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Functions

2.11 Automatic Reclosing System 79

SIPROTEC, 7SJ61, Manual
C53000-G1140-C210-1, Release date 02.2008

173

For the busbar fault F2, the 50-2 element at the bus would have cleared the fault in 0.4 seconds. Zone sequenc-
ing enables the user to set a relatively short time period for the 50-2 elements. The 50-2 element is only used 
as backup protection. If zone sequencing is not applied, the 50-1 element is to be used only with its relatively 
long time period (0.9 s).

Figure 2-59

Zone sequencing with a fault occurring at Tap Line #5 and the busbar

2.11.6

Setting Notes

General Settings

The internal automatic reclosure system will only be effective and accessible if address 

171

 

79 Auto Recl.

 

is set 

Enabled

 during configuration. If not required, this function is set to 

Disabled

. The function can be 

turned 

ON

 or 

OFF

 under address 

7101

 

FCT 79

.

If no automatic reclosures are performed on the feeder for which the 7SJ61 is used (e.g. cables, transformers, 
motors, etc.), the automatic reclosure function is disabled by configuration. The automatic reclosure function is 
then completely disabled, i.e. the automatic reclosure function is not processed in the 7SJ61. No messages 
exist for this purpose and binary inputs for the automatic reclosure function are ignored. All parameters of block 
71 are inaccessible and of no significance.

Blocking Duration for Manual-CLOSE Detection

Parameter 

7103

 

BLOCK MC Dur.

 defines the reaction of the automatic reclosure function when a manual 

closing signal is detected. The parameter can be set to specify how long the auto reclose function will be 
blocked dynamically in case of an external manual close-command being detected via binary input (356 

„>Manual Close“

). If the setting is 0, the automatic reclosure 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 reclosing cycle is started 
in case of multiple reclosures. If no further reclosure is allowed, the last reclosure will be classed as unsuccess-
ful.

In general, a few seconds are sufficient. In areas with frequent thunderstorms or storms, a shorter blocking time 
may be necessary to avoid feeder lockout due to sequential lightning strikes or flashovers.

Summary of Contents for SIPROTEC 7SJ61

Page 1: ...i functional Protective Relay with Bay Controller 7SJ61 V4 7 Manual C53000 G1140 C210 1 Preface Contents Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Appendix A Literature Glossary Index ...

Page 2: ...editions We appreciate any suggested improvements We reserve the right to make technical improvements without notice Document version V04 00 02 Release date 02 2008 Copyright Copyright Siemens AG 2008 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 damage...

Page 3: ...matic and control facilities and personnel of electrical facilities and power plants Applicability of this Manual This manual applies to SIPROTEC 4 Multi functional Protective Relay with Bay Controller 7SJ61 firmware version V4 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 relatin...

Page 4: ...e local Siemens rep resentative 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 Siemens Power Academy TD Humboldt Street 59 90459 Nuremberg Telephone 0911 4 33 ...

Page 5: ...d according to the degree 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 re...

Page 6: ... approved by Siemens The 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 b...

Page 7: ... may appear word for 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 ma...

Page 8: ... is active Coincidence gate 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 paramete...

Page 9: ... 33 2 1 3 Power System Data 1 35 2 1 3 1 Description 35 2 1 3 2 Setting Notes 35 2 1 3 3 Settings 40 2 1 3 4 Information List 41 2 1 4 Oscillographic Fault Records 41 2 1 4 1 Description 41 2 1 4 2 Setting Notes 42 2 1 4 3 Settings 43 2 1 4 4 Information List 43 2 1 5 Settings Groups 43 2 1 5 1 Description 43 2 1 5 2 Setting Notes 44 2 1 5 3 Settings 44 2 1 5 4 Information List 44 2 1 6 Power Syst...

Page 10: ...ttings 81 2 3 4 Information List 82 2 4 Single Phase Overcurrent Protection 83 2 4 1 Functional Description 83 2 4 2 High impedance Ground Fault Unit Protection 85 2 4 3 Tank Leakage Protection 87 2 4 4 Setting Notes 88 2 4 5 Settings 93 2 4 6 Information List 93 2 5 Negative Sequence Protection 46 94 2 5 1 Definite Time Characteristic 94 2 5 2 Inverse Time Characteristic 46 TOC 95 2 5 3 Setting N...

Page 11: ...on Responses of the Monitoring Functions 144 2 8 3 1 Description 144 2 9 Ground Fault Protection 50N s 51N s 147 2 9 1 Current Elements 50Ns 51Ns 147 2 9 2 Logic 148 2 9 3 Setting Notes 150 2 9 4 Settings 154 2 9 5 Information List 155 2 10 Intermittent Ground Fault Protection 156 2 10 1 Description 156 2 10 2 Setting Notes 160 2 10 3 Settings 161 2 10 4 Information List 161 2 11 Automatic Reclosi...

Page 12: ...s 198 2 13 4 Information List 199 2 14 Temperature Detection via RTD Boxes 200 2 14 1 Description 200 2 14 2 Setting Notes 201 2 14 3 Settings 203 2 14 4 Information List 208 2 15 Phase Rotation 209 2 15 1 Description 209 2 15 2 Setting Notes 210 2 16 Function Logic 211 2 16 1 Pickup Logic of the Entire Device 211 2 16 2 Tripping Logic of the Entire Device 212 2 16 3 Setting Notes 212 ...

Page 13: ...r of Measured Values 228 2 17 3 3 Information List 229 2 17 4 Average Measurements 230 2 17 4 1 Description 230 2 17 4 2 Setting Notes 230 2 17 4 3 Settings 230 2 17 4 4 Information List 231 2 17 5 Min Max Measurement Setup 231 2 17 5 1 Description 231 2 17 5 2 Setting Notes 231 2 17 5 3 Settings 231 2 17 5 4 Information List 232 2 17 6 Set Points for Measured Values 232 2 17 6 1 Description 233 2...

Page 14: ...3 Installation 282 3 1 3 1 Panel Flush Mounting 282 3 1 3 2 Rack Mounting and Cubicle Mounting 283 3 1 3 3 Panel Flush Mounting 284 3 2 Checking Connections 285 3 2 1 Checking Data Connections of Serial Interfaces 285 3 2 2 Checking System Connections 288 3 3 Commissioning 290 3 3 1 Test Mode and Transmission Block 291 3 3 2 Testing the System Interface 291 3 3 3 Checking the Status of Binary Inpu...

Page 15: ...tection 46 1 46 2 334 4 8 Negative Sequence Protection 46 TOC 335 4 9 Motor Starting Protection 48 341 4 10 Motor Restart Inhibit 66 342 4 11 Load Jam Protection 343 4 12 Thermal Overload Protection 49 344 4 13 Ground Fault Protection 50N s 51N s 346 4 14 Intermittent Ground Fault Protection 350 4 15 Automatic Reclosing System 79 351 4 16 Breaker Failure Protection 50BF 352 4 17 Flexible Protectio...

Page 16: ...s 389 A 4 Current Transformer Requirements 391 A 4 1 Accuracy limiting factors 391 Effective and Rated Accuracy Limiting Factor 391 Calculation example according to IEC 60044 1 391 A 4 2 Class conversion 392 A 4 3 Cable core balance current transformer 393 General 393 Requirements 393 Class accuracy 393 A 5 Default Settings 394 A 5 1 LEDs 394 A 5 2 Binary Input 394 A 5 3 Binary Output 395 A 5 4 Fu...

Page 17: ... 2008 17 Introduction 1 The SIPROTEC 7SJ61 device is introduced in this chapter An overview of the 7SJ61 is presented with its ap plications areas characteristics and scope of functions 1 1 Overall Operation 18 1 2 Application Scope 21 1 3 Characteristics 23 ...

Page 18: ...t inputs three of these are for the input of the phase currents Depending on the model the fourth current input IN may be used for mea suring the ground fault current IN current transformer starpoint or for a separate ground current transformer for ground fault detection INs The analog input quantities are passed on to the input amplifiers IA Figure 1 1 Hardware structure of the numerical multi fu...

Page 19: ...ributed via output amplifiers OA Binary Inputs and Outputs Binary inputs 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 ...

Page 20: ... 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 from a variety of additional interface modules The ope...

Page 21: ...ions are available Some of them depend on the version of the device that is ordered These additional functions include negative se quence protection 46 thermal overload protection 49 with start inhibit for motors 66 68 and motor starting protection 48 as well as automatic reclosing 79 which allows different reclosing cycles on overhead lines An automatic reclosing system may also be connected exte...

Page 22: ...r 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 system interface ensures the central communication between the device and the...

Page 23: ...cs covering the hard ware and software 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 star...

Page 24: ...urrent transformer Suitable as differential protection that includes the neutral point current on a transformer side a generator side or a motor side or for a grounded reactor set As tank leakage protection against illegal leakage currents between transformer casing and ground Negative Sequence Protection 46 Evaluation of negative sequence component of the currents Two definite time elements 46 1 ...

Page 25: ...s 1 mA The overcurrent protection element may be operated with either a definite time or an inverse time delay One user defined and two logarithmic inverse current time curves are available for inverse time O C protec tion Optionally applicable as additional ground fault protection Intermittent Ground Fault Protection Detects and accumulates intermittent ground faults Tripping after configurable t...

