factor Frequency df dt rising df dt falling Binary Input Please select Selection of Measured Q...

Page 294: ...shold 0 P U THRESHOLD 50 00 70 00 Hz 61 00 Hz Pickup Threshold 0 P U THRESHOLD 0 10 20 00 Hz s 5 00 Hz s Pickup Threshold 0 P U THRESHOLD 1A 0 5 10000 0 W 200 0 W Pickup Threshold 5A 2 5 50000 0 W 1000 0 W 0 P U THRESHOLD 0 99 0 99 0 50 Pickup Threshold 0 P U THRESHOLD 15 100 20 Pickup Threshold 0 T TRIP DELAY 0 00 3600 00 sec 1 00 sec Trip Time Delay 0A T PICKUP DELAY 0 00 60 00 sec 0 00 sec Pick...

Page 295: ...L TripB SP Function 00 BLOCK TRIP Phase B 235 2117 00 BL TripC SP Function 00 BLOCK TRIP Phase C 235 2118 00 BLOCKED OUT Function 00 is BLOCKED 235 2119 00 OFF OUT Function 00 is switched OFF 235 2120 00 ACTIVE OUT Function 00 is ACTIVE 235 2121 00 picked up OUT Function 00 picked up 235 2122 00 pickup A OUT Function 00 Pickup Phase A 235 2123 00 pickup B OUT Function 00 Pickup Phase B 235 2124 00...

Page 296: ...urrent from the energy supplier The generator runs in syn chronism without feeding power If the power supply company can no longer guarantee the required supply the control system is separated from the system of the power supply company and the generator is taking over the internal supply In this example the control system is disconnected from the system of the power supply company as soon as the ...

Page 297: ...ower supply company The circuit breaker CB1 is part of the power system of the power supply company Disconnection from the control system of the power supply company s power system is effected by the load isolator The trans former with a transformation ratio of 10 1 transforms the voltage level to 11 kV The transformer the generator and the two feeders are linked via a busbar at the low voltage si...

Page 298: ...me overcurrent protection elements Circuit breakers CB4 and CB5 are activated in the event of a fault In addition the busbar could be equipped with the 7UT635 differential protective relay for multiple ends The current transformers required to this end are already included in Figure 2 107 Synchronization Before Connecting the Generator In most cases it is the power customer who is responsible for ...

Page 299: ...ion with Flexible Protection Function SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 299 Figure 2 108 Wiring diagram for a 7SJ642 as reverse power protection flush mounted case w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 300: ...rection extending from the busbar to the trans former of the device Functional Logic The following logic diagram depicts the functional logic of the reverse power protection Figure 2 109 Logic diagram of the reverse power determination with flexible protection function The reverse power protection picks up once the configured pickup threshold has been exceeded If the pickup condition persists duri...

Page 301: ...out threshold of Psec dropout 15 6 W If the pickup threshold is reduced to a value near the lower setting limit of 0 5 W the dropout ratio should equally be reduced to approximately 0 7 Delay for Pickup Dropout and Trip The reverse power protection does not require short tripping times as protection from undesired power feed back In the present example it is useful to delay pickup and dropout by a...

Page 302: ...4x e g 7SJ642 device in DIGSI Manager Configure a flexible protection function flexible function 01 for the present example in the Device Configuration figure 2 110 Figure 2 110 Configuration of a flexible protection function Select Additional functions in the Parameters menu to view the flexible function figure 2 111 Figure 2 111 The flexible function appears in the function selection w w w E l e...

Page 303: ...g mode In menu items Measured Value and Measurement Procedures Active Power reverse or Exceeding must be set If in menu item Settings the box Additional Parameters display is enabled threshold value pickup delay time and trip delay time can be configured Figure 2 113 As the power direction cannot be determined in case of measured voltage failure protection blocking would be sensible in this case F...

Page 304: ...ix initially shows the following indications after selecting Indications and com mands only and No filter Figure 2 114 Figure 2 114 Indications prior to editing Clicking the texts allows for editing short text and long text as required by the application Figure 2 115 Figure 2 115 Indications after editing The indications are allocated in the same way as the indications of other protective function...

Page 305: ...switching does not en danger the stability of the power system Applications Typical applications are for example the synchronism check of a feeder and a busbar see Figure 2 116 or the synchronism check of two busbars via bus coupler see Figure 2 117 Prerequisites In 7SJ62 only one SYNC function group exists Furthermore only the operation mode SYNCHROCHECK is avail able for 7SJ62 2 19 1 1 General F...

Page 306: ...nded for special applications see de energized switching Connection Multiple phase For comparing the two voltages the synchronization function uses the reference voltage V1 and an additional voltage to be connected V2 The reference voltage V1 is derived from the multi phase system usually the three phase to ground voltages The voltage to be synchronized V2 is assigned to the single phase connectio...

Page 307: ...licitly messages 25 Vdiff ok 25 fdiff ok 25 αdiff ok Also conditions not fulfilled are indicated for example when voltage differences messages 25 V2 V1 25 V2 V1 frequency differences messages 25 f2 f1 25 f2 f1 or angle differences messages 25 α2 α1 25 α2 α1 lie outside the threshold values For these messages to be sent both voltages must lie within the operating range of the synchrocheck see margi...

Page 308: ... BUS VT In this case the synchronization can be controlled directly via a binary input Operating Range The operating range of the synchronization function is defined by the configured voltage thresholds Vmin and Vmax and the fixed frequency band fNom 3 Hz If measurement is started and one or both voltages are outside the operating range or one voltage leaves the permissible range corresponding mes...

Page 309: ...Sync f syn 170 2332 If the systems are asynchronous the time window for switching is passed relatively quickly Therefore it is sensible to take the operating time of the circuit breaker into account Thus the device can issue the ON command at a time where asynchronous conditions are still prevailing As soon as the poles make contact the conditions will be synchronous It is also possible to general...

Page 310: ... three voltages must have a higher value than threshold V so that side V1 is recognized as energized With single phase connection of course only one voltage has to exceed the threshold value Besides release under synchronous conditions the following additional release conditions can be selected for the check SYNC V1 V2 Release on the condition that component V1 is energized and component V2 is de ...

Page 311: ...itoring time which requires above stated release conditions for de energized connection to be fulfilled at least this time before switching is al lowed 2 19 1 5 Direct Command Blocking Parameter Direct CO can be set to grant a release without performing any checks In this case switching is released immediately when initiating the synchrocheck It is obviously not reasonable to combine Direct CO wit...

Page 312: ...up to operate with via one of the binary inputs from 25 1 act to 25 4 act If the assignment to the SYNC groups is clear the binary inputs are not required Selecting one SYNC function group several times causes output of error message 25 FG Error 2 19 1 7 Interaction with Control AR and External Control With Control Basically the synchrocheck interacts with the device control The switchgear compone...

Page 313: ...uit breaker Q0 is configured as component to be switched synchronized a CLOSE command of the AR function will address this breaker and assign it a CLOSE command which will be processed by the control As this breaker requires synchronization the control launches the synchronizing function and awaits release If the configured conditions are fulfilled the release is granted and the control issues the...

Page 314: ...function refers to the nominal frequency of the power system fNom 3 Hz The synchronization function can only operate if at least one of the addresses 161 25 Function 1 to 164 25 Function 4 is set to Enabled during configuration of the functional scope see Section 2 1 1 2 The operating mode can be preselected ASYN SYNCHRON means that switching will take place under synchronous and asynchronous cond...

Page 315: ...or de energized connection before switching is allowed The preset value of 0 1 s accounts for transient responses and can be applied without modification Release via synchronism check can be limited to a configurable synchronous monitoring time T SYN DURATION address 6x12 The configured conditions must be fulfilled within this time period Otherwise release is not granted and the synchronization fu...

Page 316: ...ail able see Figure 2 122 and also example in Figure 2 121 According to definition the three phase voltage is the reference voltage V1 To compare the three phase voltage V1 with voltage V2 correctly the connection type of voltage V2must be signaled to the device Address CONNECTIONof V2 assumes this task parameter 6x23 If three phase to ground voltages are connected to side V1 any phase to phase or...

Page 317: ... the system parts to be synchronized Asynchronous Conditions The synchronizing function 7SJ64 can issue a close command also for asynchronous power systems such that considering the circuit breaker operating time address 6x20 the power systems are coupled when the phases are equal Parameters 6x30dV ASYN V2 V1 and 6x31dV ASYN V2 V1 can be set to adjust the permissible voltage differences asymmetric...

Page 318: ...nd the conditions for synchronous switching apply If it is above the threshold the switching is asynchronous with consideration of the time left until the voltages are in phase Address 6x42dV SYNC V2 V1 and 6x43dV SYNC V2 V1 can be used to set the permissible voltage differ ences asymmetrically Parameters 6x44 dα SYNC α2 α1 and 6x45 dα SYNC α2 α1 confine the operating range for synchronous switchi...

Page 319: ...elease range to be set Parameters 6x52 df SYNCHK f2 f1 and 6x53df SYNCHK f2 f1 determine the permissible frequency dif ferences The availability of two parameters enables an asymmetrical release to be set Parameters 6x54 dα SYNCHK α2 α1 and 6x55 dα SYNCHK α2 α1 confine the operating range for synchro nous switching The availability of two parameters enables an asymmetrical release to be set Settin...

Page 320: ...t CO YES NO NO Direct ON Command 6111A TSUP VOLTAGE 0 00 60 00 sec 0 10 sec Supervision time of V1 V2 or V1 V2 6112 T SYN DURATION 0 01 1200 00 sec 30 00 sec Maximum duration of Synchroni zation 6113A 25 Synchron YES NO YES Switching at synchronous condi tion 6120 T CB close 0 01 0 60 sec 0 06 sec Closing operating time of CB 6121 Balancing V1 V2 0 50 2 00 1 00 Balancing factor V1 V2 6122A ANGLE A...

Page 321: ...gle difference alpha2 alpha1 6155 dα SYNCHK α2 α1 2 80 10 Maximum angle difference alpha2 alpha1 No Information Type of In formation Comments 170 0001 25 1 act SP 25 group 1 activate 170 0043 25 Sync req SP 25 Syncronization request 170 0049 25 CloseRelease OUT 25 Sync Release of CLOSE Command 170 0050 25 Sync Error OUT 25 Synchronization Error 170 0051 25 1 BLOCK OUT 25 group 1 is BLOCKED 170 200...

Page 322: ...missible 170 2039 25 V2 OUT 25 Voltage V2 Vmax permissible 170 2040 25 V2 OUT 25 Voltage V2 Vmin permissible 170 2050 V1 MV V1 170 2051 f1 MV f1 170 2052 V2 MV V2 170 2053 f2 MV f2 170 2054 dV MV dV 170 2055 df MV df 170 2056 dα MV dalpha 170 2090 25 V2 V1 OUT 25 Vdiff too large V2 V1 170 2091 25 V2 V1 OUT 25 Vdiff too large V2 V1 170 2092 25 f2 f1 OUT 25 fdiff too large f2 f1 170 2093 25 f2 f1 OU...

Page 323: ...ues are made available at a serial port Communication with the Protection Device The protection device can employ up to two RTD boxes via its service port port C 7SJ64 also via the addi tional port port D Therefore up to 12 temperature measuring points are available in this way For greater distances to the pro tection device the communication via fiber optic cables is recommended Alternative commu...

Page 324: ...of a plug in jumper see Section 3 1 2 in Chapter Mounting and Commissioning CTS enabled by RTS Device Settings The settings are the same for each input and are here shown at the example of measuring input 1 Set the type of temperature detector for RTD 1 temperature sensor for measuring point 1 at address 9011 RTD 1 TYPE You can choose between Ni 120 Ω and Ni 100 Ω If no temperature detector is ava...

Page 325: ...er settings are required to this end A baudrate of 9600 bits s ensures communication Parity is even The factory setting of the bus number 0 Mod ifications at the RTD box can be made in mode 7 The following convention applies Table 2 26 Setting the bus address at the RTD box Further information is provided in the operating manual of the RTD box Processing Measured Values and Messages The RTD box is...

Page 326: ...0 C RTD 1 Temperature Stage 2 Pickup 9016 RTD 1 STAGE 2 58 482 F 248 F RTD 1 Temperature Stage 2 Pickup 9021A RTD 2 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 2 Type 9022A RTD 2 LOCATION Oil Ambient Winding Bearing Other Other RTD 2 Location 9023 RTD 2 STAGE 1 50 250 C 100 C RTD 2 Temperature Stage 1 Pickup 9024 RTD 2 STAGE 1 58 482 F 212 F RTD 2 Temperature Stage 1 Pickup 902...

Page 327: ...TD 4 STAGE 2 50 250 C 120 C RTD 4 Temperature Stage 2 Pickup 9046 RTD 4 STAGE 2 58 482 F 248 F RTD 4 Temperature Stage 2 Pickup 9051A RTD 5 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 5 Type 9052A RTD 5 LOCATION Oil Ambient Winding Bearing Other Other RTD 5 Location 9053 RTD 5 STAGE 1 50 250 C 100 C RTD 5 Temperature Stage 1 Pickup 9054 RTD 5 STAGE 1 58 482 F 212 F RTD 5 Temper...

Page 328: ...74 RTD 7 STAGE 1 58 482 F 212 F RTD 7 Temperature Stage 1 Pickup 9075 RTD 7 STAGE 2 50 250 C 120 C RTD 7 Temperature Stage 2 Pickup 9076 RTD 7 STAGE 2 58 482 F 248 F RTD 7 Temperature Stage 2 Pickup 9081A RTD 8 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 8 Type 9082A RTD 8 LOCATION Oil Ambient Winding Bearing Other Other RTD 8 Location 9083 RTD 8 STAGE 1 50 250 C 100 C RTD 8 Te...

Page 329: ...0 Location 9103 RTD10 STAGE 1 50 250 C 100 C RTD10 Temperature Stage 1 Pickup 9104 RTD10 STAGE 1 58 482 F 212 F RTD10 Temperature Stage 1 Pickup 9105 RTD10 STAGE 2 50 250 C 120 C RTD10 Temperature Stage 2 Pickup 9106 RTD10 STAGE 2 58 482 F 248 F RTD10 Temperature Stage 2 Pickup 9111A RTD11 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD11 Type 9112A RTD11 LOCATION Oil Ambient Windi...

Page 330: ... Fail RTD 2 broken wire shorted 14122 RTD 2 St 1 p up OUT RTD 2 Temperature stage 1 picked up 14123 RTD 2 St 2 p up OUT RTD 2 Temperature stage 2 picked up 14131 Fail RTD 3 OUT Fail RTD 3 broken wire shorted 14132 RTD 3 St 1 p up OUT RTD 3 Temperature stage 1 picked up 14133 RTD 3 St 2 p up OUT RTD 3 Temperature stage 2 picked up 14141 Fail RTD 4 OUT Fail RTD 4 broken wire shorted 14142 RTD 4 St 1...

Page 331: ...ature stage 2 picked up 14201 Fail RTD10 OUT Fail RTD10 broken wire shorted 14202 RTD10 St 1 p up OUT RTD10 Temperature stage 1 picked up 14203 RTD10 St 2 p up OUT RTD10 Temperature stage 2 picked up 14211 Fail RTD11 OUT Fail RTD11 broken wire shorted 14212 RTD11 St 1 p up OUT RTD11 Temperature stage 1 picked up 14213 RTD11 St 2 p up OUT RTD11 Temperature stage 2 picked up 14221 Fail RTD12 OUT Fai...

Page 332: ...ly changed then a changeover signal at the routed binary input for this purpose is sufficient to inform the protective relay of the phase rotation reversal Logic Phase rotation is permanently established at address 209 PHASE SEQ Power System Data Via the exclu sive OR gate the binary input Reverse Rot inverts the sense of the phase rotation applied with setting Figure 2 127 Message logic of the ph...

Page 333: ...Setting Notes Setting the Function Parameter The normal phase sequence is set at 209 see Section 2 1 3 If on the system side phase rotation is reversed temporarily then this is communicated to the protective device using the binary input Reverse Rot 5145 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 334: ...UP The general pickup is a prerequisite for a number of internal and external consequential functions The follow ing are among the internal functions controlled by general device pickup Start of a trip log From general device pickup to general device dropout all fault messages are entered in the trip log Initialization of Oscillographic Records The storage and maintenance of oscillographic values ...

Page 335: ...last protection func tion has dropped out no function is in pickup mode AND the minimum trip signal duration has expired Finally it is possible to latch the trip signal until it is manually reset lockout function This allows the circuit breaker to be locked against reclosing until the cause of the fault has been clarified and the lockout has been manually reset The reset takes place either by pres...

Page 336: ...g specific messages can be freely configured The relay is delivered with a default setting The Appendix of this manual deals in detail with the delivery status and the allocation options The output relays and the LEDs may be operated in a latched or unlatched mode each may be individually set The latched conditions are protected against loss of the auxiliary voltage They are reset On site by press...

Page 337: ...y the device maybe reclose commands as well as values of interrupted currents and accumulated fault currents A complete list of all message and output functions that can be generated by the device with the maximum functional scope can be found in the appendix All functions are associated with an information number FNo There is also an indication of where each message can be sent to If functions ar...

Page 338: ...ldest data are erased for newest data when the buffer is full Ground Fault Messages In devices with sensitive ground fault detection separate ground fault logs are provided for ground fault record ing These logs are completed if the ground fault detection is not set to tripping but to Alarm Only address 3101 Alarm Only or the setting ON with GF log has been selected With this setting apart from th...

Page 339: ...s of 7SJ62 64 the 7SJ62 64 relay has to be informed of the position of the circuit breaker auxiliary contacts via binary inputs Hereby it is necessary that the internal pulse counter is al located in the matrix to a binary input that is controlled by the circuit breaker OPEN position The pulse count value Number of TRIPs CB can be found in the Statistics group if the option Measured and Metered Va...

Page 340: ...he four following autonomous subfunctions Summation tripping current ΣI procedure Summation of tripping powers ΣIx procedure Two point procedure for calculating the remaining lifetime 2P procedure Sum of all Squared Fault Current Integral I2 t procedure Measured value acquisition and preparation operates phase selectively for all four subfunctions The three results are each evaluated using a thres...

Page 341: ... separate the contacts As soon as the start criterion has been fulfilled the parameterized opening time of the circuit breaker is started The time of commencement of separation of the circuit breaker contacts is thus determined The end of the trip procedure including arc deletion is determined via another given parameter CB tripping time supplied by the manufacturer of the circuit breaker In order...

Page 342: ...ctions 2 23 Auxiliary Functions SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 342 Figure 2 131 Logic of the start and end criterion w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 343: ...the values does not satisfy the criterion its predecessor will be used instead for calculation If no r m s value satisfies the criterion up to the predecessor of the starting point which is marked by the start criterion a trip has taken place which only affects the mechanical lifetime of the breaker and is consequently not detected by this procedure If the current criterion grants the logic releas...

Page 344: ...s determined by the number of permitted operating cycles at rated operating current Ir point P2 by the maximum number of operating cycles at rated fault tripping current Isc The associated four values can be configured Figure 2 132 Diagram of operating cycles for the 2P procedure As Figure 2 132 illustrates a double log diagram the straight line between P1 and P2 can be expressed by the following ...

Page 345: ...in the Section General grants the phase selective logic release the present number of operating cycles is calculated based on the tripping currents determined when the CB operating time on tripping has elapsed They are set off against the remaining lifetime allowing the present statistic values to be displayed and the evaluation to be started using the specified threshold If one of the new values ...