Page 26: ...lemented ΣI procedure ΣIx procedure 2P procedure and I2t procedure Acquisition and conditioning of measured values for all subfunctions operates phase selective using one procedure specific threshold per subfunction User defined Functions Internal and external signals can be logically combined to establish user defined logic functions All common Boolean operations are available for programming AND...

Page 27: ...ctions should be used 2 1 General 28 2 2 Overcurrent Protection 50 51 50N 51N 48 2 3 Dynamic Cold Load Pickup 77 2 4 Single Phase Overcurrent Protection 83 2 5 Negative Sequence Protection 46 94 2 6 Motor Protection 102 2 7 Thermal Overload Protection 49 124 2 8 Monitoring Functions 134 2 9 Ground Fault Protection 50N s 51N s 147 2 10 Intermittent Ground Fault Protection 156 2 11 Automatic Reclosi...

Page 28: ...deactivated during the configuration procedure The interaction of functions may also be modified 2 1 1 1 Description Configuration of Functions Example for the configuration of 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 re...

Page 29: ...hether 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 sensitive ground fault detection address 131Sens Gnd Fault is used to specify whether this function...

Page 30: ...be created This is done by setting checkmarks at the functions If the checkmark of a function is removed all settings and configurations made previously will be lost After re selecting the function all settings and config urations are in default setting Setting of the flexible function is done in DIGSI under Parameters Additional Functions and Settings The configuration is done as usual under Para...

Page 31: ...2 52 B WEAR MONIT Disabled Ix Method 2P Method I2t Method Disabled 52 Breaker Wear Monitoring 182 74 Trip Ct Supv Disabled 2 Binary Inputs 1 Binary Input Disabled 74TC Trip Circuit Supervision 190 RTD BOX INPUT Disabled Port C Disabled External Temperature Input 191 RTD CONNECTION 6 RTD simplex 6 RTD HDX 12 RTD HDX 6 RTD simplex Ext Temperature Input Connec tion Type FLEXIBLE FUNC 1 20 Flex Functi...

Page 32: ...ssages When the relay drops off stationary conditions fault display Target on PU Target on TRIP Trip No 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 2 1 2 2 Setting Notes Fault Messages A new pickup of a protection function generally turns off any previously set light displays so that only the latest fault i...

Page 33: ...or FMS FO 2 Distur CFC OUT Disturbance CFC 1 Not configured SP No Function configured 2 Non Existent SP Function Not Available 3 Time Synch SP_Ev Synchronize Internal Real Time Clock 5 Reset LED SP Reset LED 15 Test mode SP Test mode 16 DataStop SP Stop data transmission 51 Device OK OUT Device is Operational and Protecting 52 ProtActive IntSP At Least 1 Protection Funct is Active 55 Reset Device ...

Page 34: ... 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 from MLFB 220 CT Ph wrong OUT Error Range CT Ph wrong 301 Pow Sys Flt OUT Power System fault 302 Fault Event OUT Fault Event 303 sens Gnd flt OUT sensitive Ground fault 320 Warn Mem Data OUT Warn Lim...

Page 35: ... display To obtain the Power System Data display select the P System Data 1 in SETTINGS display In DIGSI double click on Settings to display the relevant selection A dialog box will open under the option P System Data 1 with the tabs and Prot Op quant where you can configure the individual parameters The following descriptions are therefore structured accordingly Rated Frequency Power System The r...

Page 36: ...nt 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 9 In this case parameter 280 Holmgr for Σi is set to YES In all other cases even if the ground current of the own line is measured via a separate ground current transformer the setting NO has to be made This setting exclusively affects...

Page 37: ... 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 settings only differ in the calculation of IB In case of A G2 C G G B the phase current IB is determined by phase currents IA and IC as well as the measured ground curren...

Page 38: ...re rating of the current transformer In case of a normal connection starpoint current connected to IG transformer 217 Ignd CT PRIM and 204 CT PRIMARY must be set to the same value If the device features a sensitive ground current input parameter 218 Ignd CT SEC is set to 1 A by default In this case the setting cannot be changed If address 251 has been set so that ground currents are measured by tw...

Page 39: ...nd the different procedures are explained in the setting notes of this function see Section 2 17 2 Two phase Time Overcurrent Protection Protection Operating Quantities The two phase overcurrent protection functionality is used in grounded or compensated systems where inter action of three phase devices with existing two phase protection equipment is required Via parameter 250 50 51 2 ph prot the ...

Page 40: ...uration 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 214 Rated Frequency 50 Hz 60 Hz 50 Hz Rated Frequency 217 Ignd CT PRIM 1 50000 A 60 A Ignd CT rated primary current 218 Ignd CT SEC 1A 5A 1A Ignd CT rated secondary current 235A ATEX100 NO YES NO Storage of th Replicas w o Power Supply 238 Ignd2 CT PRIM 1 50000 A 60 A Ignd2 CT rated primary...

Page 41: ...ents the data recorded during the system fault and also calculates additional information from the mea sured values Currents 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 recording data can be passed on to a central device via this interface The evaluation of ...

Page 42: ...criterion A fault event starts with the pickup by any protection function and ends when the last pickup of a protection function has dropped out Usually this is also the extent of a fault recording address 402 WAVEFORM DATA Fault event If automatic reclosing is performed the entire system fault with several reclosing attempts if necessary can be recorded until the fault has been cleared for good a...

Page 43: ...ault A setting group includes the setting values for all functions that have been selected as Enabled during con figuration see Section 2 1 1 2 In 7SJ61 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 Addr Parameter Setting Options Default Setting Comments 401 WAVEFORMTRIGGE R Save w Pickup Save ...

Page 44: ... information on how to copy setting groups or reset them to their status at delivery and also how to change from one setting group to another Subsection 3 1 of this manual tells you how to change between several setting groups externally via binary inputs 2 1 5 3 Settings 2 1 5 4 Information List Addr Parameter Setting Options Default Setting Comments 302 CHANGE Group A Group B Group C Group D Bin...

Page 45: ... the primary reference current phase of the protected equipment is entered e g motors If this reference variable matches the primary value of the current transformer it is equiv alent to the setting at Address 204 Section 2 1 3 2 They are generally used to show values as a percentage of full scale Recognition of Running Condition Only for Motors When the configured current value at Address 1107 I ...

Page 46: ...n 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 561 Man Clos Detect OUT Manual close signal detected 2720 Enable ANSI 2 SP Enable 50 67 N 2 overrid...

Page 47: ...nteroperable operation Parallel 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 modul...

Page 48: ... with the quantities 3I0 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 tim...

Page 49: ...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 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 PIC...

Page 50: ...1 Release date 02 2008 50 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 ...

Page 51: ...lease date 02 2008 51 Figure 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 ...

Page 52: ... currents 0 3 INom Pickup 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 pick...

Page 53: ... dropout delay only operates 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 ...

Page 54: ...ted as soon as the pickup 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...

Page 55: ... 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 The calculated tripping time depends on t...

Page 56: ...6 Figure 2 10 Logic diagram 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 ...

Page 57: ...f when 95 of the pickup value 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 inerti...

Page 58: ...l seconds Although pickup of the relay elements is based only on the fundamental harmonic component of the measured currents false device pickup due to inrush is still a potential problem since depending on the transformer size and design the inrush current also comprises a large component of the fundamental 7SJ61 features an integrated inrush restraint function It prevents the normal pickup of 50...

Page 59: ...ually for each phase protection is ideal where a power transformer is en ergized into a single phase fault and inrush currents are detected on a different healthy phase However the protection feature can be configured to allow that not only this phase element but also the remaining elements including ground are blocked the so called CROSS BLOCK function address 2203 if the permissible har monic co...

Page 60: ...Functions 2 2 Overcurrent Protection 50 51 50N 51N SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 60 Figure 2 12 Logic diagram for inrush restraint ...

Page 61: ...the tripping is also indicated Internal Annunciation Display 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 C 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 P...

Page 62: ... 9 Fast Busbar Protection 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 s...

Page 63: ...stics available The superimposed 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 characteris...

Page 64: ...method the operating time of the element is reduced compared to the measurement of true r m s values or fundamental harmonics see Technical Data 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 13...

Page 65: ... by overvoltage conditions is already accounted for by the 1 6 factor The 50 2 element can be tripped without delay 50 2 DELAY 0 00 s since saturation of the shunt reactance occurs in a motor unlike in a transformer for example The principle of the reverse interlocking utilizes the multi element function of the time overcurrent protection Element 50 2 PICKUP is applied as a fast busbar protection ...

Page 66: ...y can be also be set to In this case the element will not trip after pickup However pickup will be signaled If the 50 1 element is not required at all then the pickup threshold 50 1 should be set to This setting prevents tripping and the generation of a pickup message 50N 1 Element ground For setting the 50N 1 ement it is the minimum anticipated ground fault current that must be considered If the ...

Page 67: ...after pickup However pickup will be signaled If the 51 element is not required at all address 112 Charac Phase should be set to Definite Time during protective function configuration see Section 2 1 1 2 51N Element ground with IEC or ANSI Characteristics Having set address 113 Charac Ground TOC IEC when configuring the protection functions Section 2 1 1 the parameters for the inverse characteristi...

Page 68: ...rrent values is They are therefore disabled and no pickup or tripping of these pro tection functions will occur The following must be observed The value pairs should be entered in increasing sequence If desired fewer than 20 pairs can be entered In most cases about 10 pairs is sufficient to define the characteristic accurately A value pair which is not used has to be made invalid by entering for t...

Page 69: ...urves When using DIGSI to make settings a dialog box opens where you can enter up to 20 value pairs measured quantity and trip time see Figure 2 15 In order to represent the characteristic graphically the user should click on characteristic The previously entered characteristic will appear as shown in Figure 2 15 The characteristic curve shown in the graph can be modified later on Placing the mous...

Page 70: ...vide more restraint in exceptional cases where energizing conditions are particularly unfavorable a smaller value can be set in the aforementioned address e g 12 Irrespective of parameter 2202 2nd HARMONIC rush blocking will only occur if the absolute value of the 2nd harmonic is at least 0 025 INom sec The effective duration of the cross blocking 2203 CROSS BLK TIMER can be set to a value between...

Page 71: ...will be blocked At address 1214 50 2 active or 1216 50 3 active it can be spec ified whether the 50 2 or the 50 3 element should be influenced by the status of an internal or external auto matic reclosing system The setting with 79 active means that the 50 2 or 50 3 elements will only be re leased if automatic reclosing is not blocked If this is not desired choose the setting Always so that the 50...

Page 72: ...0 00 sec 0 50 sec 50 1 Time 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...

Page 73: ...ay 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 3 20 sec 0 20 sec 51N Time Dial 1309 51N TIME DIAL 0 50 15 00 5 00 51N Time Dial 1310 51N Drop out Instantaneous Disk Emulation Disk Emulation Drop Out Characteristi...

Page 74: ...ent 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 ON OFF Inrush Restraint 2202 2nd HARMONIC 10 45 15 2nd harmonic in of fun damental 2203 CROSS BLOC...

Page 75: ...0 51 Ph A PU OUT 50 51 Phase 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 ...

Page 76: ...BLOCKED OUT 51N BLOCKED 1866 51 Disk Pickup OUT 51 Disk emulation Pickup 1867 51N Disk Pickup OUT 51N Disk emulation picked 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 ...

Page 77: ...tarted and 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 ...

Page 78: ...CLP is enabled all triggered 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 break...

Page 79: ...Functions 2 3 Dynamic Cold Load Pickup SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 79 Figure 2 18 Logic diagram of the dynamic cold load pickup function 50c 50Nc 51c 51Nc 67c 67Nc ...

Page 80: ...haracteristics of the equipment being protected and should be set to allow for brief overloads associated with dynamic cold load conditions 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 settings for the high set elements are set at addresses...

Page 81: ...KUP 1A 0 10 35 00 A 2 00 A 50c 1 Pickup 5A 0 50 175 00 A 10 00 A 1804 50c 1 DELAY 0 00 60 00 sec 0 30 sec 50c 1 Time Delay 1805 51c PICKUP 1A 0 10 4 00 A 1 50 A 51c Pickup 5A 0 50 20 00 A 7 50 A 1806 51c TIME DIAL 0 05 3 20 sec 0 50 sec 51c Time dial 1807 51c TIME DIAL 0 50 15 00 5 00 51c Time dial 1808 50c 3 PICKUP 1A 1 00 35 00 A A 50c 3 Pickup 5A 5 00 175 00 A A 1809 50c 3 DELAY 0 00 60 00 sec ...

Page 82: ...rmation Comments 1730 BLOCK 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 ...

Page 83: ...y 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 protection The dropout value i...

Page 84: ...Functions 2 4 Single Phase Overcurrent Protection SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 84 Figure 2 20 Logic diagram of the single phase time overcurrent protection ...

Page 85: ...e system is assumed somewhere else Figure 2 21 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 extern...

Page 86: ...ned such that even with the 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 4 4 High impedance Protection with 7SJ61 With 7SJ61 the sensitive measurement input INs or alternatively the insensitive measurement input IN is used for high impedance prot...

Page 87: ...ion for example the device is connected to the parallel connection of all feeder current transformers via the resistor 2 4 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 throu...

Page 88: ...n also be set to the corresponding element will then not trip after pickup but the pickup is reported Special 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...

Page 89: ...e current transformers gets totally saturated The other ones will continue transmitting their partial currents 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 25 shows a simplified equivalent circuit CT1 and CT2 are assumed as ideal transformers with their inner resistances R...

Page 90: ...07 m 117 02 yd with 2 5 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 t...

Page 91: ...nd faults for a short period 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...

Page 92: ...this case the mag netizing 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...

Page 93: ...50 1Ph 1 PICKUP 1A 0 05 35 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 BLO...

Page 94: ...ddition with unbalanced supply 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 cur...

Page 95: ...ociated 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 exceeds 1 1 times the setting value a pickup annunciation is generated ...

Page 96: ...f 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 menting process is in idle state Disk emulation offers advantages when th...

Page 97: ...p delay time is reset unless 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 e...

Page 98: ...rred to the nominal machine 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 ...

Page 99: ...cation is well suited for 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 tran...

Page 100: ...of about 1 1 times the setting 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 addr...

Page 101: ...2 DELAY 0 00 60 00 sec 1 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...

Page 102: ...time If the durations 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 ti...

Page 103: ...onfigured under address 4102 then the actual tripping time tTrip is prolonged or shortened ac cordingly see Figure 2 30 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 inpu...

Page 104: ... will reset timers and pickup 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 31 Logic diagra...

Page 105: ... be turned ON or OFF under 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 exte...

Page 106: ...factors are present peak 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...

Page 107: ...during this startup attempt There fore the 7SJ61 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...

Page 108: ...during motor starting the different maximum temperatures in the the rotor are not pertinant for motor restart inhibit see Figure 2 32 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 32 shows as an example the heating processes during repeated motor starts three starts from cold o...

Page 109: ...passed restarting time TRestart 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 re...

Page 110: ...he operational measured value 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...

Page 111: ...otor restart inhibit signal 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 th...

Page 112: ...Functions 2 6 Motor Protection SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 112 Figure 2 33 Logic diagram for the restart inhibit ...

Page 113: ...rent IMOT NOM the maximum 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...

Page 114: ... thermal replica T MIN INHIBIT 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 ...

Page 115: ... machine into a temperature 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 34 on the left 2 A normal startup brings the machine into a temperature range belo...

Page 116: ...ing until the temperature 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 35 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 equilibr...

Page 117: ...er is able to detect a locked rotor quicker thus reducing possible damage to the motor and powered equipment 2 6 3 1 Mode of Operation Principle of Operation Figure 2 36 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 a...

Page 118: ...38 shows the logic diagram 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 pr...

Page 119: ...Functions 2 6 Motor Protection SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 119 Figure 2 38 Logic diagram of the load jam protection ...

Page 120: ... BkrClosed I MIN the open 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 39 i...

Page 121: ...time can remain at the default 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 cu...

Page 122: ...UP 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 Time 4304 T Equal 0 0 320 0 min 1 0 min Temperature Equalizaton Time 4305 I MOTOR NOMINAL 1A 0 20 1 2...

Page 123: ...or 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 6813 ...

Page 124: ...mal 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 object s heating I Present true r m s value of phase current k k factor indicating the maximum p...

Page 125: ...rst 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 coolant temperature the maximum permissible current Imax is influenced by the tempera ture di...

Page 126: ...eatures a programmable run 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 Dependin...

Page 127: ...Functions 2 7 Thermal Overload Protection 49 SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 127 Figure 2 40 Logic diagram of the overload protection ...

Page 128: ...overload protection is 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 Par...

Page 129: ...For cable protection the 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 calcula...

Page 130: ...qual to or slightly less than the permissible current 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 the 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 behav...

Page 131: ...iates from the nominal CT 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 420...

Page 132: ...K 40 C ΘNom Mach 93 C Temperature 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 ...

Page 133: ...erload Alarm Setpoint 5A 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 150...

Page 134: ...ation and a message is 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 devia...

Page 135: ... Imax takes into account the permissible current proportional ratio errors of the input transformer which are par ticularly prevalent during large short circuit currents Figure 2 41 The dropout ratio is about 97 Figure 2 41 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 ...

Page 136: ...ctions during the processing of programs are discovered This also initiates a restart of the processor system If such a malfunction is not cleared by the restart 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 d...

Page 137: ...x BAL FACTOR I as long as Imax INom BALANCE I LIMIT INom Thereby Imax is the largest of the three phase currents and Imin the smallest The symmetry factor BAL FACTOR I address 8105 represents the allowable asymmetry of the phase currents while the limit value 8105 address 8104 is the lower limit of the operating range of this monitoring see Figure 2 43 Both param eters can be set The dropout ratio...

Page 138: ...sporadically the relevant parameters should be set less sensitive Address 8104 BALANCE I LIMIT determines the limit current above which the current symmetry monitor is effective Address 8105 BAL FACTOR I is the associated symmetry factor that is the slope of the symmetry characteristic curve Address 8106 Σ I THRESHOLD determines the limit current above which the current sum monitor is activated ab...

Page 139: ... Threshold for Balance Monitoring 5A 0 50 5 00 A 2 50 A 8105 BAL FACTOR I 0 10 0 90 0 50 Balance Factor for Current Monitor 8106 Σ I THRESHOLD 1A 0 05 2 00 A 0 10 A Summated Current Moni toring Threshold 5A 0 25 10 00 A 0 50 A 8107 Σ I FACTOR 0 00 0 95 0 10 Summated Current Moni toring Factor 8109 FAST Σ i MONIT OFF ON ON Fast Summated Current Monitoring No Information Type of In formation Comment...