Page 346: ...ΣI 2t is generated Commissioning Usually no measures are required for commissioning However should the protection device be exchanged e g old circuit breaker and a new protection device the initial values of the respective limit or statistical values must be determined via the switching statistics of the respective circuit breaker 2 23 2 3 Motor Statistics General There are two different types of ...

Page 347: ...EC 4 System Description provides a description of how to read out the statistical counters via the device front panel or DIGSI Setting or resetting of these statistical counters takes place under the menu item MESSAGES STATISTICS by overwriting the counter values displayed Circuit Breaker Maintenance Under address 172 52 B WEAR MONIT one of the alternatives ΣIx procedure 2P procedure I2t procedure...

Page 348: ...ent powers the values are referred to the involuted CB rated operational current This value is indicated in the CB data at address 260 Ir 52 in the P System Data 1 and can be set as primary value This reference allows the threshold of the ΣIx procedure to correspond to the maximum number of make break operations For a circuit breaker whose contacts have not yet been worn the maximum number of make...

Page 349: ...260 Ir 52 Point P2 is determined by the maximum number of make break operations parameter 263 OP CYCLES Isc for rated fault tripping current Isc parameter 262 Isc 52 For the procedure to operate correctly the time response of the circuit breaker must be specified in parameters 266T 52 BREAKTIME and 267T 52 OPENING I2 t Procedure The I2 t procedure is activated via configuration parameter 172 52 B ...

Page 350: ...urrent2 VI Startup Current 2 10039 StartupVoltage2 VI Startup Voltage 2 10040 StartDuration3 VI Startup Duration 3 10041 StartupCurrent3 VI Startup Current 3 10042 StartupVoltage3 VI Startup Voltage 3 10043 StartDuration4 VI Startup Duration 4 10044 StartupCurrent4 VI Startup Current 4 10045 StartupVoltage4 VI Startup Voltage 4 10046 StartDuration5 VI Startup Duration 5 10047 StartupCurrent5 VI St...

Page 351: ...e and correct entry of the nominal values for the instrument transformers and the protected equipment as well as current and voltage transformer ratios in the ground paths when configuring the device The following table shows the formulas which are the basis for the conversion of secondary values to primary values and percentages 2 23 3 1 Display of Measured Values Table 2 27 Conversion formulae b...

Page 352: ...measured value of restart inhibit rotor winding Θ Restart restarting limit of restart inhibit TReclose total time before the motor can be restarted ΘRTD 1 to ΘRTD 12 temperature values at the RTD boxes Upon delivery the power and operating values are set in such manner that power in line direction is positive Active components in line direction and inductive reactive components in line direction a...

Page 353: ...current and voltage within the system data The current unit format can be determined in DIGSI or at the device via Menu Opera tional Values The user can select via DIGSI which operational measured values primary secondary or percentage must be transmitted The measured values are always transmitted as 16 bit values including sign range 32768 The user can define the scaling of the operational measur...

Page 354: ... MV Temperature of RTD 2 1070 Θ RTD 3 MV Temperature of RTD 3 1071 Θ RTD 4 MV Temperature of RTD 4 1072 Θ RTD 5 MV Temperature of RTD 5 1073 Θ RTD 6 MV Temperature of RTD 6 1074 Θ RTD 7 MV Temperature of RTD 7 1075 Θ RTD 8 MV Temperature of RTD 8 1076 Θ RTD 9 MV Temperature of RTD 9 1077 Θ RTD10 MV Temperature of RTD10 1078 Θ RTD11 MV Temperature of RTD11 1079 Θ RTD12 MV Temperature of RTD12 16031...

Page 355: ...e the second number gives the frequency of updates within the time window 15 Min 3 Subs for example means Time average is generated for all measured values with a window of 15 minutes The output is updated every 15 3 5 minutes With address 8302 DMD Sync Time the starting time for the averaging window set under address 8301 is determined This setting specifies if the window should start on the hour...

Page 356: ...ed The min max values can be reset via binary inputs via DIGSI or via the integrated control panel at any time In addition the reset can also take place cyclically beginning with a pre selected point in time 2 23 5 2 Setting Notes Minimum and Maximum Values The tracking of minimum and maximum values can be reset automatically at a programmable point in time To select this feature address 8311 MinM...

Page 357: ...a Reset SP Q MIN MAX Buffer Reset 403 Idmd MiMaReset SP Idmd MIN MAX Buffer Reset 404 Pdmd MiMaReset SP Pdmd MIN MAX Buffer Reset 405 Qdmd MiMaReset SP Qdmd MIN MAX Buffer Reset 406 Sdmd MiMaReset SP Sdmd MIN MAX Buffer Reset 407 Frq MiMa Reset SP Frq MIN MAX Buffer Reset 408 PF MiMaReset SP Power Factor MIN MAX Buffer Reset 412 Θ MiMa Reset SP Theta MIN MAX Buffer Reset 837 IAdmdMin MVT I A Deman...

Page 358: ... MVT Vc a Min 871 Vc aMax MVT Vc a Max 872 Vn Min MVT V neutral Min 873 Vn Max MVT V neutral Max 874 V1 Min MVT V1 positive sequence Voltage Minimum 875 V1 Max MVT V1 positive sequence Voltage Maximum 876 Pmin MVT Active Power Minimum 877 Pmax MVT Active Power Maximum 878 Qmin MVT Reactive Power Minimum 879 Qmax MVT Reactive Power Maximum 880 Smin MVT Apparent Power Minimum 881 Smax MVT Apparent P...

Page 359: ...hat reason in the event of a fault it may not respond to fast measured value changes before protection functions are started and tripped This monitoring program is not suitable for blocking protection functions 2 23 6 1 Description Setpoint Monitoring Upon delivery the following individual setpoint levels are configured IAdmd Exceeding a preset maximum average value in Phase A IBdmd Exceeding a pr...

Page 360: ...nder current PF LV Power Factor 270 SP Pressure OUT Set Point Pressure 271 SP Temp OUT Set Point Temp 273 SP I A dmd OUT Set Point Phase A dmd 274 SP I B dmd OUT Set Point Phase B dmd 275 SP I C dmd OUT Set Point Phase C dmd 276 SP I1dmd OUT Set Point positive sequence I1dmd 277 SP Pdmd OUT Set Point Pdmd 278 SP Qdmd OUT Set Point Qdmd 279 SP Sdmd OUT Set Point Sdmd 284 SP 37 1 alarm OUT Set Point...

Page 361: ... Double click to display the corresponding contents in another window By overwriting the previous value the settings can be changed please refer to the SIPROTEC 4 System Description 2 23 7 3 Information List No Information Type of In formation Comments OpHour LV Operating hours greater than 272 SP Op Hours OUT Set Point Operating Hours 16004 ΣI x LV Threshold Sum Current Exponentiation 16005 Thres...

Page 362: ... The signs of the measured values appear as configured in address 1108 P Q sign see Section Display of Measured Values 2 23 8 2 Setting Notes Setting of parameter for meter resolution Parameter 8315 MeterResolution can be used to maximize the resolution of the metered energy values by Factor 10 or Factor 100 compared to the Standard setting 2 23 8 3 Settings 2 23 8 4 Information List Addr Paramete...

Page 363: ...features a system interface and uses it to communicate with the control center the DIGSI device operation can be used to test if messages are transmitted correctly A dialog box shows the display texts of all messages which were allocated to the system interface in the con figuration matrix In another column of the dialog box you can specify a value for the messages you intend to test e g ON OFF Af...

Page 364: ...llation or during operation It uses Internet technology for this purpose The display is effected by means of a Web browser e g the Internet Explorer The SIPROTEC Web Monitor provides a variety of comprehensive device functions other available functions are device specific For the 7SJ62 64 a phase diagram and an observation function for the illustration of syn chronization data are implemented as a...

Page 365: ... operator interface via a COM port of the operator PC and the Web Monitor at the rear operating interface via another COM port of the operating PC The Web Monitor consists of HTML pages and the Java Applets contained therein which are stored in the 7SJ62 64 SIPROTEC 4 device in EEPROM It forms an integral part of the SIPROTEC 4 device firmware and therefore does not need not be installed separatel...

Page 366: ...gnostics Device File System CFC A description of these functions is provided in the Online Help of DIGSI as from Version V4 60 Figure 2 135 Web Monitor Default Display The above figure of the device operation view shows a device connected through the data transmission link with its control keyboard and display elements display LEDs inscriptions The device can be operated with the keys shown in the...

Page 367: ...IGSI via Interfaces Operator Interface on Device for access via serial interface or via Interfaces Ether net on Device for access via the Ethernet interface see the following figure Figure 2 136 Setting the Web Monitor authorization for acces via Ethernet interface As an example for the basic functionality the figure below shows messages of the event log of the device in the form of a list These m...

Page 368: ...d via the Web Monitor The synchronisation function includes the following views Synchronization range The synchronisation ranges are displayed in a coordinate system The X axis shows the frequency and the Y axis the voltage Synchronoscope The synchronoscope is dynamically visualized by three diagrams showing respectively the difference angle the difference voltages and the difference frequency Syn...

Page 369: ... list An LED icon shows the current status of the selected group bright green ON for active and dark green OFF for inactive For an inactive function group only the parameter settings are shown whereas for an active function group the current measured values are displayed as well On startup the first active function group found is displayed automatically All measured values are read out directly in...

Page 370: ...e interface of the device via a direct optical connection to a star coupler Connec tion of the operator PC s serial interface to a star coupler In this way several devices can be operated within the system the existing installation can be used for central operation of protection devices Operation via Ethernet Connection via an Ethernet interface This type of connection requires an EN100 communicat...

Page 371: ...e navigation bar A list with the desired infor mation appears see Figure 2 139 Figure 2 139 Measured values in the Web Monitor examples for measured values The currents voltages and their phase angles derived from the primary and secondary measured values are graphically displayed as phasor diagrams see Figure 2 140 In addition to phasor diagrams of the measured values the numerical values as well...

Page 372: ...P Configura tion or via DIGSI for the front operator interface and for the rear service interface These are IP addresses related to the interface via which communication with the PC and the Web monitor is to be performed The IP addresses apply to SIPROTEC for the following operations via the front operator interface 192 168 1 1 rear service interface 192 168 2 1 If the device has an EN100 module o...

Page 373: ...e Usually it is a phase voltage However it may also be a phase to phase voltage Via configuration the device may be adapted for such an application 2 24 1 Connection The device may optionally be supplied with a phase to ground voltage e g VAA GN or a phase to phase voltage e g VAABB The connection mode has been specified during the configuration see Subsection 2 1 3 2 in address 240 VT Connect 1ph...

Page 374: ...connection the threshold generally represents a phase to phase quantity See also Section 2 6 4 Functional logic scope of settings and information of this function are described in Section 2 6 Frequency Protection 81 Elements Depending on the configuration in address 240 frequency protection is either operated by a phase to ground or a phase to phase voltage A maximum voltage may be configured If t...

Page 375: ...erated in non directional mode Except for the above mentioned restriction the functional logic scope of settings and information are described in Section 2 12 Fault Locator If the device is connected to only one voltage transformer this function is set to inactive and hidden Monitoring Functions Voltage measuring monitoring functions such as Voltage symmetry and Fuse Failure Monitor cannot be ap p...

Page 376: ...ses 202 Vnom PRIMARY and 203 Vnom SECONDARY set as usual the voltage transformer nominal values defined as phase to phase quantities This depends on whether the device is connected to a phase voltage or phase to phase voltage Undervoltage Protection Overvoltage Protection Frequency Protection If phase to ground voltage connection is selected for address 240 the voltage thresholds of this function ...

Page 377: ...ngle phase voltage VA N is connected see Figure 2 143 Threshold values for voltage protection are set as follows Overvoltage 59 1 to 120 VNom Undervoltage 27 1 to 60 VNom Figure 2 143 Example of a single phase voltage transformer connection phase to ground Apply the following settings to the device Address 202 Vnom PRIMARY 138 kV Address 203 Vnom SECONDARY 115 V Address 240 VT Connect 1ph Van w w ...

Page 378: ...Device Devices with integrated or detached operator panel can control switchgear via the operator panel of the device In addition control can be executed via the operator interface using a personal computer and via the serial in terface with a link to the substation control equipment Applications Switchgears with single and double busbars Prerequisites The number of switchgear devices to be contro...

Page 379: ... the corresponding actual status Cancellation via the ESC key is possible at any time before the control command is issued During normal processing the control display indicates the new actual status after the control command was executed and the message command end appears at the lower display edge In case of control commands with feedback the message FB reached is displayed for a short time befo...

Page 380: ...rlocking Disconnect switch Open Disc Close IntSP Interlocking Disconnect switch Close GndSw Open IntSP Interlocking Ground switch Open GndSw Cl IntSP Interlocking Ground switch Close UnlockDT IntSP Unlock data transmission via BI Q2 Op Cl CF_D2 Q2 Open Close Q2 Op Cl DP Q2 Open Close Q9 Op Cl CF_D2 Q9 Open Close Q9 Op Cl DP Q9 Open Close Fan ON OFF CF_D2 Fan ON OFF Fan ON OFF DP Fan ON OFF 31000 Q...

Page 381: ...itiate internal functions simulate changes of state or to acknowledge changes of state Manual overriding commands to manually update information on process dependent objects such as an nunciations and switching states e g if the communication with the process is interrupted Manually over ridden objects are flagged as such in the information status and can be displayed accordingly Tagging commands ...

Page 382: ... controller Double Operation interlocking against parallel switching operation Protection Blocking blocking of switching operations by protective functions Fixed Command Checks Internal Process Time software watch dog which checks the time for processing the control action between initiation of the control and final close of the relay contact Setting Modification in Process if setting modification...

Page 383: ...configurable command checks in the SIPROTEC 4 devices are also called standard interlocking These checks can be activated via DIGSI interlocked switching tagging or deactivated non interlocked Deactivated interlock switching means the configured interlocking conditions are not checked in the relay Interlocked switching means that all configured interlocking conditions are checked within the comman...

Page 384: ...es as soon as one of the protection functions of the unit has opened a fault case The OPEN command by contrast can always be executed Please be aware activation of thermal overload protection elements or sensitive ground fault de tection can create and maintain a fault condition status and can therefore block CLOSE commands If the interlocking is removed consider that on the other hand the restart...

Page 385: ...Functions 2 25 Breaker Control SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 385 Figure 2 145 Standard interlockings w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 386: ...owing table Table 2 29 Command types and corresponding messages The following figure shows all interlocking conditions which usually appear in the display of the device for three switchgear items with the relevant abbreviations explained in the previous table All parameterized inter locking conditions are indicated Figure 2 147 Example of configured interlocking conditions Interlocking Commands Ab...

Page 387: ...DIGSI connection When a local or remote DIGSI PC logs on to the device it enters its Virtual Device Number VD The device only accepts commands having that VD with switching authority OFF or REMOTE When the DIGSI PC logs off the VD is cancelled Commands are checked for their source SC and the device settings and compared to the information set in the objects Switching authority and Switching author...

Page 388: ...ching modes remote are defined Remote or DIGSI commands SC LOCAL REMOTE or DIGSI interlocked or non interlocked switching Here deactivation of interlocking is accomplished via a separate command The position of the key switch is irrelevant For commands from CFC SC AUTO SICAM please observe the notes in the CFC manual compo nent BOOL to command Switching Mode for devices without operator panel The ...

Page 389: ...and the command will be refused with the operating message set condition equals actual condition If the circuit breaker switchgear device is in the intermediate position then this check is not performed Bypassing Interlockings Bypassing configured interlockings at the time of the switching action happens device internal via interlocking recognition in the command job or globally via so called swit...

Page 390: ... with the local command but by ordinary command and feedback information recording Monitoring of Feedback Information The processing of commands monitors the command execution and timing of feedback information for all com mands At the same time the command is sent the monitoring time is started monitoring of the command ex ecution This time controls whether the device achieves the required final ...

Page 391: ...n and control systems the management of power systems and the safety rules and regulations Hard ware adjustments to the power system data might be necessary The primary tests require the protected object line transformer etc to carry load 3 1 Mounting and Connections 392 3 2 Checking Connections 438 3 3 Commissioning 443 3 4 Final Preparation of the Device 463 w w w E l e c t r i c a l P a r t M a...

Page 392: ...onnection Examples in Appendix A 3 The devices 7SJ621 and 7SJ622 have 3 voltage inputs the devices 7SJ623 7SJ624 and all 7SJ64 variants have 4 voltage inputs For the standard connection the 4th voltage measuring input is not used the address 213 VT Connect 3ph Van Vbn Vcn must be set accordingly The factor in address 206 Vph Vdelta must however be set to 1 73 this factor is used internally for the...

Page 393: ...so check that the labelling strips on the front panel correspond to the configured message functions Setting Group Change If binary inputs are used to switch setting groups please observe the following Two binary inputs must be dedicated to the purpose of changing setting groups when four groups are to be switched One binary input must be set for Set Group Bit0 the other input for Set Group Bit1 I...

Page 394: ...t be volt free i o w not be commoned with each other or with another binary input If one binary input is used a bypass resistor R must be used see following figure The resistor R is inserted into the circuit of the 52b circuit breaker auxiliary contact to facilitate the detection of a malfunction also when the 52a circuit breaker auxiliary contact is open and the trip contact has dropped out The v...

Page 395: ...sults in Rmax Rmin the calculation must be repeated with the next lowest switching thresh old VBI min and this threshold must be implemented in the relay using plug in jumpers see Section Hardware Modifications For the power consumption of the resistance IBI HIGH Constant current with activated BI 1 8 mA VBI min minimum control voltage for BI 19 V for delivery setting for nominal voltage of 24 48 ...

Page 396: ... the power is IBI HIGH 1 8 mA SIPROTEC 4 7SJ62 64 VBI min 19 V for delivery setting for nominal voltage of 24 48 60 250 V device 7SJ62 64 88 V for delivery setting for nominal voltage of 110 125 220 250 V device 7SJ62 64 VCTR 110 V system release circuit RCBTC 500 Ω from system trip circuit VCBTC LOW 2 V system release circuit w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 397: ...ntact The live contacts of devices 7SJ62 64 are changeover contacts With device 7SJ64 either the normally closed NC contact or the normally open NO contact can be connected to two device connections via a plug in jumper X40 The assignment of the plug in jumper to the contact type and the spatial arrangement of the jumper are described in the following section for the device 7SJ64 Nominal Currents ...

Page 398: ...h mounting and for surface mounted devices with detached or without operator panel The following section under margin heading Rreplacing Interface Modules describes which interfaces can be exchanged and how this is done Termination of Bus capable Interfaces If the device is equipped with a serial RS485 interface or Profibus they must be terminated with resistors at the last device on the bus to en...

Page 399: ... needed screwdriver with a 5 to 6 mm wide tip a Philips screwdriver size 1 5 mm socket or nut driver Unfasten the screw posts of the D subminiature connectors on the back panel at location A and C 7SJ64 This is not necessary if the device is designed for surface mounting If the device has additional interfaces at locations B and D apart from interfaces at locations A and D the screws located diago...

Page 400: ...e rear side must be removed Disconnect the ribbon cables between the CPU unit No 1 and the input output printed circuit boards I O No 2 No 3 and No 4 Remove the boards and set them on the grounded mat to protect them from ESD damage In the case of the device variant for panel surface mounting please be aware of the fact a certain amount of force is re quired in order to remove the CPU board due to...