Page 140: ...etected under all circuit 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 supervisi...

Page 141: ...a short circuit exists in 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 5 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 ...

Page 142: ... R by the 52b circuit breaker 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 s...

Page 143: ...liably bridged and an indica 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 ...

Page 144: ...he front cover if the internal auxiliary voltage is present and the green RUN LED goes out If the internal auxiliary voltage fails all LEDs are dark Table 2 6 provides a summary of the mon itoring 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 Ti...

Page 145: ...Internal hardware Device shutdown LED ERROR DOK2 drops out Measured value acquisition External hardware 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...

Page 146: ...rtain messages of the monitoring functions are already combined to group alarms A listing of the group alarms and their composition is given in the Appendix A 10 In this case it must be noted that message 160 Alarm Sum Event is only issued when the measured value monitoring functions 8101 MEASURE SUPERV are activated ...

Page 147: ...n electrical machines which are directly connected to the busbar of an isolated power system when in case of a network ground fault the machine supplies only a neg ligible ground fault current across the measurement location which must be situated between the machine ter minals and the network whereas in case of a machine ground fault the higher ground fault current produced by the total network i...

Page 148: ... When ground fault protection is ON tripping is possible The entire func tion may be blocked via binary input Switching off or blocking means the measurement logic shown in Figure 2 50 is deactivated Therefore time delays and pickup messages are reset All elements can be blocked individually via binary inputs In this case pickups are still reported but tripping is prevented because the time stages...

Page 149: ...Functions 2 9 Ground Fault Protection 50N s 51N s SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 149 Figure 2 50 Logic diagram of the sensitive ground fault protection ...

Page 150: ...sed high set element 50Ns 2 is available in all these cases If the function is not required Disabled is set Sensitive ground fault detection may be switched ON or OFF or to Alarm Only in address 3101 Sens Gnd Fault If sensitive ground fault protection is switched ON both tripping and message reporting is possible A two stage current time characteristic may be set at addresses 3113 through 3120 The...

Page 151: ...stics of inverse 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 see figure 2 52 is set with the parameters 3119 51Ns PICKUP 3127 5...

Page 152: ...ot enabled and no pickup or tripping of these protective functions will occur Up to 20 pairs of values 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 Fewer than 20 pairs is also sufficient In most cases about 10 pairs is suff...

Page 153: ...ed as primary values under consideration of the current transformer ratio However problems related to the resolution of the pickup currents can occur when very small settings and small nominal primary currents are given The user is therefore encouraged to enter settings for the sensitive ground fault detection in secondary values MofPU 1 to 1 94 MofPU 2 to 4 75 MofPU 5 to 7 75 MofPU 8 to 20 1 00 1...

Page 154: ... 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 3127 51Ns I T min 0 003 1 400 A 1 333 A 51Ns Current at const...

Page 155: ... 50Ns 2 SP BLOCK 50Ns 2 1203 BLOCK 50Ns 1 SP BLOCK 50Ns 1 1204 BLOCK 51Ns SP BLOCK 51Ns 1207 BLK 50Ns 67Ns SP BLOCK 50Ns 67Ns 1211 50Ns 67Ns OFF OUT 50Ns 67Ns is OFF 1212 50Ns 67Ns ACT OUT 50Ns 67Ns is ACTIVE 1221 50Ns 2 Pickup OUT 50Ns 2 Pickup 1223 50Ns 2 TRIP OUT 50Ns 2 TRIP 1224 50Ns 1 Pickup OUT 50Ns 1 Pickup 1226 50Ns 1 TRIP OUT 50Ns 1 TRIP 1227 51Ns Pickup OUT 51Ns picked up 1229 51Ns TRIP ...

Page 156: ...ee phase currents 3 I0 Unlike the over current protection which uses the fundamental wave the intermittent ground fault protection creates the r m s value of this current and compares it to a settable threshold Iie This method accounts for higher order har monics contents up to 400 Hz and for the direct component since both factors contribute to the thermal load Pickup Tripping If the pickup thres...

Page 157: ...fault or after expiration of the summation monitoring time T sum det and besides this its basic design is to prevent thermal overload For these reasons the intermittent ground fault protection is not implemented as starting feature of the automatic reclosing function Interaction with Breaker Failure Protection A pickup that is present when the time delay TRIP Timer has expired is interpreted by th...

Page 158: ...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 time overcurrent stages to pick up e g 50 1 50N 1 50Ns 1 and produce a burst of ...

Page 159: ...messages which usually do not occur during an intermittent ground fault are not affected by this mechanism This includes the pickup and TRIP commands of the following protective functions Breaker failure protection Thermal Overload Protection FNo Message Explanation 1800 50 2 picked up 50 2 picked up 7551 50 1 InRushPU 50 1 InRush picked up 7552 50N 1 InRushPU 50N 1 InRush picked up 7553 51 InRush...

Page 160: ...etting range depends on the selection of the current to be evaluated at address 133 INTERM EF The pickup time can be prolonged at address 3303 T det ext This pickup stabilization is especially impor tant for the coordination with existing analog or electromechanical overcurrent relays The time T det ext can also be disabled T det ext 0 The stabilized pickup starts the counter T sum det This counte...

Page 161: ...3 T det ext 0 00 10 00 sec 0 10 sec Detection extension time 3304 T sum det 0 00 100 00 sec 20 00 sec Sum of detection times 3305 T reset 1 600 sec 300 sec Reset time 3306 Nos det 2 10 3 No of det for start of int E F prot No Information Type of In formation Comments 6903 IEF block SP block interm E F prot 6921 IEF OFF OUT Interm E F prot is switched off 6922 IEF blocked OUT Interm E F prot is blo...

Page 162: ...er In some systems several reclosing attempts are performed Applications The automatic reclosure system integrated in the 7SJ61 can also be controlled by an external protection device e g backup protection For this application an output contact from the tripping relay must be wired to a binary input of the 7SJ61 relay It is also possible to allow the relay 7SJ61 to work in conjunction with an exte...

Page 163: ...successful 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 this purpose for the first and all subsequent reclosing commands ...

Page 164: ...o influence or block reclosing Stops 79 Table 2 10 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 Autom...

Page 165: ... 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 binary input The multiple phase fault phase fault reclosing program applies to all other cases That is when elements associated with two or more...

Page 166: ...n 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 repeated until the set number of reclosing attempts for the corresponding reclose program has been reached The dead time intervals preceding th...

Page 167: ...tarted by a blocking condition 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 ...

Page 168: ...es from dynamic blocking 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 11 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 recl...

Page 169: ... to each reclosing attempt 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 7SJ61 The mon itoring time CB TIME OUT expires for as long as the circuit breaker does not indicate that it is ready via binary input CB Ready F...

Page 170: ...esholds and tripping time 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 r...

Page 171: ...Functions 2 11 Automatic Reclosing System 79 SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 171 Figure 2 58 Control of protection elements for two fold successful auto reclosure ...

Page 172: ...her high voltage fuses can be overgraded or undergraded Zone sequencing functions by means of blocking certain protection functions depending on the reclosing cycle This is implemented by the protection elements control see margin heading Controlling Protection Ele ments As a special feature changing from one reclosing cycle to the next is possible without trip command only via pickup dropout of 5...

Page 173: ...essed in the 7SJ61 No messages exist for this purpose and binary inputs for the automatic reclosure function are ignored All parameters of block 71 are inaccessible and of no significance Blocking Duration for Manual CLOSE Detection Parameter 7103 BLOCK MC Dur defines the reaction of the automatic reclosure function when a manual closing signal is detected The parameter can be set to specify how l...

Page 174: ...e is set slightly higher than the maximum recovery time of the circuit breaker following reclosure If the circuit breaker is not ready after the time has expired reclosing is omitted and dynamic blocking is initiated Automatic reclosure thus is blocked Time Max DEAD EXT serves for monitoring the dead time extension The extension can be initiated by the circuit breaker monitoring time CB TIME OUT a...

Page 175: ...he exact sequence is described in the func tional description at margin heading Delay of Dead Time Start Number of Reclosing Attempts The number of reclosing attempts can be set separately for the phase program address 7136 OF RECL PH and ground program address 7135 OF RECL GND The exact definition of the programs is described in the functional description at margin heading Reclosing Programs Clos...

Page 176: ...d in this case Auto Reclosing with External Synchrocheck Parameter 7139 External SYNC can be set to determine that the auto reclose function operates with exter nal synchrocheck External synchronization is possible if the parameter is set to YES and 7SJ61 is linked to the external synchrocheck via the message 2865 79 Sync Request and the binary input Sync release Initiation and Blocking of Automat...

Page 177: ... reclosing function Thus protective elements can be blocked selectively made to operate instan taneously or according to the configured delay times The following options are available The following options are available Set value T T The protective element is delayed as configured i e the auto reclose function does not effect this element instant T 0 The protective element becomes instantaneous if...

Page 178: ... which the device has conducted after a trip command With the zone sequencing function switched on an additional sequence counter also counts such auto reclosures which in radial systems are carried out by relays connected on load side This presupposes that the pickup of the 50 1 50N 1 elements drops out without a trip command being issued by a protective function initiating the auto reclose funct...

Page 179: ... for controlling the cold load pickup The signal 79 ready is always active if the auto reclosing system is available active unblocked and ready for another cycle Control via the cold load pickup function is not AR cycle related Since control via cold load pickup and cyclic control via auto reclosing system can run simultaneously the over current protection must coordinate the input values of the t...