Page 401: ...nt of the modules for devices 7SJ64 with housing size 1 3 The sub sequent figures illustrate housing sizes 1 2 and 1 1 Figure 3 4 Front view with housing size 1 3 after removal of the front cover simplified and scaled down Figure 3 5 Front view of the 7SJ64 with housing size 1 2 after removal of the front cover simplified and scaled down w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 402: ...e date 01 2008 402 Figure 3 6 Front view of the 7SJ645 with housing size 1 1 after removal of the front cover simplified and scaled down Figure 3 7 Front view of the 7SJ647 with housing size 1 1 after removal of the front cover simplified and scaled down w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 403: ...tion of the miniature fuse F1 and of the buffer battery G1 are also shown in the following figures Processor Board A CPU for 7SJ62 DD Figure 3 8 Processor printed circuit board A CPU for devices up to release DD with jumpers settings required for the board configuration The provided nominal voltage of the integrated power supply is checked according to Table 3 2 and the select ed pickup voltages o...

Page 404: ...uts BI1 to BI3 on the processor board A CPU to 7SJ62 DD 1 Factory settings for devices with power supply voltages of 24 VDC to 125 VDC 2 Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 230 VAC Jumper Rated Voltage 60 to 125 VDC 110 to 250 VDC 115 VAC 24 48 VDC 230 VAC X51 1 2 2 3 Jumpers X51 to X53 are not used X52 1 2 and 3 4 2 3 X53 1 2 2 3 interchangeable c...

Page 405: ...eleases EE and higher with jumpers settings required for the module configuration up to firmware V4 6 The preset nominal voltage of the integrated power supply is checked according to Table 3 4 the pickup volt ages of the binary inputs BI1 to BI3 are checked according to Table 3 5 and the contact mode of the binary outputs BO1 and BO2 is checked according to Table 3 6 w w w E l e c t r i c a l P a...

Page 406: ...ctory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 230 VAC Contact Mode for Binary Outputs BO1 and BO2 Table 3 6 Jumper settings for the contact mode of the binary inputs BI1 to BI3 on the processor printed circuit board A CPU for 7SJ62 EE Jumper Nominal Voltage 24 48 VDC 60 to 125 VDC 110 to 250 VDC 115 to 230 VAC X51 Not used 1 2 2 3 X52 Not used 1 2 and 3 4 2 3 ...

Page 407: ...140 C207 2 Release date 01 2008 407 Processor Board A CPU for 7SJ62 FF Figure 3 10 Processor printed circuit board A CPU for devices releases FF and higher with jumpers settings required for the module configuration as from firmware V4 7 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 408: ... settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 230 VAC Contact Mode for Binary Outputs BO1 and BO2 Table 3 9 Jumper settings for the contact mode of relays BO1 and BO3 on the processor board A CPU as from 7SJ62 FF Jumper Rated Voltage 24 48 VDC 60 to 125 VDC 110 to 250 VDC 115 to 230 VAC X51 not used 1 2 2 3 X52 not used 1 2 and 3 4 2 3 X53 not used 1 2 2 3 not chan...

Page 409: ... to BI11 are checked Figure 3 11 Input output module A I O 2 for devices releases EE and higher with representation of the jumper settings required for the board configuration The jumpers X60 to X63 must all be set to the same rated current i e one jumper X61 to X63 for each input transformer and in addition the common jumper X60 The jumper X64 determines the rated current for the input IN and may...

Page 410: ...on the input output board A I O 2 up to 7SJ62 EE 1 Factory settings for devices with power supply voltages of 24 VDC to 125 VDC 2 Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 230 VAC Binary inputs Jumper 19 VDC threshold 1 88 VDC threshold 2 BI4 X21 L H BI5 X22 L H BI6 X23 L H BI7 X24 L H BI8 X25 L H BI9 X26 L H BI10 X27 L H BI11 X28 L H w w w E l e c t r i...

Page 411: ... and higher with representation of the jumper settings required for the board configuration The jumpers X60 to X63 must all be set to the same rated current i e one jumper X61 to X63 for each input transformer and in addition the common jumper X60 The jumper X64 determines the rated current for the input IN and may thus have a setting that deviates from that of the phase currents In models with se...

Page 412: ...t board A I O 2 as from 7SJ62 FF 1 Factory settings for devices with power supply voltages of 24 VDC to 125 VDC 2 Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 230 VAC Binary inputs Jumper 19 VDC threshold 1 88 VDC threshold 2 176 VDC threshold BI4 X21 L M H BI5 X22 L M H BI6 X23 L M H BI7 X24 L M H BI8 X25 L M H BI9 X26 L M H BI10 X27 L M H BI11 X28 L M H w...

Page 413: ... of the miniature fuse F1 and of the buffer battery G1 are shown in the following figure Figure 3 13 Processor printed circuit board C CPU 2 with jumpers settings required for the board configuration The set nominal voltage of the integrated power supply is checked according to Table 3 12 the quiescent state of the life contact according to Table 3 13 and the selected control voltages of the binar...

Page 414: ...the C CPU 2 processor board 1 Factory settings for devices with power supply voltages of 24 to 125 VDC 2 Factory settings for devices with power supply voltages of 110 to 250 VDC and 115 VAC or 115 to 230 VAC 3 Use only with pickup voltages 220 or 250 VDC Jumper Rated Voltage 24 to 48 VDC 60 to 125 VDC 110 to 250 VDC 115 to 230 VAC 1 X51 not used 1 2 2 3 X52 not used 1 2 and 3 4 2 3 X53 not used 1...

Page 415: ...ording to RS232 standard DIN 66020 are not available The modem signals are not required since the connection to the SIPROTEC 4 devices is always operated in the half duplex mode Please use the connection cable with order number 7XV5100 4 The jumper setting 2 3 is also necessary when using the RTD box in half duplex operation Jumper setting 1 2 This setting makes the modem signals available i e for...

Page 416: ...as currently no function The factory setting is 1 2 The terminating resistors can also be connected externally e g to the connection module In this case the terminating resistors located on the RS485 or PROFIBUS interface module or directly on the PCB of the 7SJ64 processor board C CPU 2 must be de energized Figure 3 14 Termination of the RS485 interface external Jumper Terminating resistor closed...

Page 417: ... C I O 11 The jumpers X60 to X63 must all be set to the same rated current i e one jumper X61 to X63 for each input trans former of the phase currents and in addition the common jumper X60 The jumper X64 determines the rated current for the input IN and may thus have a setting that deviates from that of the phase currents In models with sensitive ground fault current input there is no jumper X64 F...

Page 418: ...oltages 220 or 250 VDC Jumpers X71 X72 and X73 on the input output board C I O 11 are used to set the bus address and must not be changed The following table lists the jumper presettings Mounting location with housing size 1 3 Serial no 2 in Figure 3 4 slot 19 with housing size 1 2 Serial no 2 in Figure 3 5 slot 33 with housing size 1 1 Serial no 2 in Figure 3 6 slot 33 on right side Bus Address T...

Page 419: ...3 16 Figure 3 16 Input output board B I O 2 with representation of the jumper settings required for the board configuration The selected pickup voltages of the binary inputs BI8 to BI20 with housing size 1 2 are checked according to Table 3 20 BI8 to BI33 with housing size 1 1 are checked according to Table 3 21 Figures 3 5 and 3 6 illustrate the assignment of the binary inputs to the module slot ...

Page 420: ... settings for devices with power supply voltages of 24 VDC to 125 VDC 2 Factory settings for devices with power supply voltages of 110 to 220 VDC and 115 VAC or 115 to 230 VAC Binary Inputs Jumper 19 VDC Pickup 1 88 VDC Pickup 2 Slot 19 BI8 X21 1 2 2 3 BI9 X22 1 2 2 3 BI10 X23 1 2 2 3 BI 11 X24 1 2 2 3 BI12 X25 1 2 2 3 BI13 X26 1 2 2 3 BI14 X27 1 2 2 3 BI15 X28 1 2 2 3 BI16 X29 1 2 2 3 BI17 X30 1 ...

Page 421: ...gs The mounting locations are shown in Figures 3 5 and 3 6 Bus Addresses Table 3 22 Jumper settings of bus addresses of input output modules B I O 2 for 7SJ64 housing size 1 2 Table 3 23 Jumper settings of bus addresses of input output modules B I O 2 for 7SJ64 housing size 1 1 Jumper Mounting Location Slot 19 X71 1 2 X72 2 3 X73 1 2 Jumper Mounting Location Slot 19 right side Slot 33 left side X7...

Page 422: ...h representation of the jumper settings required for the board configuration The selected control voltages of binary inputs BI8 to BI15 are checked according to Table 3 24 Jumper settings for the contact mode of binary output BO6 are checked according to Table 3 25 Figure 3 5 illustrates the assignment of the binary inputs to the mounting location w w w E l e c t r i c a l P a r t M a n u a l s c ...

Page 423: ...able shows the setting of jumper X40 regarding the contact mode Table 3 25 Jumper settings for contact mode of the binary output BO6 on the C I O 1 board PCB Addresses Jumpers X71 X72 and X73 on the input output board C I O 1 are used to set the bus address and must not be changed The following table lists the jumper presettings The slots of the boards are shown in Figure 3 5 Table 3 26 Jumper Set...

Page 424: ...f the printed circuit board for the input output board C I O 4 is illustrated in the following figure The selected pickup voltages of the binary inputs BI6 to BI20 are checked according to Table 3 14 Figure 3 18 Input output module C I O 4 with representation of the jumper settings required for the module configuration w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 425: ...ress Jumpers X71 X72 and X73 on the C I O 4 board serve to set the bus address The jumpers must not be changed The following table lists the jumper presettings Table 3 28 Jumper Settings of module addresses of C I O 4 Board Binary inputs Jumper 19 VDC threshold 1 88 VDC threshold 2 176 VDC threshold 3 BI34 X21 1 2 2 3 3 4 BI35 X22 1 2 2 3 3 4 BI36 X23 1 2 2 3 3 4 BI37 X24 1 2 2 3 3 4 BI38 X25 1 2 ...

Page 426: ...No 1 in Figure 3 3 to 3 6 of the devices 7SJ62 64 Please note the following The interface modules can only be exchanged in devices designed for panel and cubicle mounting and surface mounted devices with detached or without operator panel Devices in surface mounted housings with two tier terminals have to be retrofitted at our factory Use only interface modules that can be ordered in our facilitie...

Page 427: ...unting Loca tion Port Exchange Module System Interface 7SJ62 64 B IEC 60870 5 103 RS232 IEC 60870 5 103 RS485 IEC 60870 5 103 redundant RS485 FO 820 nm Profibus FMS RS 485 Profibus FMS double ring Profibus FMS single ring Profibus DP RS485 Profibus DP double ring Modbus RS485 Modbus 820 nm DNP 3 0 RS485 DNP 3 0 820 nm IEC 61850 Ethernet electrical IEC 61850 Ethernet optical DIGSI Modem Interface R...

Page 428: ...CTS feature which is important for modem communication Table 3 30 Jumper setting for CTS Clear to Send on the interface module 1 Default setting Jumper setting 2 3 The modem connection is usually established with star coupler or fiber optic converter Therefore the modem control signals according to RS232 Standard DIN 66020 are not available The modem signals are not required since the connection t...

Page 429: ...ersa according to Figure 3 20 Figure 3 21 Position of terminating resistors and the plug in jumpers for configuration of the RS485 interface Profibus FMS DP DNP 3 0 Modbus Figure 3 22 Position of the plug in jumpers for the configuration of the terminating resistors at the Profibus FMS and DP DNP 3 0 and Modbus interfaces IEC 61850 Ethernet EN100 The interface module does not feature any jumpers I...

Page 430: ...hown in Figures 3 3 to 3 6 For the model of the device designed for surface mounting use the metal lever to insert the processor circuit board CPU board The installation is easier with the lever First plug the plug connectors of the ribbon cable into the input output boards I O and then onto the proces sor module CPU Do not bend any connector pins Do not use force Insert the plug connector of the ...

Page 431: ... Connect the ground on the rear plate of the device to the protective ground of the panel using at least one M4 screw The cross sectional area of the ground wire must be equal to the cross sectional area of any other control conductor connected to the device The cross section of the ground wire must be at least 2 5 mm 2 Connections are realized via the plug or screw terminals on the rear side of t...

Page 432: ...ions SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 432 Figure 3 25 Panel flush mounting of a device housing size 1 2 Figure 3 26 Panel flush mounting of a device housing size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 433: ...ews Put the 4 or six covers back in place Tighten the mounting brackets to the rack or cubicle using eight screws Connect the ground on the rear plate of the device to the protective ground of the panel Using at least one M4 screw The cross section of the line here used must correspond to the maximum connected cross sec tion at least 2 5 mm2 Connections are realized via the plug or screw terminals...

Page 434: ...ng 3 1 Mounting and Connections SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 434 Figure 3 28 Installing a device in a rack or cubicle housing size 1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 435: ... grounding terminal on the rear plate of the device The cross sectional area of the cable used must correspond to the maximum connected cross section but must be at least 2 5 mm2 Alternatively fasten the said ground to the grounding surface on the side with at least one M4 screw Connections according to the circuit diagram via screw terminals connections for optical fiber cable and electrical comm...

Page 436: ...vers on the corners of the front plate Thus 4 respectively elongated holes in the mounting bracket are revealed and can be accessed Insert the operator panel into the panel cut out and fasten with four screws For dimensions see Technical Data Replace the 4 covers Connect the ground on the rear plate of the device to the protective ground of the panel Using at least one M4 screw The cross section o...

Page 437: ...Plug the 68 pin connector of the cable into the corresponding connection at the rear side of the device Caution Be careful when pulling or plugging the dongle cable Non observance of the following measures can result in minor personal injury or property damage Never pull or plug the dongle cable while the device is alive Without the cable the device is not ready for op eration The connector of the...

Page 438: ...e Figure 3 31 9 pin D subminiature female connectors Figure 3 32 RJ45 sockets Operator Interface When the recommended communication cable is used refer to the Appendix for the ordering number correct connection between the SIPROTEC 4 device and the PC or laptop is automatically ensured Service Interface Check the data connection if the service interface Port C is used to communicate with the devic...

Page 439: ...ording to one of the connection examples given in Appendix A 3 must be verified For the assignment of the connectors see the table above Termination The RS485 interface is bus capable for half duplex operation with the signals A A and B B and the common reference potential C C GND Verify that only at the bus of the last device the terminating resistors are con nected but not at the bus of the othe...

Page 440: ...TD Box If one or two 7XV5662 xAD temperature detection units are connected check their connections to the port port C or D Verify also the termination The terminating resistors must be connected to 7SJ62 64 see margin heading Ter mination For further information refer to the operating manual of 7XV5662 xAD Check the transmission settings at the temperature meter Besides the baud rate and the parit...

Page 441: ...d for the first time it should be in the final operating environment for at least 2 hours to equalize the temperature to minimize humidity and to avoid condensation Connections are checked with the device at its final location The plant must first be switched off and grounded Proceed as follows in order to check the system connections Protective switches for the power supply and the measured volta...

Page 442: ...rent from the CTs Attach the front panel and tighten the screws Connect an ammeter in the supply circuit of the power supply A range of about 2 5 A to 5 A for the meter is appropriate Switch on m c b for auxiliary voltage supply protection check the voltage level and if applicable the po larity of the voltage at the device terminals or at the connection modules The current input should correspond ...

Page 443: ...Chapter 4 must not be exceeded neither during testing nor during commissioning When testing the device with secondary test equipment make sure that no other measurement quantities are connected and that the trip and close circuits to the circuit breakers and other primary switches are disconnect ed from the device DANGER Hazardous voltages during interruptions in secondary circuits of current tran...

Page 444: ...is in real operation DANGER Danger evolving from operating the equipment e g circuit breakers disconnectors by means of the test function Non observance of the following measure will result in death severe personal injury or substantial property damage Equipment used to allow switching such as circuit breakers or disconnectors is to be checked only during com missioning Do not under any circumstan...

Page 445: ...tion that is transmitted to the central station test the options in the list which appears in SET POINT Status Make sure that each checking process is carried out carefully without causing any danger see above and refer to DANGER Click on Send in the function to be tested and check whether the transmitted information reaches the central station and shows the desired reaction Data which are normall...

Page 446: ...ers are erased If re quired these buffers should be read out with DIGSI and saved prior to the test The hardware test can be carried out using DIGSI in the Online operating mode Open the Online directory by double clicking the operating functions for the device appear Click on Test the function selection appears in the right half of the screen Double click in the list view on Hardware Test The dia...

Page 447: ...62 64 and the system without having to generate the message that is assigned to the relay As soon as the first status change for any one of the output relays is initiated all output relays are separated from the in ternal device functions and can only be operated by the hardware test function This for example means that a switching command coming from a protection function or a control command fro...

Page 448: ... the password No 6 has been entered all binary inputs are separated from the plant and can only be activated via the hardware test function Test of the LEDs The LEDs may be tested in a similar manner to the other input output components As soon as the first state change of any LED has been triggered all LEDs are separated from the internal device functionality and can only be controlled via the ha...

Page 449: ...ction routed to the circuit breaker must be disconnected so that the trip command can only be initiated by the breaker failure protection Although the following lists do not claim to be complete they may also contain points which are to be ignored in the current application Auxiliary Contacts of the CB The circuit breaker auxiliary contact s form an essential part of the breaker failure protection...

Page 450: ... breakers largely depends on the system topology In particular with multiple busbars the trip distribution logic for the adjacent circuit breakers must be checked Here it should be checked for every busbar section that all circuit breakers which are connected to the same busbar section as the feeder circuit breaker under observation are tripped and no other breakers Termination All temporary measu...

Page 451: ...figured phase rotation in general a clockwise phase rotation If the system has an anti clockwise phase rotation this must have been considered when the power system data was set address 209 PHASE SEQ If the phase rotation is incorrect the alarm Fail Ph Seq FNo 171 is generated The measured value phase allocation must be checked and corrected if required after the line has been isolated and current...

Page 452: ... circuit system or the pickup current missing closed circuit system For open circuit system the following tests are to be proceeded The feeder protection relays of all associated feeders must be in operation At the beginning no auxiliary voltage is fed to the reverse interlocking system A test current higher than the pickup values of 50 2 PICKUP and 50 1 PICKUP or 51 PICKUP is set As a result of t...

Page 453: ...e as well The power measurement provides an initial indication as to whether the measured values have the correct po larity If both the active power and the reactive power have the wrong sign and 1108 P Q sign is set to not reversed the polarity according to address 201 CT Starpoint must be checked and corrected However power measurement itself is not able to detect all connection errors For this ...

Page 454: ... For this purpose an angle corresponding to the transformer vector group is entered in address 6X22 ANGLE ADJUSTM The angle is set in direction busbar viewed from the feeder An example is shown in Subsection 2 19 1 If necessary different transformation ratios of the transformers on the busbar and the feeder may have to be considered under address Balancing V1 V2 The synchronism and voltage check m...

Page 455: ...busbar voltage Via binary input 170 0043 25 Sync req initiate the measuring request There is no close release If there is the VT mcb for the busbar voltage is not allocated Check whether this is the required state al ternatively check the binary input FAIL BUS VT 6510 Close the VT mcb of the busbar voltage again Open the circuit breaker For the synchrocheck the program SYNC V1 V2 is set to YES add...

Page 456: ...round fault method a most reliable test result is guaranteed Therefore please proceed as follows Isolate the line and ground it on both ends During the whole testing procedure the line must be open at the remote end Make a test connection between a single phase and ground On overhead lines it can be connected any where however it must be located behind the current transformers looking from the bus...

Page 457: ...31 which can be operated as additional fault protection In the following the check is described using the directional ground fault protection function address 116 as an example To generate a displacement voltage the e n winding of one phase in the voltage transformer set e g A is bypassed see Figure 3 37 If no connection on the e n windings of the voltage transformer is provided the corresponding ...