Page 180: ...lay 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 Fault 7131 DEADTIME 3 PH 0 01 320 00 sec 0 50 sec Dead Time 3 Phase Fault 7132 DEADTIME 3 G 0 01 320 00 sec 0 5...

Page 181: ...67 50N 3 No influence Starts 79 Stops 79 No influence 50N 3 7200 bef 1 Cy 50 1 Set value T T instant T 0 blocked T Set value T T before 1 Cycle 50 1 7201 bef 1 Cy 50N 1 Set value T T instant T 0 blocked T Set value T T before 1 Cycle 50N 1 7202 bef 1 Cy 50 2 Set value T T instant T 0 blocked T Set value T T before 1 Cycle 50 2 7203 bef 1 Cy 50N 2 Set value T T instant T 0 blocked T Set value T T b...

Page 182: ...ocked T Set value T T before 3 Cycle 50 2 7227 bef 3 Cy 50N 2 Set value T T instant T 0 blocked T Set value T T before 3 Cycle 50N 2 7228 bef 3 Cy 51 Set value T T instant T 0 blocked T Set value T T before 3 Cycle 51 7229 bef 3 Cy 51N Set value T T instant T 0 blocked T Set value T T before 3 Cycle 51N 7236 bef 4 Cy 50 1 Set value T T instant T 0 blocked T Set value T T before 4 Cycle 50 1 7237 b...

Page 183: ...nt 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 79 Ground program 2716 Start 79 Ph SP Start 79 Phase program 2722 ZSC ON SP Switch zone sequence coordination O...

Page 184: ...cle 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 2879 79 L L Sequence OUT 79 A R multi phase reclosing sequence 2883...

Page 185: ...unction principle of the breaker failure protection Initiation The breaker failure protection function can be initiated by two different sources Trip signals of internal protective functions of the 7SJ61 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 set...

Page 186: ...ent Flow Address 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 63 The currents are filtered through numerical filters to evaluate the fundamental harmonic They are monitored and compared to the ...

Page 187: ...sition If valid this information can be used for a proper initiation of the breaker failure protection function The logic diagram illustrates the monitoring of the circuit breaker s auxiliary contacts Figure 2 64 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 sett...

Page 188: ...Functions 2 12 Breaker Failure Protection 50BF SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 188 Figure 2 65 Logic diagram of the breaker failure protection ...

Page 189: ...o not always have a certain criterion for detection of an open circuit breaker 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 66 illustrates the time sequ...

Page 190: ...7005 TRIP Timer 0 06 60 00 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 swit...

Page 191: ...lso be enabled In this state the pickup will not result in a fault and the trip command delay time is not started Tripping is thus not possible If changes of Power System Data 1 are effected after configuration of the flexible functions it may be possible that the sequence of the functions is not configured correctly This is indicated by message Fno 00 inval set This function is not active in this...

Page 192: ...the function employs either a phase s measured quantity which must be stated explicitly e g evaluating only the current in phase Ib or the measured ground current In If external trip commands are used the operating principle is without fixed phase reference Additional parameters can be set to specify the used MEAS QUANTITY and the MEAS METHOD The MEAS METHOD determines whether the function uses th...

Page 193: ...recording is started on pickup If the setting is set to Message only this does not occur If the threshold values continue to be exceeded after expiry of the trip command delay time the trip command is generated 235 2126 00 TRIP Time expiry is reported via Fno 235 2125 00 Time Out Expiry of the trip command delay time can be blocked via binary input Fno 235 2113 00 BLK TDly As long as the binary in...

Page 194: ...e i e the set minimum current threshold 7006 50BF PICKUP is exceeded With the Automatic Reclosure Function AR Initiation of the AR cannot occur directly For interaction with the AR the trip command of the flexible function must be linked via CFC with binary input Fno 2716 Start 79 Ph or Fno 2715 Start 79 Gnd If operating time is used the pickup of the flexible function must be linked additionally ...

Page 195: ...is not required to operate as a protection function Fur thermore the OPERRAT MODE can be configured 3 phase functions evaluate the three phase measuring system i e all three phases are processed simulta neously A typical example is the three phase operating time overcurrent protection Single phase functions evaluate only the individual measuring value This can be an individual phase value e g IB o...

Page 196: ... Positive Sequence System Negative Sequence System Zero Sequence System In order to realize certain applications the positive sequence system or neg ative sequence system can be configured as measurement procedure Exam ple I2 tripping monitoring system Via the selection zero sequence system additional zero sequence current functions can be realized that operate independent of the ground variable I...

Page 197: ... delayed 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 shorte...

Page 198: ...asured Quantity 0 MEAS METHOD Fundamental True RMS Positive seq Negative seq Zero sequence Ratio I2 I1 Fundamental Selection of Measurement Method 0 PICKUP WITH Exceeding Dropping below Exceeding Pickup with 0 CURRENT Ia Ib Ic In In sensitive In2 Ia Current 0 P U THRESHOLD Pickup Threshold 0 P U THRESHOLD Pickup Threshold 0 P U THRESHOLD 0 001 1 500 A 0 100 A Pickup Threshold 0 P U THRESHOLD 15 10...

Page 199: ...RIP Phase A 235 2116 00 BL 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 P...

Page 200: ...erts it to a numerical value The numerical values are made available at a serial port Communication with the Protection Device The protection device can employ with up to 2 RTD boxes via its service port port C 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...

Page 201: ...ust be selected by means 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 te...

Page 202: ...connection is used no further 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 15 Setting the bus address at the RTD box Further information is provided in the operating manual of the RTD box Processing Measured Values ...

Page 203: ... RTD 1 STAGE 2 50 250 C 120 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 Temp...

Page 204: ...ure Stage 1 Pickup 9045 RTD 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...

Page 205: ...perature Stage 1 Pickup 9074 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...

Page 206: ... Bearing Other Other RTD10 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 L...

Page 207: ...e 9122A RTD12 LOCATION Oil Ambient Winding Bearing Other Other RTD12 Location 9123 RTD12 STAGE 1 50 250 C 100 C RTD12 Temperature Stage 1 Pickup 9124 RTD12 STAGE 1 58 482 F 212 F RTD12 Temperature Stage 1 Pickup 9125 RTD12 STAGE 2 50 250 C 120 C RTD12 Temperature Stage 2 Pickup 9126 RTD12 STAGE 2 58 482 F 248 F RTD12 Temperature Stage 2 Pickup Addr Parameter Setting Options Default Setting Comment...

Page 208: ...ure stage 1 picked up 14153 RTD 5 St 2 p up OUT RTD 5 Temperature stage 2 picked up 14161 Fail RTD 6 OUT Fail RTD 6 broken wire shorted 14162 RTD 6 St 1 p up OUT RTD 6 Temperature stage 1 picked up 14163 RTD 6 St 2 p up OUT RTD 6 Temperature stage 2 picked up 14171 Fail RTD 7 OUT Fail RTD 7 broken wire shorted 14172 RTD 7 St 1 p up OUT RTD 7 Temperature stage 1 picked up 14173 RTD 7 St 2 p up OUT ...

Page 209: ...utinely 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 69 Message logic of th...

Page 210: ...e date 02 2008 210 2 15 2 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 ...

Page 211: ...is reported 501 Relay PICKUP 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...

Page 212: ...terminated first when the last protection function 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 t...

Page 213: ...ice further more has output relays for remote indication All LEDs and binary outputs indicating 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 ...

Page 214: ...trip commands initiated by 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 b...

Page 215: ...closing shots oc cupies only one trip log buffer Within a network fault several fault messages can occur from the first pickup of a protective function to the last dropout of a protective function Without auto reclosing each fault event rep resents a network fault In total 600 indications can be recorded Oldest data are erased for newest data when the buffer is full General Interrogation The gener...

Page 216: ...binary inputs Hereby it is necessary that the internal pulse counter is allocated 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 Values Only was enabled in the configuration matrix Number of Automatic Reclosing Commands The number of reclosing co...

Page 217: ... functions and comprises the 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 ea...

Page 218: ...put in motion in order to 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...

Page 219: ...Functions 2 17 Auxiliary Functions SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 219 Figure 2 73 Logic of the start and end criterion ...

Page 220: ...rent criterion If one of 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 criterio...

Page 221: ...on necting line Point P1 is 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 74 Diagram of operating cycles for the 2P procedure As Figure 2 74 illustrates a double log diagram the straight line between P1 and P2 can be exp...

Page 222: ...ent criterion described 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 I...

Page 223: ...breaker 2 17 2 3 Motor Statistics General There are two different types of statistical motor data Operational information and startup information The statistical operational information contains the total number of motor startups total number of the motor operating hours including startup conditions total number of motor shutdown hours For every motor startup the duration the startup current Motor...

Page 224: ... operate correctly The CB Tripping Time is a characteristic value provided by the manufacturer It covers the entire tripping process from the trip command applying auxiliary power to the trip element of the circuit breaker up to arc extinction in all poles The time is set at address 266 T 52 BREAKTIME The CB Operating Time T 52 OPENING is equally a characteristic value of the circuit breaker It co...