Page 458: ...3 37 Polarity testing for IN example with current transformers configured in a Holmgreen connection VTs with broken delta connection e n winding Figure 3 38 Polarity testing for IN example with current transformers configured in a Holmgreen connection VTs Wye connected w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 459: ... device can be checked by slowly approaching the resistance value Temperature in C Temperature in F Ni 100 DIN 43760 Ni 120 DIN 34760 Pt 100 IEC 60751 50 58 74 255 89 106 80 3062819 40 40 79 1311726 94 9574071 84 270652 30 22 84 1457706 100 974925 88 2216568 20 4 89 2964487 107 155738 92 1598984 10 14 94 581528 113 497834 96 085879 0 32 100 120 100 10 50 105 551528 126 661834 103 902525 20 68 111 ...

Page 460: ...ting time a setup as shown in Figure 3 39 is recommended The timer is set to a range of 1 s and a graduation of 1 ms The circuit breaker is connected manually At the same time the timer is started After closing the poles of the circuit breaker the voltage VLine appears and the timer is stopped The time displayed by the timer is the real circuit breaker closing time If the timer is not stopped due ...

Page 461: ...interlocked switching Please note that non interlocked switching can be a safety hazard Control by Protective Functions For OPEN commands sent to the circuit breaker please take into consideration that if the internal or external automatic reclosure function is used a TRIP CLOSE test cycle is initiated DANGER A test cycle successfully started by the automatic reclosure function can lead to the clo...

Page 462: ...the oscillographic recording then occurs for instance via the binary input when the protection object is energized Those that are externally triggered that is without a protective element pickup are processed by the device as a normal oscillographic record For each oscillographic record a fault record is created which is given its individual number to ensure that assignment can be made properly Ho...

Page 463: ...at future infor mation will only apply to actual events and states see also SIPROTEC 4 System Description The counters in the switching statistics should be reset to the values that were existing prior to the testing see also SIPROTEC 4 System Description Reset the counter of the operational measured values e g operation counter if available under MAIN MENU Measured Values Reset also see SIPROTEC ...

Page 464: ...Mounting and Commissioning 3 4 Final Preparation of the Device SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 464 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 465: ...kup 495 4 7 Single phase Overcurrent Protection 496 4 8 Voltage Protection 27 59 497 4 9 Negative Sequence Protection 46 1 46 2 499 4 10 Negative Sequence Protection 46 TOC 500 4 11 Motor Starting Protection 48 506 4 12 Motor Restart Inhibit 66 507 4 13 Load Jam Protection 508 4 14 Frequency Protection 81 O U 509 4 15 Thermal Overload Protection 49 510 4 16 Ground Fault Protection 64 67N s 50N s 5...

Page 466: ...ath at INom 1 A at INom 5 A for sensitive ground fault detection at 1 A Approx 0 05 VA Approx 0 3 VA Approx 0 05 VA Current overload capability Thermal rms Dynamic peak value 100 INom for 1 s 30 INom for 10 s 4 INom continuous 250 INom half cycle Current overload capability for high sensitivity input INs 1 Thermal rms Dynamic peak value 300 A for 1 s 100 A for 10 s 15 A continuous 750 A half cycle...

Page 467: ...J641 Approx 5 5 W Approx 13 W 7SJ642 Approx 5 5 W Approx 12 W 7SJ645 Approx 6 5 W Approx 15 W 7SJ647 approx 7 5 W approx 21 W Bridging time for failure short circuit IEC 60255 11 in not energized operation 50 ms at V 110 V 20 ms at V 24 V Voltage Supply via Integrated Converter Nominal Auxiliary Voltage AC VAux 115 VAC 230 VAC Permissible Voltage Ranges 92 to 132 VAC 184 to 265 VAC Power input at ...

Page 468: ...0 7SJ645 BI8 19 BI21 32 BI1 7 BI20 BI33 7SJ647 BI8 19 BI21 32 BI1 7 BI20 BI33 48 Current consumption picked up independent of the operating voltage approx 0 9 mA approx 1 8 mA Pickup time approx 9 ms approx 4 ms Secured switching threshold adjustable with jumpers for nominal voltages 24 48 60 110 125 VDC V high 19 V V low 10 V for nominal voltages 110 125 220 250 VDC V high 88 V V low 44 V for nom...

Page 469: ... 8 7SJ647 21 1 8 Switching Capability MAKE 1000 W VA Switching Capability BRAKE 30 VA 40 W resistive 25 W at L R 50 ms Switching Voltage 250 VDC VAC 250 VDC VAC admissible current per contact continuous 5 A admissible current per contact close and hold 30 A for 0 5 s NO contact Total current on common path 5 A continuous 30 A for 0 5 s max switching capability for 30 s at 48 V to 250 V at 24 V 100...

Page 470: ...rear panel mounting location C 9 pole D SUB miniature female connector Connection for surface mounted casing at the housing mounted case on the case bottom shielded data cable Test Voltage 500 VAC RS232 Maximum Distance of Transmission 49 2 feet 15 m RS485 Maximum Distance of Transmission 3 280 feet 1 000 m Fiber Optical Link FO 1 FO connector type ST connector Connection for flush mounted casing ...

Page 471: ... 62 5 125 µm Permissible Optical Link Signal Atten uation max 8 dB with glass fiber 62 5 125 µm Maximum Distance of Transmission max 0 93 miles 1 5 km Character Idle State Configurable factory setting Light off IEC 60870 5 103 single RS232 RS485 FO according to the ordering variant isolated interface for data transfer to a master terminal RS232 Connection for flush mounted casing rear panel mounti...

Page 472: ... max 57 600 baud Factory setting 19 200 Bd Bridgeable distance max 1 km Profibus RS485 FMS and DP Connection for flush mounted casing Rear panel mounting location B 9 pin D SUB miniature connector Connection for surface mounted casing at the housing mounted case on the case bottom Test Voltage 500 VAC Transmission Speed up to 1 5 MBd Maximum Distance of Transmission 3 280 ft or 1 000 m at 93 75 kB...

Page 473: ...ng to EN 60825 1 2 using glass fiber 50 125 µm or using glass fiber 62 5 125 µm Permissible Optical Link Signal Atten uation max 8 dB with glass fiber 62 5 125 µm Maximum Distance of Transmission max 0 93 miles 1 5 km Ethernet electrical EN 100 for IEC61850 and DIGSI Connection for flush mounted casing rear panel mounting location B 2 x RJ45 socket contact 100BaseT acc to IEEE802 3 Connection for ...

Page 474: ...mA 4 5 mA to 9 3 mA 4 5 mA to 8 7 mA RI 890 at VI 4 V 1930 at VI 8 7 V 3780 at VI 17 V 640 at VI 6 V 1700 at VI 15 8 V 3560 at VI 31 V Standards IEC 60255 product standards ANSI IEEE Std C37 90 0 1 2 UL 508 DIN 57435 Part 303 for more standards see also individual functions Standards IEC 60255 5 and IEC 60870 2 1 High Voltage Test routine test All circuits except power supply Binary Inputs Communi...

Page 475: ...Auxiliary voltage common mode 2 kV 12 Ω 9 µF diff mode 1 kV 2 Ω 18 µF Measuring Inputs Binary Inputs and Relay Outputs common mode 2 kV 42 Ω 0 5 µF diff mode 1 kV 42 Ω 0 5 µF HF on lines amplitude modulated IEC 61000 4 6 Class III 10 V 150 kHz to 80 MHz 80 AM 1 kHz Power System Frequency Magnetic Field IEC 61000 4 8 class IV IEC 60255 6 30 A m continuous 300 A m for 3 s 50 Hz 0 5 mT 50 Hz Oscillat...

Page 476: ...s I IEC 60068 3 3 Sinusoidal 1 Hz to 8 Hz 3 5 mm amplitude horizontal vectors 1 Hz to 8 Hz 1 5 mm Amplitude vertical axis 8 Hz to 35 Hz 1 g acceleration horizontal axis 8 Hz to 35 Hz 0 5 g acceleration vertical axis frequency sweep rate 1 octave min 1 cycle in 3 orthogonal axes Standards IEC 60255 21 and IEC 60068 Oscillation IEC 60255 21 1 Class II IEC 60068 2 6 Sinusoidal 5 Hz to 8 Hz 7 5 mm amp...

Page 477: ...r 75 relative humidity on 56 days of the year up to 93 relative humidity con densation must be avoided Siemens recommends that all devices be installed such that they are not exposed to direct sunlight nor subject to large fluctuations in temperature that may cause condensation to occur The protective device is designed for use in an industrial environment and an electrical utility environment Pro...

Page 478: ...8 kg 7SJ645 A C in housing for detached operator panel 1 1 26 45 lb or 12 kg 7SJ647 A C for mounting with detached operator panel 1 1 12 5 kg 7SJ641 2 F G in housing without operator panel 1 2 17 4 lb or 8 kg 7SJ645 F G in housing without operator panel 1 1 26 45 lb or 12 kg 7SJ647 F G for housing without operator panel 1 1 12 5 kg 7SJ640 D E in flush mounting housing 1 3 11 02 lb or 5 kg 7SJ641 2...

Page 479: ...A 0 05 A to 35 00 A or disabled Increments 0 01 A for INom 5 A 0 25 A to 175 00 A or disabled Delay times T 0 00 s to 60 00 s or disabled Increments 0 01 s Dropout delay times 50 T DROP OUT 50N T DROP OUT 0 00 s to 60 00 s Increments 0 01 s Pickup times without inrush restraint with restraint add 10 ms First harmonic rms value for 2 x setting value for 10 x setting value Instantaneous value for 2 ...

Page 480: ... INom 1 A or 50 mA at INom 5 A Delay times T 1 or 10 ms Power supply direct voltage in range 0 8 VPS VPSNom 1 15 1 Temperature in range 23 00 F 5 C Θamb 131 00 F 55 C 0 5 10 K Frequency in range 0 95 f fNom 1 05 1 Harmonics up to 10 3rd harmonic up to 10 5th harmonic 1 1 Transient overreaction during fundamental harmonic measuring procedure for τ 100 ms with full displacement 5 w w w E l e c t r i...

Page 481: ...p current 51N ground for INom 1 A 0 05 A to 4 00 A Increments 0 01 A for INom 5 A 0 25 A to 20 00 A Time multiplier T for 51 51N for IEC curves 0 05 s to 3 20 s or disabled Increments 0 01 s Time multiplier T for 51 51N for ANSI curves 0 50 s to 15 00 s or disabled Increments 0 01 s Undervoltage threshold 51V V for release of 51 10 0 V to 125 0 V Increments 0 1V Acc to IEC 60255 3 or BS 142 Sectio...

Page 482: ...r Ip IN 0 3 this corresponds to approx 0 95 pickup value IEC with Disk Emulation approx 0 90 set value Ip Pickup dropout thresholds Ip IEp 2 of setting value or 10 mA for IN 1 A or 50 mA for IN 5 A Pickup time for 2 I Ip 20 5 of reference calculated value 2 current tolerance respective ly 30 ms Dropout time for I Ip 0 90 5 of reference calculated value 2 current tolerance respective ly 30 ms Power...

Page 483: ...ent Protection 51 N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 483 Figure 4 1 Dropout time and trip time curves of the inverse time overcurrent protection acc to IEC w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 484: ...ent Protection 51 N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 484 Figure 4 2 Dropout time and trip time curves of the inverse time overcurrent protection acc to IEC w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 485: ... acc to ANSI Acc to ANSI IEEE see also Figures 4 3 to 4 6 The tripping times for I Ip 20 are identical with those for I Ip 20 For zero sequence current read 3I0p instead of Ip and T3I0p instead of Tp for ground fault read IEp instead of Ip and TIEp instead of Tp Pickup Threshold approx 1 10 Ip w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 486: ...E see also Figures 4 3 to 4 6 The dropout time curves apply to I Ip 0 90 For zero sequence current read 3I0p instead of Ip and T3I0p instead of Tp for ground fault read IEp instead of Ip and TIEp instead of Tp IEC without Disk Emulation approx 1 05 setting value Ip for Ip IN 0 3 this corresponds to approx 0 95 pickup value ANSI with Disk Emulation approx 0 90 set value Ip w w w E l e c t r i c a l...

Page 487: ...eference calculated value 2 current tolerance respective ly 30 ms Dropout time for I Ip 0 90 5 of reference setpoint value 2 or 30 ms Power supply direct voltage in range 0 8 VPS VPSNom 1 15 1 Temperature in range 23 00 F 5 C Θamb 131 00 F 55 C 0 5 10 K Frequency in range 0 95 f fNom 1 05 1 Harmonics up to 10 3rd harmonic up to 10 5th harmonic 1 1 Transient overreaction during fundamental harmonic...

Page 488: ... Protection 51 N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 488 Figure 4 3 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 489: ... Protection 51 N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 489 Figure 4 4 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 490: ... Protection 51 N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 490 Figure 4 5 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 491: ... Protection 51 N SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 491 Figure 4 6 Dropout time and trip time curve of the inverse time overcurrent protection acc to ANSI IEEE w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 492: ...ase faults dynamically unlimited steady state approx 7V phase to phase Polarization with zero sequence quantities 3V0 3I0 Forward Range Vref rot 86 Rotation of the reference voltage Vref rot 180 to 180 Increments 1 Dropout difference 2 Directional Sensitivity VN 2 5 V displacement voltage measured 3V0 5 V displacement voltage calculated Polarization with negative sequence quantities 3V2 3I2 Forwar...

Page 493: ...SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 493 Tolerances Influencing Variables Angle faults for phase and ground faults 3 electrical Frequency Influence With no memory voltage approx 1 in range 0 95 f fNom 1 05 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 494: ...s 1 Lower Function Limit Phases for INom 1 A at least one phase current 50 Hz and 100 Hz 25 mA for INom 5 A at least one phase current 50 Hz and 100 Hz 125 mA Lower Function Limit ground for INom 1 A Ground current 50 Hz and 100 Hz 25 mA for INom 5 A Ground current 50 Hz and 100 Hz 125 mA Upper Function Limit configurable for INom 1 A 0 30 A to 25 00 A increments 0 01 A for INom 5 A 1 50 A to 125 ...

Page 495: ...l Current threshold BkrClosed I MIN reset on current falling below threshold monitoring with timer Current Control BkrClosed I MIN for INom 1 A 0 04 A to 1 00 A Increments 0 01 A for INom 5 A 0 20 A to 5 00 A Time Until Changeover To Dynamic Settings TCB OPEN 0 s to 21600 s 6 h Increments 1 s Period Dynamic Settings are Effective After a Reclosure TActive 1 s to 21600 s 6 h Increments 1 s Fast Res...

Page 496: ...p Increments 0 01 s The set times are pure delay times 1 Secondary values for INom 1 A with INom 5 A multiply currents by 5 2 Secondary values for sensitive measuring input independent of nominal device current Pickup Dropout Times Frequency Pickup Time 50 Hz 60 Hz minimum 14 ms 13 ms maximum 35 ms 35 ms Dropout time approx 25 ms 22 ms Current Elements approx 0 95 for I INom 0 5 Currents 3 of sett...

Page 497: ... for INom 1 A 0 04 A to 1 00 A Increment 0 01 A for INom 5 A 0 20 A to 5 00 A Overvoltages 59 1 59 2 Measured quantity used with three phase connection Positive sequence system of voltages Negative sequence system of the voltages Largest phase to phase voltage Largest phase to ground voltage Measured quantity used with single phase connection Connected single phase phase to ground voltage or phase...

Page 498: ...voltage 59 1 59 2 Overvoltage 59 1 V1 59 2 V1 59 1 V2 59 2 V2 Approx 50 ms Approx 50 ms Approx 60 ms Pickup Voltage Limits 3 of setting value or 1 V Delay times T 1 of setting value or 10 ms Power supply direct voltage in range 0 8 VPS VPSNom 1 15 1 Temperature in range 23 00 F 5 C Θamb 131 00 F 55 C 0 5 10 K Frequency in range 0 95 f fNom 1 05 1 Frequency outside range fNom 5 Hz Increased toleran...

Page 499: ...Dropout Delay Times 46 T DROP OUT 0 00 s to 60 00 s Increments 0 01 s Functional Limit for INom 1 A all phase currents 10 A for INom 5 A all phase currents 50 A Pickup Times Dropout Times Approx 35 ms Approx 35 ms Characteristic 46 1 46 2 Approx 0 95 for I2 INom 0 3 Pickup values 46 1 46 2 3 of set value or 10 mA for INom 1 A or 50 mA for INom 5 A Time Delays 1 or 10 ms Power supply direct voltage...

Page 500: ... 0 10 A to 2 00 A Increments0 01 A for INom 5 A 0 50 A to 10 00 A Time Multiplier TI2p IEC 0 05 s to 3 20 s or disabled Increments 0 01 s Time Multiplier DI2p ANSI 0 50 s to 15 00 s or disabled Increments 0 01 s Functional Limit for INom 1 A all phase currents 10 A for INom 5 A all phase currents 50 A See also Figure 4 7 The trip times for I2 I2p 20 are identical to those for I2 I2p 20 Pickup Thre...

Page 501: ...me characteristic curves in the figures 4 8 and 4 9 each on the right side of the figure The trip times for I2 I2p 20 are identical to those for I2 I2p 20 Pickup Threshold Approx 1 10 I2p Pickup Threshold I2p 3 of setting value or 10 mA for INom 1 A or 50 mA with INom 5 A Time for 2 I I2p 20 5 of reference calculated value 2 current tolerance respectively 30 ms w w w E l e c t r i c a l P a r t M ...

Page 502: ...ation Approx 1 05 I2p setting value which is approx 0 95 pickup thresholdI2 ANSI with Disk Emulation Approx 0 90 I2p setting value Pickup threshold I2p Time for I2 I2p 0 90 2 of set value or 10 mA for INom 1 A or 50 mA for INom 5 A 5 of reference calculated value 2 current tolerance respectively 30 ms Power supply direct voltage in range 0 8 VPS VPSNom 1 15 1 Temperature in range 23 00 F 5 C Θamb ...

Page 503: ...rotection 46 TOC SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 503 Figure 4 7 Trip time characteristics of the inverse time negative sequence element 46 TOC acc to IEC w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 504: ...ction 46 TOC SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 504 Figure 4 8 Dropout time and trip time characteristics of the inverse time unbalanced load stage acc to ANSI w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 505: ...ction 46 TOC SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 505 Figure 4 9 Dropout time and trip time characteristics of the inverse time unbalanced load stage acc to ANSI w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 506: ...TUP 1 0 s to 180 0 s Increments 0 1 s Permissible locked rotor time TLOCKED ROTOR 0 5 s to 120 0 s or disabled Increments 0 1 s Maximum startup time with warm motor TMax STARTUP W 0 5 s to 180 0 s or disabled Increments 0 1 s Maximum startup time with cold motor TMax STAR TUP C 0 to 80 or disabled Increments 1 Dropout ratio Approx 0 95 Pickup Threshold 2 of set value or 10 mA for INom 1 A or 50 mA...

Page 507: ...n Increments 0 1 min Maximum permissible number of warm startups nWARM 1 to 4 Increment 1 Difference between cold and warm startups nCOLD nWARM 1 to 2 Increment 1 Extension of Time Constant at stop kτ at STOP 0 2 to 100 0 Increment 0 1 Extension of Time constant at running kτ at RUNNING 0 2 to 100 0 Increment 0 1 Where ΘRESTART Temperature limit below which restarting is possible kR k factor for t...