Page 225: ...arameters 266 T 52 BREAKTIME and 267 T 52 OPENING The summated values can be interpreted as the number of tripping operations at rated operational current of the CB They are displayed in the statistical values without unit and with two decimal places 2P Procedure Parameter 172 52 B WEAR MONIT can be set to activate the 2P procedure An operating cycles diagram see sample diagram in the functional d...

Page 226: ...me VI Motor Percent Running Time 10037 StartDuration2 VI Startup Duration 2 10038 StartupCurrent2 VI Startup Current 2 10040 StartDuration3 VI Startup Duration 3 10041 StartupCurrent3 VI Startup Current 3 10043 StartDuration4 VI Startup Duration 4 10044 StartupCurrent4 VI Startup Current 4 10046 StartDuration5 VI Startup Duration 5 10047 StartupCurrent5 VI Startup Current 5 16001 ΣI x A VI Sum Cur...

Page 227: ...d percentage values is complete and correct entry of the nominal values for the transformers and the protected equipment as well as current transformer ratios in the ground path when configuring the device The following table shows the formulas which are the basis for the conversion from secondary values into primary values and percentages 2 17 3 1 Display of Measured Values Table 2 16 Conversion ...

Page 228: ...these values are transmitted depend on the protocol and if necessary addition al settings Protocol Transmittable measuring range format IEC 60870 5 103 0 to 240 of the measured value IEC 61850 The primary operational measured values are transmitted The measured values as well as their unit format are set out in detail in manual PIXIT 7SJ The measured values are transmitted in Float format The tran...

Page 229: ...oad 809 T reclose MV Time untill release of reclose blocking 830 INs MV INs Senstive Ground Fault Current 831 3Io MV 3Io zero sequence 1068 Θ RTD 1 MV Temperature of RTD 1 1069 Θ RTD 2 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...

Page 230: ...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 231: ...selected point in time 2 17 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 MinMax cycRESET should be set to YES The point in time when reset is to take place the minute of the day in which reset will take place is set at address 8312 MiMa RESET TIME The reset cycl...

Page 232: ...gnals of protection functions Applications This monitoring program works with multiple measurement repetitions and lower priority than the protection functions For that 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 No Information Type of I...

Page 233: ...Values Setting is performed in the DIGSI Configuration Matrix under Settings Masking I O Configuration Matrix Set the filter Measured and Metered Values Only and select the configuration group Setpoints LV Here default settings may be changed or new setpoints defined Settings must be applied in percent and usually refer to nominal values of the device 2 17 6 3 Information List No Information Type ...

Page 234: ... for Statistic Double click to display the corresponding contents in another window By overwriting the previous value you can change the settings please refer to the SIPROTEC 4 System Descrip tion 2 17 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 Exponentiat...

Page 235: ...rrectly interpreted as resulting from an actual power system disturbance or event As another option all messages and measured values normally trans ferred via the system interface can be blocked during the testing block data transmission Data transmission block can be accomplished by controlling binary inputs by using the operating panel on the device or with a PC and DIGSI via the operator interf...

Page 236: ...s for Tests During commissioning energization sequences should be carried out to check the stability of the protection also during closing operations Oscillographic event recordings contain the maximum information on the be havior of the protection Along with the capability of storing fault recordings via pickup of the protection function the 7SJ61 also has the capability of capturing the same dat...

Page 237: ...is connected via a serial interface Network adapter The required software component is included in Microsoft Windows XP Microsoft Windows 2000 Microsoft Windows NT and Windows 98 This component is only required if the device is connected via a serial interface possible for devices with EN 100 interface 2 17 9 1 General During the commissioning phase the device configuration created in the devices ...

Page 238: ...ss is set at the front and service interface using DIGSI 4 or directly on the device using the integrated operator interface Note It is only possible to monitor this process Control of the process through the data transmission link is only pos sible after a control feature has been set up and established A parameter can be modified either directly on the device or with DIGSI 4 in such manner that ...

Page 239: ...tions The device can be operated with the keys shown in the display in the same way as with the sealed keypad on the device It is recommended to block the control via the Web Monitor This can also be achieved by setting Read Only access for the interface via which the Web browser accesses the device This parameter can be accessed in DIGSI via Interfaces Operator Interface on Device for access via ...

Page 240: ...2 2008 240 Figure 2 78 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 messages are displayed with their short text stored in the device ...

Page 241: ...ion can be electrically implemented via RS232 over short distance or via fiber optics The connection to the system modem is established from the office or from any other system using a switched line DIGSI Remote can also be carried out using this connection Thus parameters of a remote device can also be changed during the in stallation Operation with Star Coupler Connection of the rear service int...

Page 242: ...access is assigned all these operating actions are also possible via the Web Monitor Note No access has no effect yet i e the user also has full access in this case See Figure 2 78 on that 2 17 9 4 Display Example With the help of the Web Monitor a clear representation of the most important measurement data of the device can be achieved The measurement values can be called via the navigation bar A...

Page 243: ... the device menu Setup Options IP 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 ...

Page 244: ...device operator panel via the operating port using a personal computer and via the serial port with a link to the substation control equipment Applications Switchgears with single and double busbars Prerequisites The number of switchgear devices to be controlled is limited by the binary inputs present binary outputs present 2 18 1 1 Description Operation Using the Integrated Operator Panel Using t...

Page 245: ...ker 52Breaker DP 52 Breaker Disc Swit CF_D2 Disconnect Switch Disc Swit DP Disconnect Switch GndSwit CF_D2 Ground Switch GndSwit DP Ground Switch 52 Open IntSP Interlocking 52 Open 52 Close IntSP Interlocking 52 Close Disc Open IntSP Interlocking Disconnect switch Open Disc Close IntSP Interlocking Disconnect switch Close GndSw Open IntSP Interlocking Ground switch Open GndSw Cl IntSP Interlocking...

Page 246: ...ctly operate binary outputs They serve to initiate 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 indi cations and switching states e g if the communication with the process is interrupted Manually overridden objects are flagged as such in the information status and can b...

Page 247: ...CADA system or substation 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 Proces...

Page 248: ... checks can be activated via DIGSI interlocked switching tagging or deactivated non interlocked Deactivated interlock switching means that the configured interlocking conditions are not checked in the relay Interlocked switching means that all configured interlocking conditions are checked within the command pro cessing If a condition is not fulfilled the command will be rejected by a message with...

Page 249: ...be aware activation of thermal overload protection elements or sensitive ground fault detection 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 inhibit for motors will not automatically reject a CLOSE command to the motor Restarting would then have to be interlocked in some other way ...

Page 250: ...Functions 2 18 Breaker Control SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 250 Figure 2 83 Standard interlockings ...

Page 251: ...DIGSI dialog box for setting the interlocking conditions The configured interlocking causes appear on the device display They are marked by letters explained in the following table Table 2 18 Command types and corresponding messages Interlocking Commands Abbrev Message Switching authority L L System interlocking S S Zone controlled Z Z SET ACTUAL switch direction check P P Protection blockage B O ...

Page 252: ... serves to interlock or enable LOCAL control but not REMOTE or DIGSI com mands For the 7SJ61 the switching authority can be changed between REMOTE and LOCAL in the oper ator panel after having entered the password or by means of CFC also via binary input and function key The Switching authority DIGSI is used for interlocking and allows commands to be initiated using DIGSI Commands are allowed for ...

Page 253: ...ed in the op erator panel by password or by means of CFC also via binary input and function key The following switching modes remote are defined For remote or DIGSI commands SC LOCAL REMOTE or DIGSI interlocked or non interlocked switching Here deactivation of interlocking is accomplished via a separate command For commands from CFC SC Auto please observe the notes in the CFC manual component BOOL...

Page 254: ...itchgear conditions of other bays evaluated by a central control system Double Activation Blockage Parallel switching operations are interlocked As soon as the command has arrived all command objects subject to the interlocking are checked to know whether a command is being processed While the command is being executed interlocking is enabled for other commands Blocking by Protection Protection fu...

Page 255: ...modes interlocked or non interlocked to be selected in the operator panel after password entry REMOTE and DIGSI Commands issued by SICAM or DIGSI are unlocked via a global switching mode REMOTE A separate request must be sent for the unlocking The unlocking applies only for one switching operation and for command caused by the same source Job order command to object Switching mode REMOTE ON Job or...

Page 256: ...executed by a response indication as it is done 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 ...

Page 257: ...commissioning of protection 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 258 3 2 Checking Connections 285 3 3 Commissioning 290 3 4 Final Preparation of the Device 303 ...

Page 258: ...rams General diagrams for 7SJ61 are shown in Appendix A 2 Connection examples for current transformer circuits are provided in A 3 Binary Inputs and Outputs The configuration options of the binary in and outputs i e the procedure for the individual adaptation to the plant conditions are described in the SIPROTEC 4 System Description The connections to the plant are de pendent on this configuration...

Page 259: ...nected in series The pick up threshold of the binary inputs must therefore stay substantially below half the rated control DC volt age If two binary inputs are used for the trip circuit supervision these binary inputs must 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 ...

Page 260: ...e binary input This results in an upper limit for the resistance dimension Rmax and a lower limit Rmin from which the optimal value of the arithmetic mean R should be selected In order that the minimum voltage for controlling the binary input is ensured Rmax is derived as So the circuit breaker trip coil does not remain energized in the above case Rmin is derived as ...

Page 261: ... mA VBI min minimum control voltage for BI 19 V for delivery setting for nominal voltage of 24 48 60 125 V 88 V for delivery setting for nominal voltage of 110 125 220 250 V VCTR Control Voltage for Trip Circuit RCBTC DC resistance of circuit breaker trip coil VCBTC LOW Maximum voltage on the circuit breaker trip coil that does not lead to tripping IBI HIGH 1 8 mA SIPROTEC 4 7SJ61 VBI min 19 V for...

Page 262: ...s of the miniature fuse and the buffer battery are also shown When the relays are delivered these jumpers are set according to the name plate sticker Generally they need not be altered Nominal Currents The input transformers of the devices are set to a nominal current of 1 A or 5 A with jumpers Jumpers are set according to the name plate sticker The assignment of the plug in jumpers to the nominal...

Page 263: ... are replaceable Which interfaces can be exchanged and how this is done is described in the following section under the margin heading Exchanging Interface Modules 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 ensure reliable data transmission For this purpose termina...

Page 264: ...ed mat for protecting components subject to damage from electro static discharges ESD The following equipment is required screwdriver with a 5 to 6 mm wide tip 1 Phillips screwdriver 5 mm socket or nut driver Unfasten the screw posts of the D subminiature connector on the back panel at location A This activity is not necessary if the device is designed for surface mounting If besides the interface...

Page 265: ... CPU unit No 1 and the input output printed circuit board A I O No 2 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 that a certain amount of force is required to remove the A CPU board due to the existing plug connector Check the jumpers according to Figures 3 4 to and the f...

Page 266: ...The loca tion of the miniature fuse F1 and of the buffer battery G1 are also shown in the following figures Processor Board A CPU for 7SJ61 DD Figure 3 4 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 the selected control volta...

Page 267: ...up voltages of the binary inputs BI1 to BI3 on the processor board A CPU to 7SJ61 DD 1 Factory settings for devices with rated supply voltage DC 24 to 125 V 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...

Page 268: ... board A CPU for devices releases 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 7 the pickup volt ages of the binary inputs BI1 to BI3 are checked according to Table 3 8 and the contact mode of the binary outputs BO1 and BO2 is checked according to Table 3 6 ...

Page 269: ...ltage DC 24 to 125 V 2 Factory 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 relays BO1 and BO2 on the processor printed circuit board A CPU for 7SJ61 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 us...

Page 270: ...TEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 270 Processor Board A CPU for 7SJ61 FF Figure 3 6 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 ...

Page 271: ...e DC 24 to 125 V 2 Factory 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 BO2 on the processor board A CPU as from 7SJ61 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...

Page 272: ... BI11 are checked Figure 3 7 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 thu...

Page 273: ...es of binary inputs BI4 to BI11 on the input output board A I O 2 up to 7SJ61 EE 1 Factory settings for devices with rated supply voltage DC 24 to 125 V 2 Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 230 VAC Binary Inputs Jumper 19 VDC Pickup 1 88 VDC Pickup 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 ...

Page 274: ... 8 Input output module A I O 2 for devices releases FF 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 devi...

Page 275: ...ts BI4 to BI11 on the input output board A I O 2 as from 7SJ61 FF 1 Factory settings for devices with rated supply voltage DC 24 to 125 V 2 Factory settings for devices with power supply voltages of 110 VDC to 220 VDC and 115 230 VAC Binary Inputs Jumper 19 VDC Pickup 1 88 VDC Pickup 2 176 V 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 ...

Page 276: ...anual C53000 G1140 C210 1 Release date 02 2008 276 3 1 2 4 Interface Modules Exchanging Interface Modules The following Figure shows the processor printed circuit board CPU and arrangement of the modules Figure 3 9 Processor printed circuit board CPU with interface modules ...

Page 277: ...er key see also Appendix A 1 You may have to ensure the termination of the ports featuring bus capability according to the margin heading Termination Table 3 12 Exchangeable interface modules The order numbers of the exchange modules can be found in the Appendix in Section A 1 Accessories Interface Mounting Location Port Exchange Module System Interface O IEC 60870 5 103 RS232 IEC 60870 5 103 RS48...

Page 278: ...11 enables the flow control CTS feature which is important for modem communication Table 3 13 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 req...

Page 279: ...interface RS232 and vice versa according to Figure 3 10 Figure 3 11 Position of terminating resistors and the plug in jumpers for configuration of the RS485 interface Profibus FMS DP DNP 3 0 Modbus Figure 3 12 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...

Page 280: ...interfaces The terminating resistors are located on the RS485 or Profibus interface module mounted on the processor input output board CPU serial no 1 in Figure 3 3 With default setting the jumpers are set such that the terminating resistors are disconnected Both jumpers of a board must always be plugged in the same way The terminating resistors can also be connected externally e g to the connecti...

Page 281: ...lation is easier with the lever First plug the plug connector of the ribbon cable onto the input output board I O and then onto the A CPU processor board Do not bend any connector pins Do not use force Insert the plug connector of the ribbon cable between the processor board A CPU and the front cover in the socket on the front cover Press the latches of the plug connectors together Replace the fro...

Page 282: ...ional 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 terminals or screw terminals on the rear side of the device according to the circuit diagram When using forked lugs for direct connections or screw terminal the screws befo...

Page 283: ...onnect the ground on the rear plate of the device to the protective ground of the rack Use at least one M4 screw for the device ground The cross section of the wire must be equal to the maximum connection cross section area but be at least 2 5 mm 2 Connections are realized via the plug terminals or screw terminals on the rear side of the device according to the circuit diagram When using forked lu...

Page 284: ...g 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 communication...

Page 285: ...e seen in the following figure Figure 3 17 9 pin D subminiature female connectors Figure 3 18 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 ...

Page 286: ...as RS485 interface Pin 7 must therefor not be con nected Termination The RS485 interface is capable of half duplex service with the signal A A and B B with a common relative po tential C C GND Verify that only the last device on the bus has the terminating resistors connected and that the other devices on the bus do not The jumpers for the terminating resistors are located on the interface module ...

Page 287: ...ption RTD Box Resistance Temperature Detector If one or two 7XV566 temperature meters are connected check their connections to the port port C Verify also the termination The terminating resistors must be connected to 7SJ61 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 r...

Page 288: ...current transformer connections against the system and connection diagrams Are the current transformers grounded properly Are the polarities of the current transformers the same Is the phase relationship of the current transformers correct Is the polarity for current input I4 correct if used If check switches are used for secondary testing of the device their functions also must be checked in par ...

Page 289: ...ld correspond to the power input in neutral position of the device The mea sured steady state current should be insignificant Transient movement of the ammeter merely indicates the charging current of capacitors Remove the voltage from the power supply by opening the supply circuit of the power supply Disconnect the measuring test equipment restore the normal power supply connections Check the tri...

Page 290: ... given in Technical Data 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...

Page 291: ...vice features a system interface and this is used to communicate with the control center the DIGSI device operation can be used to test if messages are transmitted correctly This test option should however definitely not be used while the device is in real operation DANGER Danger evolving from operating the equipment e g circuit breakers disconnectors by means of the test function Non observance o...

Page 292: ...an be initiated To do so click on the button Send on the corresponding line The corresponding message is issued and can be read out either from the event log of the SIPROTEC 4 device or from the substation control system As long as the window is open further tests can be performed Test in Message Direction For all information that is transmitted to the central station test the options in the list ...

Page 293: ...interface Note After finishing the hardware tests the device will reboot Thereby all annunciation buffers 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 se...

Page 294: ... the output relay of the 7SJ61 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 internal 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 ...

Page 295: ...y input is triggered and 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 ...

Page 296: ...r breakers e g by interrupting the corresponding pickup voltages Before the breaker is finally closed for normal operation the trip command of the feeder protection 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 i...

Page 297: ...r or busbar section to which the feeder with the fault is connected A general detailed test guide cannot be specified because the layout of the adjacent circuit 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 ...

Page 298: ...ent source as primary and secondary quantities If the measured values are not plausible the connection must be checked and corrected after the line has been isolated and the current transformer circuits have been short circuited The measurements must then be re peated Phase Rotation The phase rotation must correspond to the configured phase rotation in general a clockwise phase rotation If the sys...

Page 299: ...vice has to cool off The direct voltage for reverse interlocking is now switched on to the line The precedent test is repeated the result will be the same Subsequently at each of the protection devices of the feeders a pickup is simulated Meanwhile another fault is simulated for the protection function of the infeed as described before Tripping is performed within time 50 1 DELAY longer time perio...

Page 300: ...0 86 117 055771 140 466925 111 672925 40 104 123 011173 147 613407 115 5408 50 122 129 105 154 926 119 397125 60 140 135 340259 162 408311 123 2419 70 158 141 720613 170 064735 127 075125 80 176 148 250369 177 900442 130 8968 90 194 154 934473 185 921368 134 706925 100 212 161 7785 194 1342 138 5055 110 230 168 788637 202 546364 142 292525 120 248 175 971673 211 166007 146 068 130 266 183 334982 2...

Page 301: ...witching 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 closing of the c...

Page 302: ...ry input Triggering for 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...

Page 303: ...nciations Set Reset so that 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...

Page 304: ...Mounting and Commissioning 3 4 Final Preparation of the Device SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 304 ...