Page 508: ...s 0 01 s Message delay 0 00 s to 600 00 s Increments 0 01 s Blocking duration after motor start 0 00 s to 600 00 s Increments 0 01 s Pickup time approx 55 ms Dropout time approx 30 ms Dropout ratio tripping stage approx 0 95 Dropout ratio warning stage approx 0 95 Pickup threshold for INom 1 A 2 of setting value or 10 mA for INom 5 A 2 of setting value or 50 mA Time delay 1 or 10 ms Power supply d...

Page 509: ... T 0 00 s to 100 00 s or disabled Increments 0 01 s Undervoltage blocking with three phase connection Positive sequence componentV1 with single phase connection single phase phase to ground or phase to phase voltage 10 V to 150 V Increments 1V Pickup times 81O 81U Approx 80 ms Dropout times 81O 81U Approx 75 ms Dropout Ratio for Undervoltage Blocking approx 1 05 Pickup Frequencies 81 O or 81U Unde...

Page 510: ... Extension kτ Factor when Machine Stopped 1 0 to 10 0 relative to the time constant for the machine running Increments 0 1 Emergency Time TEmergency 10 s to 15000 s Increments 1 s Nominal Overtemperature for INom 40 C to 200 C 13 F to 185 F Increments 1 C Θ ΘTrip Θ ΘAlarm I IAlarm Drops out with ΘAlarm Approx 0 99 Approx 0 97 Referring to k INom Referring to Trip Time 2 or 10 mA for INom 1 A or 50...

Page 511: ...Thermal Overload Protection 49 SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 511 Figure 4 10 Trip time curves for the thermal overload protection 49 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 512: ... 10 ms Measuring Principle Voltage measurement phase ground VPHASE MIN Ground Fault Phase 10 V to 100 V Increments 1V VPHASE MAX Healthy Phase 10 V to 100 V Increments 1V Measurement Tolerance acc to VDE 0435 Part 303 3 of setting value or 1 V Pickup current 50Ns 2 PICKUP for sensitive transformer for normal 1 A transformer for normal 5 A transformer 0 001 A to 1 500 A 0 05 A to 35 00 A 0 25 A to ...

Page 513: ...rements 0 05 A Starting current factor 51Ns Startpoint 1 0 to 4 0 Increments 0 1 Time factor 51Ns TIME DIAL 0 05 s to 15 00 s Increments 0 01 s Maximum time 51Ns Tmax 0 00 s to 30 00 s Increments 0 01 s Minimum time 51Ns Tmin 0 00 s to 30 00 s Increments 0 01 s Characteristics see Figure 2 89 Tolerances Times inv 5 15 ms for 2 I I51Ns 20 and 51Ns TIME DIAL 1 s def 1 of setting value or 10 ms Picku...

Page 514: ...rectional limit line for sensitive transformer for normal 1 A transformer for normal 5 A transformer 0 001 A to 1 200 A 0 05 A to 30 00 A 0 25 A to 150 00 A Increment 0 001 A Increment 0 01 A Increment 0 05 A Dropout ratio approx 0 80 Measuring method cos ϕ and sin ϕ Directional limit line PHI CORRECTION 45 0 to 45 0 Increments 0 1 Dropout delay RESET DELAY 1 s to 60 s Increments 1 s Direction det...

Page 515: ... cable converter in two operating points F1 I1 and F2 I2 Angle correction F1 F2 for grounded system 0 0 to 5 0 Increments 0 1 Current value I1 I2 for the angle correction for sensitive transformer for normal 1 A transformer for normal 5 A transformer 0 001 A to 1 600 A 0 05 A to 35 00 A 0 25 A to 175 00 A Increments 0 001 A Increments 0 01 A Increments 0 05 A Measurement Tolerance 2 of setting val...

Page 516: ...2 Release date 01 2008 516 Logarithmic Inverse Trip Time characteristic with knee point Figure 4 12 Trip time characteristics of the inverse time ground fault protection 51Ns with logarithmic inverse characteristic with knee point example for 51Ns 0 004 A w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 517: ... Tv 0 00 s to 10 00 s Increments 0 01 s Ground Fault Accumulation Time Tsum 0 00 s to 100 00 s Increments 0 01 s Reset Time for Accumulation Tres 1 s to 600 s Increments 1 s Number of Pickups for Intermittent Ground Fault 2 to 10 Increments 1 Pickup Times Current 1 25 x Pickup Value for 2 Pickup Value Dropout Time without extension time Approx 30 ms Approx 22 ms Approx 22 ms Pickup threshold I Tim...

Page 518: ...n for Manual CLOSE Detection TBlk Manual Close 0 50 s to 320 00 s or Increments 0 01 s Blocking Duration after Manual Close TBlocking Time 0 50 s to 320 00 s Increments 0 01 s Blocking Duration after Dynamic Blocking TBlk Dyn 0 01 s to 320 00 s Increments 0 01 s Start Signal Monitoring Time TStart Monitor 0 01 s to 320 00 s or Increments 0 01 s Circuit Breaker Monitoring Time TCB Monitor 0 10 s to...

Page 519: ...a binary input Reactance Setting secondary for INom 1 A 0 0050 to 9 5000 Ω km Increments 0 0001 0 0050 to 15 0000 Ω mile Increments 0 0001 for INom 5 A 0 0010 to 1 9000 Ω km Increments 0 0001 0 0010 to 3 0000 Ω mile Increments 0 0001 For the remaining parameters refer to the Power System Data 2 When configuring mixed lines the reactance value must be set for each line section A1 to A3 Measurement ...

Page 520: ... for INom 1 A 0 05 A to 20 00 A Increment 0 01 A for INom 5 A 0 25 A to 100 00 A Increment 0 01 A Delay time 50 BF trip timer 0 06 s to 60 00 s or Increments 0 01 s Pickup Times On Internal Start For external Start Dropout Time included in time delay included in time delay Approx 25 ms 1 Pickup thresholds 50 1 BF 50N 1 BF 2 of setting value or 10 mA for INom 1 A or 50 mA for INom 5 A Time Delay TR...

Page 521: ...V Increments 0 1V Displacement voltage VN 2 0 to 200 0 V Increments 0 1V Power P Q for INom 1 A 0 5 to 10000 W Increment 0 1 W for INom 5 A 2 5 to 50000 W Power factor cosϕ 0 99 to 0 99 Increment 0 01 Frequency for fNom 50 Hz für fNom 60 Hz 40 0 to 60 0 Hz 50 0 to 70 0 Hz Increments 0 01 Hz Increments 0 01 Hz Frequency change df dt 0 10 to 20 00 Hz s Increments 0 01 Hz s Dropout ratio element 1 01...

Page 522: ...pout times Current voltage phase quantities 20 ms Current voltage symmetrical components 30 ms Power typical maximum 50 ms 350 ms Power factor 300 ms Frequency 100 ms Frequency change 200 ms Binary input 10 ms Pickup tresholds Current for INom 1 A 1 of setting value or 10 mA for INom 5 A 1 of setting value or 50 mA Current symmetrical components for INom 1 A 2 of setting value or 20 mA for INom 5 ...

Page 523: ... 2008 523 Influencing Variables for Pickup Values Power supply direct voltage in range 0 8 VPS VPSNom 1 15 1 Temperature in range 23 00 F 5 C Θamb 131 00 F 55 C 0 5 10 K Frequency in range fNom 5 Hz 1 Harmonics up to 10 3rd harmonic up to 10 5th harmonic 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 524: ...hase Increments 1 V Increments 1 V Primary transformer rated voltage V2N 0 10 kV to 800 00 kV Increments 0 01 kV Tolerances 2 of pickup value or 2 V Dropout Ratios approx 0 9 V or 1 1 V Voltages differences V2 V1 V2 V1 Tolerance 0 5 V to 50 0 V phase to phase 1 V Increments 0 1 V Frequency Difference f2 f1 f2 f1 Tolerance for 7SJ64 Tolerance for 7SJ62 0 01 Hz to 2 00 Hz 15 mHz 20 mHz Increments 0 ...

Page 525: ...V1 Range Tolerance 1 in kV primary in V secondary or in of VNom 10 to 120 of VNom 1 of measured value or 0 5 of VNom Voltage to be synchronized V2 Range Tolerance 1 in kV primary in V secondary or in of VNom 10 to 120 of VNom 1 of measured value or 0 5 of VNom Frequency of voltage V1 Range Tolerance 1 f1 in Hz fNom 5 Hz 20 mHz Frequency of voltage V2 Range Tolerance 1 f2 in Hz fNom 5 Hz 20 mHz Vol...

Page 526: ... Mounting identification Oil or Ambient or Stator or Bearing or Other Number of measuring points Maximal of 12 temperature measuring points Temperature Unit C or F adjustable Measuring Range for Pt 100 for Ni 100 for Ni 120 199 C to 800 C 326 F to 1472 F 54 C to 278 C 65 F to 532 F 52 C to 263 C 62 F to 505 F Resolution 1 C or 1 F Tolerance 0 5 of measured value 1 digit for each measuring point St...

Page 527: ...ed X X X X CMD_CHAIN Switching Sequence X X CMD_INF Command Information X COMPARE Metered value compar ison X X X X CONNECT Connection X X X COUNTER Counter X X X X DI_GET_STATUS Decode double point indication X X X X DI_SET_STATUS Generate double point indication with status X X X X D_FF D Flipflop X X X D_FF_MEMO Status Memory for Restart X X X X DI_TO_BOOL Double Point to Boolean conversion X X...

Page 528: ...NT Upper Limit X X_OR XOR Gate X X X X ZERO_POINT Zero Supression X Function Module Explanation Task Level MW_ BEARB PLC1_ BEARB PLC_ BEARB SFS_ BEARB Description Limit Comments Maximum number of all CFC charts considering all task levels 32 When the limit is exceeded the device rejects the parameter set displaying an error message restores the last valid pa rameter set and uses it for restarting ...

Page 529: ...locks will not then start with the starting pulse Maximum Number of TICKS in the Task Levels 1 When the sum of TICKS of all blocks exceeds the limits before mentioned an error message is output by CFC Description Limit Comments Maximum number of synchronous changes of chart inputs per task level 165 When the limit is exceeded an error message is output by the device Consequently the device starts ...

Page 530: ...signal 7 Additional for each chart 1 Arithmetic ABS_VALUE 5 ADD 26 SUB 26 MUL 26 DIV 54 SQUARE_ROOT 83 Basic logic AND 5 CONNECT 4 DYN_OR 6 NAND 5 NEG 4 NOR 5 OR 5 RISE_DETECT 4 X_OR 5 Information status SI_GET_STATUS 5 CV_GET_STATUS 5 DI_GET_STATUS 5 MV_GET_STATUS 5 SI_SET_STATUS 5 DI_SET_STATUS 5 MV_SET_STATUS 5 ST_AND 5 ST_OR 5 ST_NOT 5 Memory D_FF 5 D_FF_MEMO 6 RS_FF 4 RS_FF_MEMO 4 SR_FF 4 SR_...

Page 531: ... 5 REAL_TO_DINT 10 REAL_TO_UINT 10 Comparison COMPARE 12 LOWER_SETPOINT 5 UPPER_SETPOINT 5 LIVE_ZERO 5 ZERO_POINT 5 Metered value COUNTER 6 Time and clock pulse TIMER 5 TIMER_LONG 5 TIMER_SHORT 8 ALARM 21 FLASH 11 Individual Element Number of TICKS In addition to the defined preassignments indications and measured values can be freely configured to buff ers preconfigurations can be removed w w w E...

Page 532: ...SNom for V VNom and I INom 50 to 120 P Active power with sign total and phase segregated in kW MW or GW primary and in SNom Range tolerance1 0 to 120 SNom 1 of SNom for V VNom and I INom 50 to 120 and cos ϕ 0 707 to 1 with SNom 3 VNom INom Q reactive power with sign total and phase segregated in kVAr MVAr or GVAr primary and in SNom Range tolerance1 0 to 120 SNom 1 of SNom for V VNom and I INom 50...

Page 533: ... of Currents of Real Power of Reactive Power of Apparent Power IAdmd IBdmd ICdmd I1dmd in A kA Pdmd in W kW MW Qdmd in VAr kVAr MVAr Sdmd in VAr kVAr MVAr Storage of Measured Values with date and time Reset automatic Time of day adjustable in minutes 0 to 1439 min Time frame and starting time adjustable in days 1 to 365 days and Manual Reset Using binary input Using keypad Via communication Min Ma...

Page 534: ...e IAdmd IB limit value IBdmd IC limit value ICdmd I1 limit value I1dmd IL limit value IL cos ϕ lower limit cos ϕ P limit value of active power Pdmd Q limit value of reactive powe Qdmd S limit value of apparent power Sdmd Druck lower pressure limit Temperature Temperature limit Recording of indications of the last 8 power system faults Recording of indications of the last 3 power system ground faul...

Page 535: ... according to pole Up to 4 digits Total number of motor startups 0 to 9999 Resolution1 Total operating time 0 to 99999 h Resolution1 h Total down time 0 to 99999 h Resolution1 h Ratio operating time down time 0 to 100 Resolution 0 1 Active energy and reactive energy see Operational Measured Values Motor start up data Start up time Start up current primary Start up voltage primary of the last 5 sta...

Page 536: ...on using DCF 77 6 Time signal Sync Box External synchronization via the time signal SIMEAS Synch Box 7 Pulse via binary input External synchronization with pulse via binary input 8 Field bus DNP Modbus External synchronization using field bus 9 NTP IEC 61850 External synchronization using system in terface IEC 61850 Number of Available Setting Groups 4 parameter group A B C and D Switchover Perfor...

Page 537: ...g Messages Feedback messages closed open intermediate position Control Commands Single command double command Switching Command to Circuit Breaker 1 1 and 2 pole Programmable Logic Controller PLC logic graphic input tool Local Control Control via menu control assignment of function keys Remote Control Using Communication Interfaces Using a substation automation and control system e g SICAM Using D...

Page 538: ...140 C207 2 Release date 01 2008 538 4 27 Dimensions 4 27 1 Panel Fush and Cubicle Mounting Housing Size 1 3 Figure 4 13 Dimensional drawing of a 7SJ62 or 7SJ64 for panel flush and cubicle mounting housing size 1 3 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 539: ...al C53000 G1140 C207 2 Release date 01 2008 539 4 27 2 Panel Flush and Cubicle Mounting Housing Size 1 2 Figure 4 14 Dimensional drawing of a 7SJ64 for panel flush and cubicle mounting housing size 1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 540: ...al C53000 G1140 C207 2 Release date 01 2008 540 4 27 3 Panel Flush and Cubicle Mounting Housing Size 1 1 Figure 4 15 Dimensional drawing of a 7SJ64 for panel flush and cubicle mounting housing size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 541: ... Surface Mounting Housing Size 1 3 Figure 4 16 Dimensional drawing of a 7SJ62 or 7SJ64 for panel flush mounting housing size 1 3 4 27 5 Panel Surface Mounting Housing Size 1 2 Figure 4 17 Dimensional drawing of a 7SJ64 for panel flush mounting housing size 1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 542: ...J62 64 Manual C53000 G1140 C207 2 Release date 01 2008 542 4 27 6 Panel Surface Mounting Housing Size 1 1 Figure 4 18 Dimensional drawing of a 7SJ64 for panel flush mounting housing size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 543: ... date 01 2008 543 4 27 7 Housing for Mounting with Detached Operator Panel or without Operator Panel Housing Size 1 2 Figure 4 19 Dimensions 7SJ64 for mounting with detached operator panel or without operator panel housing size 1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 544: ... date 01 2008 544 4 27 8 Housing for Mounting with Detached Operator Panel or without Operator Panel Housing Size 1 1 Figure 4 20 Dimensions 7SJ64 for mounting with detached operator panel or without operator panel housing size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 545: ...ons SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 545 4 27 9 Detached Operator Panel Figure 4 21 Dimensions of a detached operator panel for a 7SJ64 device w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 546: ...or Cubicle Door Cutout Figure 4 22 Dimensions of panel flush or cubicle door cutout of D SUB miniature connector of dongle cable for a 7SJ64 device without integrated operator panel 4 27 11 Varistor Figure 4 23 Dimensional drawing of the varistor for voltage limiting in high impedance differential protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 547: ... of the devices to primary equipment in many typical power system configurations Tables with all settings and all information available in this device equipped with all options are provided Default settings are also given A 1 Ordering Information and Accessories 548 A 2 Terminal Assignments 561 A 3 Connection Examples 598 A 4 Current Transformer Requirements 612 A 5 Default Settings 615 A 6 Protoc...

Page 548: ...shold Setting Pos 8 24 to 48 VDC Binary Input Threshold 19 VDC 2 60 to 125 VDC Binary Input Threshold 19 VDC 4 110 to 250 VDC 115 to 230 VAC Binary Input Threshold 88 VDC 5 110 to 250 VDC 115 to 230 VAC Binary Input Threshold 176 VDC 6 Construction Pos 9 Surface mounting case for panel 2 tier terminals top bottom B Flush mounting case with plug in terminals 2 3 pin connector D Flush mounting case ...

Page 549: ...her interface options see Additional Information in the following 9 System Interface Rear Side Port B Pos 11 Additional information to further system interfaces device rear port B Supple mentary Profibus DP Slave RS485 L 0 A Profibus DP Slave 820 nm optical Double Ring ST Connector 1 L 0 B 1 Modbus RS485 L 0 D Modbus 820 nm optical ST Connector 2 L 0 E 2 DNP3 0 RS485 L 0 G DNP3 0 820 nm optical ST...

Page 550: ...ters from current and voltage Voltage power power factor frequency change protection F E IEF V f P 27 59 81O U 27 47 59 N 32 55 81R Under Overvoltage 59 1 59 2 27 1 27 2 Under Overfrequency Intermittent ground fault Flexible protection functions parameters from current and voltage Voltage power power factor frequency change protection P E Dir 67 67N Directional overcurrent protection F C Dir V f P...

Page 551: ...tection in motors motor statistics Under Overvoltage 59 1 59 2 27 1 27 2 Under Overfrequency Flexible protection functions parameters from current and voltage Voltage power power factor frequency change protection H H 1 DGFD Motor Dir IEF V f P 67 67N 67Ns 87N 48 14 66 86 51M 27 59 81O U 27 47 59 N 32 55 81R Directional overcurrent protection Directional sensitive ground fault detection High imped...

Page 552: ...g 79 Fault Locator Pos 16 No 79 no fault locator 0 79 With 79 1 21FL With fault locator 2 79 21FL With 79 and fault locator 3 25 with synchronization check1 41 25 79 21FL with synchronization check with auto reclose system with fault locator1 71 Special model Supplementary with ATEX 100 approval for the protection of explosion protected motors of protection type increased safety e Z X 9 9 w w w E ...

Page 553: ...o 48 VDC Binary Input Threshold 19 VDC 2 60 to 125 VDC Binary Input Threshold 19 VDC 4 110 to 250 VDC 115 to 230 VAC 1 Binary Input Threshold 88 VDC 5 Construction Pos 9 Surface mounting case plug in terminals detached operator panel Installation in a low voltage compartment A Surface mounting case for panel 2 tier terminals top bottom B Surface mounting case screw type terminals direct connection...

Page 554: ... Connector 1 5 1 Profibus FMS Slave optical Double Ring ST Connector 1 6 1 For further interface options see Additional Information in the following L 9 Additional information L to further system interfaces device rear port B Supple mentary Profibus DP Slave RS485 L 0 A Profibus DP Slave 820 nm optical double ring ST connector 1 L 0 B 1 Modbus RS 485 L 0 D Modbus 820 nm optical ST connector 2 L 0 ...

Page 555: ...via the insensitive DGFD function 50Ns 1 50Ns 2 51Ns 50 50N Flexible protection functions parameters from current additive overcurrent time protection 50 4 51V Voltage controlled time overcurrent protection 49 Overload protection with 2 time constants 46 Negative sequence protection 37 Undercurrent monitoring 47 Phase rotation 64 59N Displacement voltage 50BF Circuit breaker failure protection 74T...

Page 556: ... impedance ground fault differential protection Intermittent ground fault P D 1 DGFD 67Ns 87N Directional sensitive ground fault detection High impedance ground fault differential protection F B 1 DGFD Motor V f P 67Ns 87N 48 14 66 86 51M 27 59 81O U 27 47 59 N 32 55 81R Directional sensitive ground fault detection High impedance ground fault differential protection Motor starting protection locke...

Page 557: ...ional overcurrent protection Motor starting protection locked rotor Restart inhibit for motors Load jam protection in motors motor statistics Under Overvoltage 59 1 59 2 27 1 27 2 Under Overfrequency Flexible protection functions parameters from current and voltage Voltage power power factor frequency change protection H G Motor 48 14 66 86 51M Motor starting protection locked rotor Reclosing lock...

Page 558: ...5 C53207 A351 D631 1 DNP 3 0 820 nm C53207 A351 D633 1 Ethernet electrical EN 100 C53207 A351 D675 2 Ethernet optical EN 100 C53207 A351 D676 1 IEC 60870 5 103 Protocol redundant RS485 C53207 A351 D644 1 RTD Box Resistance Temperature Detector Name Order No RTD box Vaux 24 to 60 V AC DC 7XV5662 2AD10 0000 RTD box Vaux 90 to 240 V AC DC 7XV5662 5AD10 0000 RS485 Fibre Optic Converter RS485 Fibre Opt...

Page 559: ... Angle Strip Mounting Rail C73165 A63 C200 4 Battery Lithium battery 3 V 1 Ah type CR 1 2 AA Order No VARTA 6127 101 501 Interface Cable Interface cable between PC or SIPROTEC device Order No Cable with 9 pin male female connections 7XV5100 4 Varistor Voltage limiting resistor for high impedance differential protection Name Order number 125 Veff 600 A 1S S256 C53207 A401 D76 1 240 Veff 600 A 1S S1...

Page 560: ...ctor 8 pole 7XV5103 2BA00 IEC 60870 5 103 redundant RS485 adapter cable Name Order Number Y adapter cable for devices with redundant IEC 608070 5 103 RS485 interface and RJ45 connector on 2x RJ45 sub miniature connector for a RS485 bus setup with patch cables 2 core twisted shielded length 0 3 m 1x RJ45 pin 8 pole on 2x RJ45 sub miniature connector 8 pole 7XV5103 2CA00 RS485 Bus connector for RJ45...

Page 561: ...C207 2 Release date 01 2008 561 A 2 Terminal Assignments A 2 1 7SJ62 Housing for panel flush mounting or cubicle installation 7SJ621 D E Figure A 1 General diagram for 7SJ621 D E panel flush mounting or cubicle mounting w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 562: ...J622 D E Figure A 2 General diagram for 7SJ622 D E panel flush mounted or cubicle mounted Double commands cannot be directly allocated to BO5 BO7 If these outputs are used for issuing a double command it has to be divided into two single commands via CFC w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 563: ...Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 563 7SJ623 D E Figure A 3 General diagram 7SJ623 D E panel flush mounted or cubicle mounted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 564: ...7SJ624 D E Figure A 4 General diagram 7SJ624 D E panel flush mounted or cubicle mounted Double commands cannot be directly allocated to BO5 BO7 If these outputs are used for issuing a double command it has to be divided into two single commands via CFC w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 565: ...ROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 565 A 2 2 7SJ62 Housing for Panel Surface Mounting 7SJ621 B Figure A 5 General diagram for 7SJ621 B panel surface mounted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 566: ...008 566 7SJ622 B Figure A 6 General diagram for 7SJ622 B panel surface mounted Double commands cannot be directly allocated to BO5 BO7 If these outputs are used for issuing a double command it has to be divided into two single commands via CFC w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 567: ...Terminal Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 567 7SJ623 B Figure A 7 General diagram for 7SJ623 B panel surface mounted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 568: ...008 568 7SJ624 B Figure A 8 General diagram for 7SJ624 B panel surface mounted Double commands cannot be directly allocated to BO5 BO7 If these outputs are used for issuing a double command it has to be divided into two single commands via CFC w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 569: ...140 C207 2 Release date 01 2008 569 A 2 3 7SJ62 Interface assignment on housing for panel surface mounting 7SJ621 2 B up to release CC Figure A 9 General diagram for 7SJ621 2 B up to release CC panel surface mounted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 570: ... 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 570 7SJ621 2 3 4 B release DD and higher Figure A 10 General diagram for 7SJ621 2 3 4 B release DD and higher panel surface mounted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 571: ...53000 G1140 C207 2 Release date 01 2008 571 A 2 4 7SJ64 Housing for Panel Flush Mounting or Cubicle Installation 7SJ640 D E Figure A 11 General diagram for 7SJ640 D E panel flush mounting or cubicle mounting w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 572: ...ignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 572 7SJ641 D E Figure A 12 General diagram for 7SJ641 D E panel flush mounting or cubicle mounting w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 573: ...ignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 573 7SJ642 D E Figure A 13 General diagram for 7SJ642 D E panel flush mounting or cubicle mounting w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 574: ...gnments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 574 7SJ645 D E Figure A 14 General diagram 7SJ645 D E panel flush mounted or cubicle mounted part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 575: ...gnments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 575 7SJ645 D E Figure A 15 General diagram 7SJ645 D E panel flush mounted or cubicle mounted part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 576: ...ents SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 576 7SJ647 D E Figure A 16 Connection diagram for 7SJ647 D E panel flush mounted or cubicle mounted part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 577: ...ents SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 577 7SJ647 D E Figure A 17 Connection diagram for 7SJ647 D E panel flush mounted or cubicle mounted part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 578: ...ROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 578 A 2 5 7SJ64 Housing for Panel Surface Mounting 7SJ640 B Figure A 18 General diagram for 7SJ640 B panel surface mounted w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 579: ...erminal Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 579 7SJ641 B Figure A 19 General diagram for 7SJ641 B panel surface mounting w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 580: ...erminal Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 580 7SJ642 B Figure A 20 General diagram for 7SJ642 B panel surface mounting w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 581: ...rminal Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 581 7SJ645 B Figure A 21 General diagram 7SJ645 B panel surface mounted part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 582: ...rminal Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 582 7SJ645 B Figure A 22 General diagram 7SJ645 B panel surface mounted part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 583: ...inal Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 583 7SJ647 B Figure A 23 General diagram for 7SJ647 B panel surface mounted part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 584: ...inal Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 584 7SJ647 B Figure A 24 General diagram for 7SJ647 B panel surface mounted part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 585: ...anual C53000 G1140 C207 2 Release date 01 2008 585 A 2 6 7SJ64 Housing with Detached Operator Panel 7SJ641 A C Figure A 25 General diagram 7SJ641 A C panel surface mounting with detached operator panel w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 586: ...ents SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 586 7SJ642 A C Figure A 26 General diagram 7SJ642 A C panel surface mounting with detached operator panel w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 587: ...s SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 587 7SJ645 A C Figure A 27 General diagram 7SJ645 A C panel surface mounting with detached operator panel part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 588: ...s SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 588 7SJ645 A C Figure A 28 General diagram 7SJ645 A C panel surface mounting with detached operator panel part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 589: ...s SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 589 7SJ647 A C Figure A 29 General diagram 7SJ647 A C panel surface mounting with detached operator panel part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 590: ...s SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 590 7SJ647 A C Figure A 30 General diagram 7SJ647 A C panel surface mounting with detached operator panel part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 591: ...1140 C207 2 Release date 01 2008 591 A 2 7 7SJ64 Housing for Panel Surface Mounting without Operator Panel 7SJ641 F G Figure A 31 General diagram 7SJ641 F G devices for panel surface mounting without operation unit w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 592: ...gnments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 592 7SJ642 F G Figure A 32 General diagram 7SJ642 F G panel surface mounting without operator panel w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 593: ...ents SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 593 7SJ645 F G Figure A 33 General diagram 7SJ645 F G panel surface mounting without operator panel part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 594: ...ents SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 594 7SJ645 F G Figure A 34 General diagram 7SJ645 F G panel surface mounting without operator panel part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 595: ...IPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 595 7SJ647 F G Figure A 35 General diagram 7SJ647 F G devices for panel surface mounting without operation unit part 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 596: ...IPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 596 7SJ647 F G Figure A 36 General diagram 7SJ647 F G devices for panel surface mounting without operation unit part 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 597: ...erminal Assignments SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 597 A 2 8 Connector Assignment On the Ports On the time Synchronization Port w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 598: ...for Current Transformers all Devices Figure A 37 Current connections to three current transformers with a starpoint connection for ground current residual 3I0 neutral current normal circuit layout Figure A 38 Current connections to two current transformers only for ungrounded or compensated networks w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 599: ...rent input IN INs When using a cable type current transformer the connection of k and l at Q8 and Q7 must be changed Figure A 40 Current connections to two current transformers ground current of additional toroidal transformer for sensitive ground fault detection Important Grounding of the cable shield must be effected at the cable s side For busbar side grounding of the current transformer the cu...

Page 600: ...the highly sensitive and sensitive ground input Important Grounding of the cable shield must be effected at the cable s side For busbar side grounding of the current transformer the current polarity of the device is changed via address 0201 This also reverses the polarity of current input INs When using a cable type current transformer the con nection of k and l at Q8 and Q7 must be changed w w w ...

Page 601: ... current of the transformer starpoint Important Grounding of the cable shield must be effected at the cable s side For busbar side grounding of the current transformer the current polarity of the device is changed via address 0201 This also reverses the polarity of current input IN INs When using a cable type current transformer the connection of k and l at Q8 and Q7 must be changed w w w E l e c ...

Page 602: ...rmers 7SJ621 7SJ622 Figure A 43 Voltage connections to three voltage transformers phase to ground voltages normal circuit layout appropriate for all networks Figure A 44 Voltage connections to two voltage transformers phase to phase voltages and open delta VT for V4 appropriate for all networks w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 603: ...ge transformer connections of two voltage transformers in V connection In this connection determination of zero sequence voltage V0 is not possible Functions using zero sequence voltage must be disabled Figure A 46 Voltage transformer connection only to open delta VT w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 604: ...mples SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 604 Figure A 47 Connection circuit for single phase voltage transformers with phase to ground voltages w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 605: ...nnected voltage transformers normal connection The terminal markings in brackets apply to the devices 7SJ623 7SJ624 the remaining to devices 7SJ64 Figure A 49 Voltage connections to three wye connected voltage transformers with additional open delta windings da dn The terminal markings in brackets apply to the devices 7SJ623 7SJ624 the remaining to devices 7SJ64 w w w E l e c t r i c a l P a r t M...

Page 606: ... 2008 606 Figure A 50 Voltage connections to three wye connected voltage transformers with additional open delta windings da dn of the busbar The terminal markings in brackets apply to the devices 7SJ623 7SJ624 the remaining to devices 7SJ64 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 607: ...minal markings in brackets apply to the devices 7SJ623 7SJ624 the remaining to devices 7SJ64 Figure A 52 Voltage transformer connections of two phase to phase voltages in V connection In this connection determination of zero sequence voltage V0 is not possible Functions using zero sequence voltage must be disabled The terminal markings in brackets apply to the devices 7SJ623 7SJ624 the remaining t...

Page 608: ...nd additionally to any phase to phase voltage for synchronism check for example In this connection determination of zero se quence voltage U0 is not possible Functions using zero sequence voltage must be disabled The terminal markings in brackets apply to the devices 7SJ623 7SJ624 the remaining to devices 7SJ64 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 609: ...2 Release date 01 2008 609 Figure A 54 Connection circuit for single phase voltage transformers with phase to phase voltages The terminal markings in brackets apply to the devices 7SJ623 7SJ624 the remaining to devices 7SJ64 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 610: ...the partial connection for the high impedance differential protection A 3 5 Connection Examples for RTD Box Figure A 56 Simplex operation with one RTD Box above optical design 1 FO below design with RS 485 1 for 7SJ64 port D 2 for 7SJ64 optionally port C or port D Figure A 57 Half duplex operation with one RTD Box above optical design 2 FOs below design with RS 485 1 for 7SJ64 port D 2 for 7SJ64 o...

Page 611: ...53000 G1140 C207 2 Release date 01 2008 611 Figure A 58 Half duplex operation with two RTD Boxes above optical design 2 FOs below design with RS 485 1 for 7SJ64 port D 2 for 7SJ64 optionally port C or port D w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 612: ...other transformer classes A 4 1 Accuracy limiting factors Effective and Rated Accuracy Limiting Factor Calculation example according to IEC 60044 1 Required minimum effective accuracy limiting factor but at least 20 with KALF Minimum effective accuracy limiting factor 50 2PU Primary pickup value of the high current element IpNom Primary nominal transformer current Resulting rated accuracy limiting...

Page 613: ...KSSC KALF Calculation See ChapterA 4 1 Accuracy limiting factors with KSSC n TP depending on power system and specified closing sequence with Vk Knee point voltage RCt Internal burden resistance RBN Nominal burden resistance IsNom secondary nominal transformer current KALF Rated accuracy limiting factor Vs t max sec terminal volt at 20 IpNom Val sec magnetization limit voltage K Dimensioning facto...

Page 614: ...ound fault currents it may become necessary to correct the angle at the device see func tion description of sensitive ground fault detection Transformation ratio typical It may be necessary to select a different transformation ratio to suit the specific power system and thus the amount of the maximum ground fault current 60 1 Accuracy limiting factor FS 10 Minimum power 1 2 VA Maximum connected lo...

Page 615: ...e B picked up LED4 50 51 Ph C PU 1764 50 51 Phase C picked up 67 C picked up 2694 67 67 TOC Phase C picked up LED5 50N 51NPickedup 1765 50N 51N picked up 67N picked up 2695 67N 67N TOC picked up LED6 Failure Σ I 162 Failure Current Summation Fail I balance 163 Failure Current Balance Fail V balance 167 Failure Voltage Balance Fail Ph Seq I 175 Failure Phase Sequence Current Fail Ph Seq V 176 Failu...

Page 616: ... 52Breaker 52 Breaker Binary Input Default function Function No Description BI6 Disc Swit Disconnect Switch BI7 Disc Swit Disconnect Switch BI8 GndSwit Ground Switch BI9 GndSwit Ground Switch BI11 CB ready CB ready Spring is charged BI12 DoorClose Door closed Binary Output Default function Function No Description BO1 Relay TRIP 511 Relay GENERAL TRIP command 52Breaker 52 Breaker BO2 52Breaker 52 B...

Page 617: ...ic display there is a default display indicating the actual operating state and or selected measured values The display size is selected during configuration Binary Output Default function Function No Description BO3 Relay TRIP 511 Relay GENERAL TRIP command 52Breaker 52 Breaker BO4 52Breaker 52 Breaker 79 Close 2851 79 Close command BO5 52Breaker 52 Breaker 79 Close 2851 79 Close command Binary O...

Page 618: ...7SJ62 for models without extended measured values 13th digit of MLFB 0 or 1 Page 7 and page 9 of the default display can only be used if for the current connection parameter 251 CT Connect one of the two special connection types A G2 C G G B or A G2 C G G2 B was selected see description of Power System Data 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 619: ...s with extended measured values 13th digit of MLFB 2 or 3 Page 8 and page 10 of the default display can only be used if for the current connection parameter 251CT Connect one of the two special connection types A G2 C G G B or A G2 C G G2 B were selected see description of Power System Data 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 620: ...Figure A 61 Default Display of 7SJ640 Page 8 and page 10 of the default display can only be used if for the current connection parameter 251CT Connect one of the two special connection types A G2 C G G B or A G2 C G G2 B were selected see description of Power System Data 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 621: ...rtant data about a fault They appear automatically in the display after general interrogation of the device in the sequence shown in the following figure Figure A 63 Display of spontaneous messages in the HMI Spontaneous Fault Indication of the Graphic Display All devices featuring a graphic display allow to select whether or not to view automatically the most important fault data on the display a...

Page 622: ...the input signal DataStop directly to an output This is not directly possible without the interconnection of this block Figure A 64 Logical links between input and output Setpoints MV Using modules on the running sequence measured value processing a low current monitor for the three phase currents is implemented The output message is set high as soon as one of the three phase currents falls below ...

Page 623: ...Release date 01 2008 623 Blocks of the task level MW_BEARB measured value processing are used to implement the overcurrent monitoring and the power monitoring Figure A 66 Overcurrent monitoring Figure A 67 Power monitoring w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 624: ...207 2 Release date 01 2008 624 Switchgear Interlocking for 7SJ64 Standard interlocking for three switching devices 52 Disc and GndSw Figure A 68 Standard interlocking for circuit breaker disconnector and ground switch w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 625: ... Yes User defined messag es and switching objects Yes Yes Yes Yes Yes Yes Yes Time Synchronization Yes Yes Yes Yes Yes Yes Messages with time stamp Yes Yes Yes Yes Yes Yes Yes Commissioning aids Measured value indica tion blocking Yes Yes Yes No Yes No Yes Creating test messag es Yes Yes Yes No Yes No Yes Physical mode Asynchro nous Asynchro nous Synchro nous Asynchro nous Asynchro nous Asynchrono...

Page 626: ...te Time 67 67 TOC 116 67N 67N TOC Disabled Definite Time TOC IEC TOC ANSI User Defined PU User def Reset Definite Time 67N 67N TOC 117 Coldload Pickup Disabled Enabled Disabled Cold Load Pickup 122 InrushRestraint Disabled Enabled Disabled 2nd Harmonic Inrush Restraint 127 50 1Ph Disabled Enabled Disabled 50 1Ph 130 S Gnd F Dir Ch cos ϕ sin ϕ V0 I0 ϕ mea cos ϕ sin ϕ sens Ground fault dir character...

Page 627: ...3 25 Function 3 Disabled ASYN SYNCHRON SYNCHROCHECK Disabled 25 Function group 3 164 25 Function 4 Disabled ASYN SYNCHRON SYNCHROCHECK Disabled 25 Function group 4 170 50BF Disabled Enabled enabled w 3I0 Disabled 50BF Breaker Failure Protection 171 79 Auto Recl Disabled Enabled Disabled 79 Auto Reclose Function 172 52 B WEAR MONIT Disabled Ix Method 2P Method I2t Method Disabled 52 Breaker Wear Mo...

Page 628: ...ion 02 Flex Function 03 Flex Function 04 Flex Function 05 Flex Function 06 Flex Function 07 Flex Function 08 Flex Function 09 Flex Function 10 Flex Function 11 Flex Function 12 Flex Function 13 Flex Function 14 Flex Function 15 Flex Function 16 Flex Function 17 Flex Function 18 Flex Function 19 Flex Function 20 Please select Flexible Functions Addr Parameter Setting Options Default Setting Comment...

Page 629: ...od 0 PICKUP WITH Flx Exceeding Dropping below Exceeding Pickup with 0 CURRENT Flx Ia Ib Ic In In sensitive In2 Ia Current 0 VOLTAGE Flx Please select Va n Vb n Vc n Va b Vb c Vc a Vn Please select Voltage 0 POWER Flx Ia Va n Ib Vb n Ic Vc n Ia Va n Power 0 VOLTAGE SYSTEM Flx Phase Phase Phase Ground Phase Phase Voltage System 0 P U THRESHOLD Flx 1A 0 03 40 00 A 2 00 A Pickup Threshold 5A 0 15 200 ...

Page 630: ...nect 3ph P System Data 1 Van Vbn Vcn Vab Vbc VGnd Van Vbn Vcn VGn Van Vbn Vcn VSy Van Vbn Vcn VT Connection three phase 214 Rated Frequency P System Data 1 50 Hz 60 Hz 50 Hz Rated Frequency 215 Distance Unit P System Data 1 km Miles km Distance measurement unit 217 Ignd CT PRIM P System Data 1 1 50000 A 60 A Ignd CT rated primary current 218 Ignd CT SEC P System Data 1 1A 5A 1A Ignd CT rated secon...

Page 631: ...ystem Data 1 Vphph Vph n V1 V2 Vphph Opera Quantity for 59 Overvolt Prot 615A OP QUANTITY 27 P System Data 1 V1 Vphph Vph n V1 Opera Quantity for 27 Undervolt Prot 640 Start image DD Device General image 1 image 2 image 3 image 4 image 5 image 6 image 7 image 8 image 9 image 10 image 1 Start image Default Display 1101 FullScaleVolt P System Data 2 0 10 800 00 kV 12 00 kV Measurem FullScaleVolt age...

Page 632: ... Overcur Always with 79 active Always 50 3 active 1217 50 3 PICKUP 50 51 Overcur 1A 1 00 35 00 A A 50 3 Pickup 5A 5 00 175 00 A A 1218 50 3 DELAY 50 51 Overcur 0 00 60 00 sec 0 00 sec 50 3 Time Delay 1219A 50 3 measurem 50 51 Overcur Fundamental True RMS Instantaneous Fundamental 50 3 measurement of 1220A 50 2 measurem 50 51 Overcur Fundamental True RMS Fundamental 50 2 measurement of 1221A 50 1 m...

Page 633: ...2 measurement of 1321A 50N 1 measurem 50 51 Overcur Fundamental True RMS Fundamental 50N 1 measurement of 1322A 51N measurem 50 51 Overcur Fundamental True RMS Fundamental 51N measurement of 1330 50N 51N 50 51 Overcur 1 00 20 00 I Ip 0 01 999 00 TD 50N 51N 1331 MofPU Res T TEp 50 51 Overcur 0 05 0 95 I Ip 0 01 999 00 TD Multiple of Pickup T TEp 1501 FCT 67 67 TOC 67 Direct O C OFF ON OFF 67 67 TOC...

Page 634: ...e Delay 1607 67N TOC PICKUP 67 Direct O C 1A 0 05 4 00 A 0 20 A 67N TOC Pickup 5A 0 25 20 00 A 1 00 A 1608 67N TOC T DIAL 67 Direct O C 0 05 3 20 sec 0 20 sec 67N TOC Time Dial 1609 67N TOC T DIAL 67 Direct O C 0 50 15 00 5 00 67N TOC Time Dial 1610 67N TOC DropOut 67 Direct O C Instantaneous Disk Emulation Disk Emulation Drop Out Characteristic 1611 67N TOC IEC 67 Direct O C Normal Inverse Very I...

Page 635: ... 1 PICKUP ColdLoadPickup 1A 0 05 35 00 A 1 50 A 50Nc 1 Pickup 5A 0 25 175 00 A 7 50 A 1904 50Nc 1 DELAY ColdLoadPickup 0 00 60 00 sec 0 30 sec 50Nc 1 Time Delay 1905 51Nc PICKUP ColdLoadPickup 1A 0 05 4 00 A 1 00 A 51Nc Pickup 5A 0 25 20 00 A 5 00 A 1906 51Nc T DIAL ColdLoadPickup 0 05 3 20 sec 0 50 sec 51Nc Time Dial 1907 51Nc T DIAL ColdLoadPickup 0 50 15 00 5 00 51Nc Time Dial 1908 50Nc 3 PICKU...

Page 636: ...or 3104 CT Err I2 Sens Gnd Fault 1A 0 05 35 00 A 10 00 A Current I2 for CT Angle Error 5A 0 25 175 00 A 50 00 A 3105 CT Err F2 Sens Gnd Fault 0 0 5 0 0 0 CT Angle Error at I2 3106 VPH MIN Sens Gnd Fault 10 100 V 40 V L Gnd Voltage of Faulted Phase Vph Min 3107 VPH MAX Sens Gnd Fault 10 100 V 75 V L Gnd Voltage of Unfaulted Phase Vph Max 3108 64 1 VGND Sens Gnd Fault 1 8 200 0 V 40 0 V 64 1 Ground ...

Page 637: ...Delay 3141 51Ns Tmax Sens Gnd Fault 0 00 30 00 sec 5 80 sec 51Ns Maximum Time Delay 3141 51Ns T max Sens Gnd Fault 0 50 200 00 sec 93 00 sec 51Ns Maximum Time Delay at 51Ns PU 3142 51Ns TIME DIAL Sens Gnd Fault 0 05 15 00 sec 1 35 sec 51Ns Time Dial 3143 51Ns Startpoint Sens Gnd Fault 1 0 4 0 1 1 51Ns Start Point of Inverse Charac 3150 50Ns 2 Vmin Sens Gnd Fault 0 4 50 0 V 2 0 V 50Ns 2 minimum vol...

Page 638: ... MOTOR 48 66 Motorprot 0 80 25 Temperature limit for cold motor 4201 FCT 49 49 Th Overload OFF ON Alarm Only OFF 49 Thermal overload protection 4202 49 K FACTOR 49 Th Overload 0 10 4 00 1 10 49 K Factor 4203 TIME CONSTANT 49 Th Overload 1 0 999 9 min 100 0 min Time Constant 4204 49 Θ ALARM 49 Th Overload 50 100 90 49 Thermal Alarm Stage 4205 I ALARM 49 Th Overload 1A 0 10 4 00 A 1 00 A Current Ove...

Page 639: ...9 2 Dropout Ratio 5019 59 1 PICKUP V1 27 59 O U Volt 40 150 V 110 V 59 1 Pickup V1 5020 59 2 PICKUP V1 27 59 O U Volt 40 150 V 120 V 59 2 Pickup V1 5101 FCT 27 27 59 O U Volt OFF ON Alarm Only OFF 27 Undervoltage Protection 5102 27 1 PICKUP 27 59 O U Volt 10 210 V 75 V 27 1 Pickup 5103 27 1 PICKUP 27 59 O U Volt 10 120 V 75 V 27 1 Pickup 5106 27 1 DELAY 27 59 O U Volt 0 00 100 00 sec 1 50 sec 27 1...

Page 640: ... ON f OFF 81 3 Over Under Frequency Pro tection 5424 FCT 81 4 O U 81 O U Freq OFF ON f ON f OFF 81 4 Over Under Frequency Pro tection 6001 S1 RE RL P System Data 2 0 33 7 00 1 00 S1 Zero seq compensating factor RE RL 6002 S1 XE XL P System Data 2 0 33 7 00 1 00 S1 Zero seq compensating factor XE XL 6003 S1 x P System Data 2 0 0050 15 0000 Ω mi 0 2420 Ω mi S1 feeder reactance per mile x 6004 S1 x P...

Page 641: ...ose SYNC function 1 0 01 0 60 sec 0 06 sec Closing operating time of CB 6121 Balancing V1 V2 SYNC function 1 0 50 2 00 1 00 Balancing factor V1 V2 6122A ANGLE ADJUSTM SYNC function 1 0 360 0 Angle adjustment transformer 6123 CONNECTIONof V2 SYNC function 1 A G B G C G A B B C C A A B Connection of V2 6125 VT Vn2 primary SYNC function 1 0 10 800 00 kV 12 00 kV VT nominal voltage V2 primary 6130 dV ...

Page 642: ...hing at synchronous condi tion 6220 T CB close SYNC function 2 0 01 0 60 sec 0 06 sec Closing operating time of CB 6221 Balancing V1 V2 SYNC function 2 0 50 2 00 1 00 Balancing factor V1 V2 6222A ANGLE ADJUSTM SYNC function 2 0 360 0 Angle adjustment transformer 6223 CONNECTIONof V2 SYNC function 2 A G B G C G A B B C C A A B Connection of V2 6225 VT Vn2 primary SYNC function 2 0 10 800 00 kV 12 0...

Page 643: ...Maximum duration of Synchroni zation 6313A 25 Synchron SYNC function 3 YES NO YES Switching at synchronous condi tion 6320 T CB close SYNC function 3 0 01 0 60 sec 0 06 sec Closing operating time of CB 6321 Balancing V1 V2 SYNC function 3 0 50 2 00 1 00 Balancing factor V1 V2 6322A ANGLE ADJUSTM SYNC function 3 0 360 0 Angle adjustment transformer 6323 CONNECTIONof V2 SYNC function 3 A G B G C G A...

Page 644: ...vision time of V1 V2 or V1 V2 6412 T SYN DURATION SYNC function 4 0 01 1200 00 sec 30 00 sec Maximum duration of Synchroni zation 6413A 25 Synchron SYNC function 4 YES NO YES Switching at synchronous condi tion 6420 T CB close SYNC function 4 0 01 0 60 sec 0 06 sec Closing operating time of CB 6421 Balancing V1 V2 SYNC function 4 0 50 2 00 1 00 Balancing factor V1 V2 6422A ANGLE ADJUSTM SYNC funct...

Page 645: ...e AR 7114 T Start MONITOR 79M Auto Recl 0 01 320 00 sec 0 50 sec AR start signal monitoring time 7115 CB TIME OUT 79M Auto Recl 0 10 320 00 sec 3 00 sec Circuit Breaker CB Supervision Time 7116 Max DEAD EXT 79M Auto Recl 0 50 1800 00 sec 100 00 sec Maximum dead time extension 7117 T ACTION 79M Auto Recl 0 01 320 00 sec sec Action time 7118 T DEAD DELAY 79M Auto Recl 0 0 1800 0 sec 1 0 sec Maximum ...

Page 646: ...tarts 79 Stops 79 No influence Sensitive Ground Fault 7163 46 79M Auto Recl No influence Starts 79 Stops 79 No influence 46 7164 BINARY INPUT 79M Auto Recl No influence Starts 79 Stops 79 No influence Binary Input 7165 3Pol PICKUP BLK 79M Auto Recl YES NO NO 3 Pole Pickup blocks 79 7166 50 3 79M Auto Recl No influence Starts 79 Stops 79 No influence 50 3 7167 50N 3 79M Auto Recl No influence Start...

Page 647: ...d T Set value T T before 2 Cycle 51 7217 bef 2 Cy 51N 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 2 Cycle 51N 7218 bef 2 Cy 67 1 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 2 Cycle 67 1 7219 bef 2 Cy 67N 1 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 2 Cycle 67N 1 7220 bef 2 Cy 67 2 79M Auto Recl Set value T T instant ...

Page 648: ...T Set value T T before 4 Cycle 50N 2 7240 bef 4 Cy 51 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 4 Cycle 51 7241 bef 4 Cy 51N 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 4 Cycle 51N 7242 bef 4 Cy 67 1 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 4 Cycle 67 1 7243 bef 4 Cy 67N 1 79M Auto Recl Set value T T instant T 0 ...

Page 649: ...Factor 8109 FAST Σ i MONIT Measurem Superv OFF ON ON Fast Summated Current Monitor ing 8201 FCT 74TC 74TC TripCirc ON OFF ON 74TC TRIP Circuit Supervision 8202 Alarm Delay 74TC TripCirc 1 30 sec 2 sec Delay Time for alarm 8301 DMD Interval Demand meter 15 Min 1 Sub 15 Min 3 Subs 15 Min 15 Subs 30 Min 1 Sub 60 Min 1 Sub 60 Min 10 Subs 5 Min 5 Subs 60 Min 1 Sub Demand Calculation Intervals 8302 DMD ...

Page 650: ...ge 1 Pickup 9035 RTD 3 STAGE 2 RTD Box 50 250 C 120 C RTD 3 Temperature Stage 2 Pickup 9036 RTD 3 STAGE 2 RTD Box 58 482 F 248 F RTD 3 Temperature Stage 2 Pickup 9041A RTD 4 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 4 Type 9042A RTD 4 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD 4 Location 9043 RTD 4 STAGE 1 RTD Box 50 250 C 100 C RTD 4 Temperature Sta...

Page 651: ...ge 1 Pickup 9075 RTD 7 STAGE 2 RTD Box 50 250 C 120 C RTD 7 Temperature Stage 2 Pickup 9076 RTD 7 STAGE 2 RTD Box 58 482 F 248 F RTD 7 Temperature Stage 2 Pickup 9081A RTD 8 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 8 Type 9082A RTD 8 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD 8 Location 9083 RTD 8 STAGE 1 RTD Box 50 250 C 100 C RTD 8 Temperature Sta...

Page 652: ...TD Box Oil Ambient Winding Bearing Other Other RTD11 Location 9113 RTD11 STAGE 1 RTD Box 50 250 C 100 C RTD11 Temperature Stage 1 Pickup 9114 RTD11 STAGE 1 RTD Box 58 482 F 212 F RTD11 Temperature Stage 1 Pickup 9115 RTD11 STAGE 2 RTD Box 50 250 C 120 C RTD11 Temperature Stage 2 Pickup 9116 RTD11 STAGE 2 RTD Box 58 482 F 248 F RTD11 Temperature Stage 2 Pickup 9121A RTD12 TYPE RTD Box Not connected...

Page 653: ...ion Function Type of In for matio n Log Buffers Configurable in Matrix IEC 60870 5 103 Event Log ON OFF Trip Fault Log ON OFF Ground Fault Log ON OFF Marked in Oscill Record LED Binary Input Function Key Relay Chatter Suppression Type Information Number Data Unit General Interrogation Back Light on Light on Device General SP On Off LED BI BO Reset LED Reset LED Device General IntSP on LED BO 160 1...

Page 654: ...vice IntSP LED BO Interlocking Disconnect switch Open Disc Open Control Device IntSP LED BO Interlocking Disconnect switch Close Disc Close Control Device IntSP LED BO Interlocking Ground switch Open GndSw Open Control Device IntSP LED BO Interlocking Ground switch Close GndSw Cl Control Device IntSP LED BO Unlock data transmission via BI UnlockDT Control Device IntSP LED BO Q2 Open Close Q2 Op Cl...

Page 655: ...D BI BO 135 49 1 Yes 5 Reset LED Reset LED Device General SP LED BI BO 135 50 1 Yes 7 Setting Group Select Bit 0 Set Group Bit0 Change Group SP LED BI BO 135 51 1 Yes 8 Setting Group Select Bit 1 Set Group Bit1 Change Group SP LED BI BO 135 52 1 Yes 009 0100 Failure EN100 Modul Failure Modul EN100 Modul 1 IntSP On Off LED BO 009 0101 Failure EN100 Link Channel 1 Ch1 Fail Ch1 EN100 Modul 1 IntSP On...

Page 656: ... Yes 161 Failure General Current Supervi sion Fail I Superv Measurem Superv OUT On Off LED BO 160 32 1 Yes 162 Failure Current Summation Fail ure Σ I Measurem Superv OUT On Off LED BO 135 182 1 Yes 163 Failure Current Balance Fail I balance Measurem Superv OUT On Off LED BO 135 183 1 Yes 167 Failure Voltage Balance Fail V balance Measurem Superv OUT On Off LED BO 135 186 1 Yes 169 VT Fuse Failure ...

Page 657: ...req SYNC function 1 SP On Off LED 170 2007 25 Sync Measuring request of Control 25 Measu req SYNC function 2 SP On Off LED 170 2007 25 Sync Measuring request of Control 25 Measu req SYNC function 3 SP On Off LED 170 2007 25 Sync Measuring request of Control 25 Measu req SYNC function 4 SP On Off LED 170 2008 BLOCK 25 group 1 BLK 25 1 SYNC function 1 SP On Off LED BI 170 2008 BLOCK 25 group 2 BLK 2...

Page 658: ...f LED BI 170 2015 25 Switch to V1 and V2 25 V1 V2 SYNC function 3 SP On Off LED BI 170 2015 25 Switch to V1 and V2 25 V1 V2 SYNC function 4 SP On Off LED BI 170 2016 25 Switch to Sync 25 synchr SYNC function 1 SP On Off LED BI 170 2016 25 Switch to Sync 25 synchr SYNC function 2 SP On Off LED BI 170 2016 25 Switch to Sync 25 synchr SYNC function 3 SP On Off LED BI 170 2016 25 Switch to Sync 25 syn...

Page 659: ...OUT On Off LED BO 170 2029 25 Condition V1 V2 fulfilled 25 V1 V2 SYNC function 3 OUT On Off LED BO 170 2029 25 Condition V1 V2 fulfilled 25 V1 V2 SYNC function 4 OUT On Off LED BO 170 2030 25 Voltage difference Vdiff okay 25 Vdiff ok SYNC function 1 OUT On Off LED BO 41 207 1 Yes 170 2030 25 Voltage difference Vdiff okay 25 Vdiff ok SYNC function 2 OUT On Off LED BO 170 2030 25 Voltage difference ...

Page 660: ... 25 Frequency f2 fmin permissi ble 25 f2 SYNC function 2 OUT On Off LED BO 170 2036 25 Frequency f2 fmin permissi ble 25 f2 SYNC function 3 OUT On Off LED BO 170 2036 25 Frequency f2 fmin permissi ble 25 f2 SYNC function 4 OUT On Off LED BO 170 2037 25 Voltage V1 Vmax permissi ble 25 V1 SYNC function 1 OUT On Off LED BO 170 2037 25 Voltage V1 Vmax permissi ble 25 V1 SYNC function 2 OUT On Off LED ...

Page 661: ... f1 25 f2 f1 SYNC function 2 OUT On Off LED BO 170 2092 25 fdiff too large f2 f1 25 f2 f1 SYNC function 3 OUT On Off LED BO 170 2092 25 fdiff too large f2 f1 25 f2 f1 SYNC function 4 OUT On Off LED BO 170 2093 25 fdiff too large f2 f1 25 f2 f1 SYNC function 1 OUT On Off LED BO 170 2093 25 fdiff too large f2 f1 25 f2 f1 SYNC function 2 OUT On Off LED BO 170 2093 25 fdiff too large f2 f1 25 f2 f1 SY...

Page 662: ...function 2 SP On Off LED BI 170 2102 BLOCK 25 CLOSE command BLK 25 CLOSE SYNC function 3 SP On Off LED BI 170 2102 BLOCK 25 CLOSE command BLK 25 CLOSE SYNC function 4 SP On Off LED BI 170 2103 25 CLOSE command is BLOCKED 25 CLOSE BLK SYNC function 1 OUT On Off LED BO 41 37 1 Yes 170 2103 25 CLOSE command is BLOCKED 25 CLOSE BLK SYNC function 2 OUT On Off LED BO 170 2103 25 CLOSE command is BLOCKED...

Page 663: ... Waveform data deleted Wave deleted Osc Fault Rec OUT_ Ev on LED BO 135 203 1 No 220 Error Range CT Ph wrong CT Ph wrong Device General OUT On Off 234 2100 27 59 blocked via operation 27 59 blk 27 59 O U Volt IntSP On Off LED BO 235 2110 BLOCK Function 00 BLOCK 00 Flx SP On Off On Off LED BI FC TN BO 235 2111 Function 00 instantaneous TRIP 00 instant Flx SP On Off On Off LED BI FC TN BO 235 2112 F...

Page 664: ...O 264 Failure RTD Box 1 Fail RTD Box 1 RTD Box OUT On Off LED BO 267 Failure RTD Box 2 Fail RTD Box 2 RTD Box OUT On Off LED BO 268 Supervision Pressure Su perv Pressure Measurement OUT On Off LED BO 269 Supervision Temperature Su perv Temp Measurement OUT On Off LED BO 270 Set Point Pressure SP Pres sure Set Points MV OUT On Off LED BO 271 Set Point Temp SP Temp Set Points MV OUT On Off LED BO 27...

Page 665: ...SP on LED BI BO 399 V1 MIN MAX Buffer Reset V1 MiMa Reset Min Max meter SP on LED BI BO 400 P MIN MAX Buffer Reset P MiMa Reset Min Max meter SP on LED BI BO 401 S MIN MAX Buffer Reset S MiMa Reset Min Max meter SP on LED BI BO 402 Q MIN MAX Buffer Reset Q MiMa Reset Min Max meter SP on LED BI BO 403 Idmd MIN MAX Buffer Reset Idmd MiMaReset Min Max meter SP on LED BI BO 404 Pdmd MIN MAX Buffer Res...

Page 666: ... Fault Locator VI On Off 1115 Flt Locator primary REAC TANCE Xpri Fault Locator VI On Off 1117 Flt Locator secondary RESIS TANCE Rsec Fault Locator VI On Off 1118 Flt Locator secondary REAC TANCE Xsec Fault Locator VI On Off 151 18 4 No 1119 Flt Locator Distance to fault dist Fault Locator VI On Off 151 19 4 No 1120 Flt Locator Distance to fault d Fault Locator VI On Off 1122 Flt Locator Distance ...

Page 667: ...tection BLOCKED Sens Gnd block Sens Gnd Fault OUT On Off On Off LED BO 151 130 1 Yes 1264 Corr Resistive Earth current IEEa Sens Gnd Fault VI On Off 1265 Corr Reactive Earth current IEEr Sens Gnd Fault VI On Off 1266 Earth current absolute Value IEE Sens Gnd Fault VI On Off 1267 Displacement Voltage VGND 3Vo VGND 3Vo Sens Gnd Fault VI On Off 1271 Sensitive Ground fault pick up Sens Gnd Pickup Sens...

Page 668: ...T On Off LED BO 167 15 1 Yes 1516 49 Overload Alarm Near Thermal Trip 49 O L Θ Alarm 49 Th Overload OUT On Off LED BO 167 16 1 Yes 1517 49 Winding Overload 49 Winding O L 49 Th Overload OUT On Off LED BO 167 17 1 Yes 1521 49 Thermal Overload TRIP 49 Th O L TRIP 49 Th Overload OUT on m LED BO 167 21 2 Yes 1580 49 Reset of Thermal Overload Image RES 49 Image 49 Th Overload SP On Off LED BI BO 1581 4...

Page 669: ...n LED BO 1787 50 3 TimeOut 50 3 TimeOut 50 51 Overcur OUT LED BO 1788 50N 3 TimeOut 50N 3 TimeOut 50 51 Overcur OUT LED BO 1791 50 N 51 N TRIP 50 N 51 N TRIP 50 51 Overcur OUT on m LED BO 160 68 2 No 1800 50 2 picked up 50 2 picked up 50 51 Overcur OUT On Off LED BO 60 75 2 Yes 1804 50 2 Time Out 50 2 TimeOut 50 51 Overcur OUT LED BO 60 49 2 Yes 1805 50 2 TRIP 50 2 TRIP 50 51 Overcur OUT on m LED ...

Page 670: ...up 51N Disk Pickup 50 51 Overcur OUT LED BO 1994 Cold Load Pickup switched OFF CLP OFF ColdLoadPickup OUT On Off LED BO 60 244 1 Yes 1995 Cold Load Pickup is BLOCKED CLP BLOCKED ColdLoadPickup OUT On Off On Off LED BO 60 245 1 Yes 1996 Cold Load Pickup is RUNNING CLP running ColdLoadPickup OUT On Off LED BO 60 246 1 Yes 1997 Dynamic settings are ACTIVE Dyn set ACTIVE ColdLoadPickup OUT On Off LED ...

Page 671: ... 1 Yes 2657 67N 67N TOC is BLOCKED 67N BLOCKED 67 Direct O C OUT On Off On Off LED BO 63 14 1 Yes 2658 67N 67N TOC is ACTIVE 67N ACTIVE 67 Direct O C OUT On Off LED BO 63 15 1 Yes 2659 67N 1 is BLOCKED 67N 1 BLOCKED 67 Direct O C OUT On Off On Off LED BO 63 93 1 Yes 2660 67 1 picked up 67 1 picked up 67 Direct O C OUT On Off LED BO 63 20 2 Yes 2664 67 1 Time Out 67 1 Time Out 67 Direct O C OUT LED...

Page 672: ...P On Off LED BI BO 2715 Start 79 Ground program Start 79 Gnd 79M Auto Recl SP on LED BI BO 40 15 2 Yes 2716 Start 79 Phase program Start 79 Ph 79M Auto Recl SP on LED BI BO 40 16 2 Yes 2720 Enable 50 67 N 2 override 79 blk Enable ANSI 2 P System Data 2 SP On Off LED BI BO 40 20 1 Yes 2722 Switch zone sequence coordi nation ON ZSC ON 79M Auto Recl SP On Off LED BI BO 2723 Switch zone sequence coord...

Page 673: ...79 Close 79M Auto Recl OUT on m LED BO 160 128 2 No 2862 79 cycle successful 79 Suc cessful 79M Auto Recl OUT on on LED BO 40 162 1 Yes 2863 79 Lockout 79 Lockout 79M Auto Recl OUT on on LED BO 40 163 2 Yes 2865 79 Synchro check request 79 Sync Request 79M Auto Recl OUT on LED BO 2878 79 A R single phase reclosing se quence 79 L N Sequence 79M Auto Recl OUT on LED BO 40 180 2 Yes 2879 79 A R multi...

Page 674: ...46 46 Negative Seq SP LED BI BO 70 126 1 Yes 5145 Reverse Phase Rotation Re verse Rot P System Data 1 SP On Off LED BI BO 5147 Phase rotation ABC Rotation ABC P System Data 1 OUT On Off LED BO 70 128 1 Yes 5148 Phase rotation ACB Rotation ACB P System Data 1 OUT On Off LED BO 70 129 1 Yes 5151 46 switched OFF 46 OFF 46 Negative Seq OUT On Off LED BO 70 131 1 Yes 5152 46 is BLOCKED 46 BLOCKED 46 Ne...

Page 675: ...BI BO 5952 BLOCK 50 1Ph 1 BLK 50 1Ph 1 50 1Ph SP LED BI BO 5953 BLOCK 50 1Ph 2 BLK 50 1Ph 2 50 1Ph SP LED BI BO 5961 50 1Ph is OFF 50 1Ph OFF 50 1Ph OUT On Off LED BO 5962 50 1Ph is BLOCKED 50 1Ph BLOCKED 50 1Ph OUT On Off On Off LED BO 5963 50 1Ph is ACTIVE 50 1Ph ACTIVE 50 1Ph OUT On Off LED BO 5966 50 1Ph 1 is BLOCKED 50 1Ph 1 BLK 50 1Ph OUT On Off On Off LED BO 5967 50 1Ph 2 is BLOCKED 50 1Ph ...

Page 676: ...rvoltage protection switched OFF 59 OFF 27 59 O U Volt OUT On Off LED BO 74 65 1 Yes 6566 59 Overvoltage protection is BLOCKED 59 BLOCKED 27 59 O U Volt OUT On Off On Off LED BO 74 66 1 Yes 6567 59 Overvoltage protection is ACTIVE 59 ACTIVE 27 59 O U Volt OUT On Off LED BO 74 67 1 Yes 6568 59 picked up 59 1 picked up 27 59 O U Volt OUT On Off LED BO 74 68 2 Yes 6570 59 TRIP 59 1 TRIP 27 59 O U Vol...

Page 677: ... Iie f Flt ev Prot IIE Flt det FE Intermit EF OUT on 152 13 2 No 6927 Interm E F detected Inter mitt EF Intermit EF OUT On Off LED BO 152 14 2 Yes 6928 Counter of det times elapsed IEF Tsum exp Intermit EF OUT on LED BO 152 15 2 No 6929 Interm E F reset time running IEF Tres run Intermit EF OUT On Off LED BO 152 16 2 Yes 6930 Interm E F trip IEF Trip Intermit EF OUT on LED BO 152 17 2 No 6931 Max ...

Page 678: ...66 Motorprot OUT On Off LED BO 10025 Load Jam Protection picked up Load Jam pickup 48 66 Motorprot OUT On Off LED BO 10026 Load Jam Protection TRIP Load Jam TRIP 48 66 Motorprot OUT On Off LED BO 10027 Startup Duration 1 StartDuration1 Mot Statistics VI 10028 Startup Current 1 StartupCurrent1 Mot Statistics VI 10029 Startup Voltage 1 StartupVoltage1 Mot Statistics VI 10030 Total Number of Motor St...

Page 679: ... Fail RTD 3 RTD Box OUT On Off LED BO 14132 RTD 3 Temperature stage 1 picked up RTD 3 St 1 p up RTD Box OUT On Off LED BO 14133 RTD 3 Temperature stage 2 picked up RTD 3 St 2 p up RTD Box OUT On Off LED BO 14141 Fail RTD 4 broken wire shorted Fail RTD 4 RTD Box OUT On Off LED BO 14142 RTD 4 Temperature stage 1 picked up RTD 4 St 1 p up RTD Box OUT On Off LED BO 14143 RTD 4 Temperature stage 2 pick...

Page 680: ...Temperature stage 2 picked up RTD11 St 2 p up RTD Box OUT On Off LED BO 14221 Fail RTD12 broken wire short ed Fail RTD12 RTD Box OUT On Off LED BO 14222 RTD12 Temperature stage 1 picked up RTD12 St 1 p up RTD Box OUT On Off LED BO 14223 RTD12 Temperature stage 2 picked up RTD12 St 2 p up RTD Box OUT On Off LED BO 16001 Sum Current Exponentiation Ph A to Ir x ΣI x A Statistics VI 16002 Sum Current ...

Page 681: ... Breaker W Log blk SwCyc Isc SwCyc Ir 52WL blk n PErr P System Data 2 OUT On Off LED BO 16029 Sens gnd flt 51Ns BLOCKED Setting Error 51Ns BLK PaErr Sens Gnd Fault OUT On Off LED BO 16030 Angle between 3Vo and INsens ϕ 3Vo INs Sens Gnd Fault VI On Off 30053 Fault recording is running Fault rec run Osc Fault Rec OUT LED BO 31000 Q0 operationcounter Q0 OpCnt Control Device VI 31001 Q1 operationcount...

Page 682: ...oard error Error Board 1 Error Board 2 Error Board 3 Error Board 4 Error Board 5 Error Board 6 Error Board 7 Error Offset Alarm NO calibr 160 Alarm Sum Event 162 163 167 175 176 264 267 Failure Σ I Fail I balance Fail V balance Fail Ph Seq I Fail Ph Seq V Fail RTD Box 1 Fail RTD Box 2 161 Fail I Superv 162 163 Failure Σ I Fail I balance 171 Fail Ph Seq 175 176 Fail Ph Seq I Fail Ph Seq V 255 Fail ...

Page 683: ...unction 3 130 3 No 9 4 CFC CD DD 170 2051 f1 f1 SYNC function 4 130 4 No 9 4 CFC CD DD 170 2052 V2 V2 SYNC function 1 130 1 No 9 3 CFC CD DD 170 2052 V2 V2 SYNC function 2 130 2 No 9 3 CFC CD DD 170 2052 V2 V2 SYNC function 3 130 3 No 9 3 CFC CD DD 170 2052 V2 V2 SYNC function 4 130 4 No 9 3 CFC CD DD 170 2053 f2 f2 SYNC function 1 130 1 No 9 7 CFC CD DD 170 2053 f2 f2 SYNC function 2 130 2 No 9 7...

Page 684: ...Overload Θ Θtrip Measurement CFC CD DD 809 Time untill release of reclose blocking T re close Measurement CFC CD DD 830 INs Senstive Ground Fault Current INs Measurement 134 118 No 9 3 CFC CD DD 831 3Io zero sequence 3Io Measurement CFC CD DD 832 Vo zero sequence Vo Measurement 134 118 No 9 2 CFC CD DD 833 I1 positive sequence Demand I1 dmd Demand meter CFC CD DD 834 Active Power Demand P dmd Dema...

Page 685: ...V1 positive sequence Voltage Maximum V1 Max Min Max meter CFC CD DD 876 Active Power Minimum Pmin Min Max meter CFC CD DD 877 Active Power Maximum Pmax Min Max meter CFC CD DD 878 Reactive Power Minimum Qmin Min Max meter CFC CD DD 879 Reactive Power Maximum Qmax Min Max meter CFC CD DD 880 Apparent Power Minimum Smin Min Max meter CFC CD DD 881 Apparent Power Maximum Smax Min Max meter CFC CD DD ...

Page 686: ...o 9 10 CFC CD DD 1078 Temperature of RTD11 Θ RTD11 Measurement 134 146 No 9 11 CFC CD DD 1079 Temperature of RTD12 Θ RTD12 Measurement 134 146 No 9 12 CFC CD DD 16004 Threshold Sum Current Exponentiation ΣI x SetPoint Stat CFC CD DD 16009 Lower Threshold of CB Residual Endurance Resid Endu SetPoint Stat CFC CD DD 16017 Threshold Sum Squared Current Integral ΣI 2t SetPoint Stat CFC CD DD 16031 Angl...

Page 687: ...0 C151 A8 2 SIPROTEC DIGSI Start UP E50417 G1176 C152 A2 3 DIGSI CFC Manual E50417 H1140 C098 A7 4 SIPROTEC SIGRA 4 Manual E50417 H1176 C070 A4 5 Additional Information on the Protection of Explosion Protected Motors of Protection Type Increased Safety e C53000 B1174 C157 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 688: ...Literature SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 688 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 689: ...ndication Bitstring Of x Bit x designates the length in bits 8 16 24 or 32 bits C_xx Command without feedback CF_xx Command with feedback CFC Continuous Function Chart CFC is a graphics editor with which a program can be created and configured by using ready made blocks CFC blocks Blocks are parts of the user program delimited by their function their structure or their purpose Chatter blocking A r...

Page 690: ...splay The image which is displayed on devices with a large graphic display after pressing the control key is called control display It contains the switchgear that can be controlled in the feeder with status display It is used to perform switching operations Defining this diagram is part of the configuration Data pane The right hand area of the project window displays the contents of the area sele...

Page 691: ...ea to another Electromagnetic compatibility Electromagnetic compatibility EMC is the ability of an electrical apparatus to function fault free in a specified environment without influencing the environment unduly EMC Electromagnetic compatibility ESD protection ESD protection is the total of all the means and measures used to protect electrostatic sensitive devices ExBPxx External bit pattern indi...

Page 692: ...on is used to update the system end process image The current process state can also be sampled after a data loss by means of a GI GOOSE message GOOSE messages Generic Object Oriented Substation Event in accordance with IEC 61850 are data pack ages that are transmitted cyclically and event controlled via the Ethernet communication system They serve for direct information exchange among the relays ...

Page 693: ...ra has been completed This data is split up into several files One file contains details about the fundamental project structure This also includes for example information detailing which fields exist in this project This file is called a HV project description file ID Internal double point indication Double point indication ID_S Internal double point indication intermediate position 00 Double poi...

Page 694: ...n exchanged among the users is also stored in this object IRIG B Time signal code of the Inter Range Instrumentation Group IS Internal single point indication Single point indication IS_F Internal indication fleeting Fleeting indication Single point indication ISO 9001 The ISO 9000 ff range of standards defines measures used to ensure the quality of a product from the devel opment to the manufactu...

Page 695: ...onnection the local modem and the remote modem Modem profile A modem profile consists of the name of the profile a modem driver and may also comprise several initialization commands and a user address You can create several modem profiles for one physical modem To do so you need to link various initialization commands or user addresses to a modem driver and its properties and save them under diffe...

Page 696: ...r addresses for a modem connection are saved in this object type PMV Pulse metered value Process bus Devices featuring a process bus interface can communicate directly with the SICAM HV modules The process bus interface is equipped with an Ethernet module PROFIBUS PROcess FIeld BUS the German process and field bus standard as specified in the standard EN 50170 Volume 2 PROFIBUS It defines the func...

Page 697: ...nnecting DIGSI for example via modem Setting parameters General term for all adjustments made to the device Parameterization jobs are executed by means of DIGSI or in some cases directly on the device SI Single point indication SI_F Single point indication fleeting Transient information Single point indication SICAM SAS Modular substation automation system based on the substation controller SICAM ...

Page 698: ...t Objects of type SIPROTEC 4 variant have a variety of uses such as documenting different operating states when entering parameter settings of a SIPROTEC 4 device Slave A slave may only exchange data with a master after being prompted to do so by the master SIPROTEC 4 devices operate as slaves Time stamp Time stamp is the assignment of the real time to a process event Topological view DIGSI Manage...

Page 699: ... their properties and states that are used by a communication user through services A VD can be a physical device a module of a device or a software module VD address The VD address is assigned automatically by DIGSI Manager It exists only once in the entire project and thus serves to identify unambiguously a real SIPROTEC 4 device The VD address assigned by DIGSI Manager must be transferred to th...

Page 700: ...Glossary SIPROTEC 7SJ62 64 Manual C53000 G1140 C207 2 Release date 01 2008 700 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 701: ...he Configured Operating Devices 461 Checking Additional Interface 439 Checking Operator Interface 438 Checking Service Interface 438 Checking System Connections 441 Checking System Interface 439 Checking Termination 439 Checking Time Synchronization Interface 440 Checking User Defined Functions 450 Circuit Breaker Maintenance 535 Circuit Breaker Monitoring 257 Circuit Breaker Status Recognition 25...

Page 702: ... 335 Ground Fault 131 132 Ground fault 137 Measurement procedure cos ϕ 222 Ground Fault Check 456 Ground Fault Detection Current Element for cos ϕ sin ϕ 220 Current Element for U0 10 ϕ 227 Direction Determination for cos ϕ sin ϕ 221 237 Logic for cos ϕ sin ϕ 223 Logic for U0 10 ϕ 228 Voltage Element for cos ϕ sin ϕ 219 Voltage Element for U0 10 ϕ 226 Ground fault detection Trip time delay at V0 I0...

Page 703: ...hase Current Elements 496 Frequency 496 496 Overload protection 187 Overvoltage Protection 59 142 P Panel Flush Mounting 539 540 541 Phase rotation 332 Phase Sequence Monitoring 202 Pickup logic 334 Pickup voltage 410 412 Pickup voltage of BI4 to BI11 7SJ62 410 412 Pickup Voltages of BI1 to BI7 413 Polarity Check for Current Input IN 457 R Rack Mounting 433 Reclosing Programs 253 Recordings for Te...

Page 704: ... 440 474 Total Time 168 Transformer Knee point Voltage 132 Triggering Oscillographic Recording 462 Trip Circuit Monitoring 535 Trip circuit monitoring 394 Trip circuit supervision 212 Trip Close Tests for the Configured Operating Devices 461 Tripping Logic 335 Tripping Test with Circuit Breaker 461 Two phase overcurrent protection 81 U Undervoltage Consideration 73 Undervoltage Protection 27 143 U...

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