Page 305: ...ction 51 N 320 4 4 Inrush Restraint 331 4 5 DynamiC Cold Load Pickup 332 4 6 Single phase Overcurrent Protection 333 4 7 Negative Sequence Protection 46 1 46 2 334 4 8 Negative Sequence Protection 46 TOC 335 4 9 Motor Starting Protection 48 341 4 10 Motor Restart Inhibit 66 342 4 11 Load Jam Protection 343 4 12 Thermal Overload Protection 49 344 4 13 Ground Fault Protection 50N s 51N s 346 4 14 In...

Page 306: ... 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 Voltage Supply via Integrated Converter Rated auxiliary DC VAux 24 48 VDC 60 110 125 VDC Permissible Voltage Ra...

Page 307: ...00 ms Variant Quantity 7SJ610 3 configurable 7SJ611 8 configurable 7SJ612 11 configurable Rated Voltage Range 24 VDC to 250 VDC bipolar Current Consumption independent of the control voltage Approx 1 8 mA Pickup time Approx 4 ms Switching Thresholds Switching Thresholds adjustable voltage range with jumpers For Nominal Voltages 24 48 60 110 125 VDC V high 19 VDC V low 10 VDC For Nominal Voltages 1...

Page 308: ...tive 25 W at L R 50 ms Switching voltage 250 VDC 250 VAC Admissible current per contact continuous 5 A Adm 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 AC Load it has to be taken into consideration for the dimensions of external circuits Value of the ANSI capacitor 4 70 10 9 F 20 Frequency Impedance 50 Hz 6 77 105 Ω 20 60 H...

Page 309: ...iant Connection for panel flush mounting housing Rear panel mounting location C2 9 pin D subminiature female connector Connection for panel surface mounting housing In the housing at the case bottom Shielded data cable Test voltage 500 V 50 Hz RS232 Bridgeable distance 49 2 feet 15 m RS485 Bridgeable distance 3 280 feet 1000 m Fiber optic cable FO FO connector type ST connector Connection for pane...

Page 310: ...5 200 Bd Factory setting 9 600 Bd Maximum Distance of Transmission max 0 62 miles 1 km Fiber Optical Link FO FO connector type ST connector Connection for flush mounted casing Rear panel mounting location B Connection for surface mounted casing at the housing mounted case on the case bottom Optical Wavelength λ 820 nm Laser Class 1 according to using glass fiber 50 12 µm or using glass fiber 62 5 ...

Page 311: ...ng 57 600 Bd at detached operator panel Optical Wavelength λ 820 nm Laser Class 1 according to 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 DNP3 0 MODBUS RS485 Connection for flush mounted casing Rear panel mounting location B 9 pin D SUB miniatu...

Page 312: ... to IEEE802 3 Connection for Surface mounted case not available Transmission Speed 100 MBit s Optical wavelength 1300 nm bridgeable distance max 0 93 miles 1 5 km Time Synchronization DCF 77 IRIG B Signal Telegram Format IRIG B000 Connection for flush mounted case Rear panel mounting location A 9 pin D subminiature female connector Connection for surface mounting housing at the double deck termina...

Page 313: ...E 0435 Part 303 Class III 2 5 kV Peak 1 MHz τ 15 µs 400 surges per s test duration 2 s Ri 200 Ω Electrostatic Discharge IEC 60255 22 2 Class IV and IEC 61000 4 2 Class IV 8 kV contact discharge 15 kV air discharge both polarities 150 pF Ri 330 Ω Irradiation with HF field pulse modulated IEC 60255 22 3 report Class III 10 V m 27 MHz to 500 MHz Irradiation with HF field amplitude modulated IEC 61000...

Page 314: ...ce IEEE Std C37 90 2 35 V m 25 MHz to 1000 MHz Damped Oscillations IEC 60694 IEC 61000 4 12 2 5 kV Peak Value polarity alternating 100 kHz 1 MHz 10 MHz and 50 MHz Ri 200 Ω Standard EN 50081 technical generic standard Radio noise voltage to lines only auxiliary voltage IEC CISPR 22 150 kHz to 30 MHz Limit Class B Interference field strength IEC CISPR 22 30 MHz to 1000 MHz Limit Class B Harmonic Cur...

Page 315: ...ration IEC 60255 21 3 Class 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 Sinusoid...

Page 316: ...er year 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 device is designed for installation in normal relay rooms and plants so that electromagnetic compatibi...

Page 317: ...terminals 7SJ61 E Housing 7XP20 Dimensions See dimensional drawings Section 4 22 Weight mass approx Housing for panel surface mounting 9 9 lb or 4 5 kg Housing for panel surface mounting 8 8 lb or 4 0 kg Protection class acc to IEC 60529 For surface mounting housing equipment IP 51 In flush mounted housing Front IP 51 Rear IP 50 For personal protection IP 2x with cover cap UL conditions For use on...

Page 318: ...urrents ground for INom 1 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 ...

Page 319: ... setting value or 10 mA at 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 displace...

Page 320: ... 5 A 0 50 A to 20 00 A Pickup 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 Ip IEp for IEC characteristics 0 05 s to 3 20 s or disabled Increments 0 01 s Time multiplier T for Ip IEp for ANSI characteristics 0 50 s to 15 00 s or disabled Increments 0 01 s Acc to IEC 60255 3 or BS 142 Section 3 5 2 see also Figure 4 1 and 4 2...

Page 321: ... 1 05 setting value Ip for 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 INom 1 A or 50 mA for INom 5 A Pickup time for 2 I Ip 20 5 of reference calculated value 2 current tolerance respectively 30 ms Dropout time for I Ip 0 90 5 of reference calculated value 2 current toleran...

Page 322: ...ta 4 3 Inverse Time Overcurrent Protection 51 N SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 322 Figure 4 1 Dropout time and trip time curves of the inverse time overcurrent protection acc to IEC ...

Page 323: ...ta 4 3 Inverse Time Overcurrent Protection 51 N SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 323 Figure 4 2 Dropout time and trip time curves of the inverse time overcurrent protection acc to IEC ...

Page 324: ...2008 324 Trip Time Curves 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 ...

Page 325: ...ut Setting Acc to ANSI IEEE 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...

Page 326: ...up time for 2 I Ip 20 5 of reference calculated value 2 current tolerance respectively 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 ...

Page 327: ...4 3 Inverse Time Overcurrent Protection 51 N SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 327 Figure 4 3 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE ...

Page 328: ...4 3 Inverse Time Overcurrent Protection 51 N SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 328 Figure 4 4 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE ...

Page 329: ...4 3 Inverse Time Overcurrent Protection 51 N SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 329 Figure 4 5 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE ...

Page 330: ... 4 3 Inverse Time Overcurrent Protection 51 N SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 330 Figure 4 6 Dropout time and trip time curve of the inverse time overcurrent protection acc to ANSI IEEE ...

Page 331: ... I 10 to 45 Increments 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 IN...

Page 332: ...rent Control 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...

Page 333: ... 00 s to 60 00 s or no trip 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 I...

Page 334: ...sabled Increments 0 01 s 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 Po...

Page 335: ...e 46 TOC I2p for INom 1 A 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 ...

Page 336: ...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 Representation of the possible dropout time curves see figure 4 ...

Page 337: ... 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 131 00 F 55 C 0 5 10 K Frequency in range 0 95 f fNom 1 05 1 Harmonics up to 10 ...

Page 338: ...Data 4 8 Negative Sequence Protection 46 TOC SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 338 Figure 4 7 Trip time characteristics of the inverse time negative sequence element 46 TOC acc to IEC ...

Page 339: ... 4 8 Negative Sequence Protection 46 TOC SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 339 Figure 4 8 Dropout time and trip time characteristics of the inverse time unbalanced load stage acc to ANSI ...

Page 340: ... 4 8 Negative Sequence Protection 46 TOC SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 340 Figure 4 9 Dropout time and trip time characteristics of the inverse time unbalanced load stage acc to ANSI ...

Page 341: ...le startup time TMax STARTUP 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 STARTUP C 0 to 80 or disabled Increments 1 Dropout ratio Approx 0 95 Pickup Threshold 2 of set value or 10 ...

Page 342: ...T TIME 0 2 min to 120 0 min 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 ...

Page 343: ...00 s to 600 00 s Increments 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...

Page 344: ...INom 5 A 0 50 A to 20 00 A 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 o...

Page 345: ...Technical Data 4 12 Thermal Overload Protection 49 SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 345 Figure 4 10 Trip time curves for the thermal overload protection 49 ...

Page 346: ...1 50 mA Measurement Tolerance 2 of setting value or 1 mA Operating Time Tolerance 1 of setting value or 20 ms User defined Curve defined by a maximum of 20 value pairs of current and time delay Pickup Current 51Ns for sensitive transformer for normal 1 A transformer for normal 5 A transformer 0 001 A to 1 400 A 0 05 A to 4 00 A 0 25 A to 20 00 A Increments 0 001 A Increments 0 01 A Increments 0 05...

Page 347: ...1 A Increments 0 05 A Knee point time 51Ns T knee 0 20 s to 100 00 s Increments 0 01 s Pickup current 51Ns I T knee for sensitive transformer for normal 1 A transformer for normal 5 A transformer 0 003 A to 0 650 A 0 05 A to 17 00 A 0 25 A to 85 00 A Increments 0 001 A Increments 0 01 A Increments 0 05 A Maximum time 51Ns T max 0 00 s to 30 00 s Increments 0 01 s Time factor 51Ns TD 0 05 s to 1 50...

Page 348: ...02 2008 348 Logarithmic Inverse Trip Time Characteristics Figure 4 11 Trip time characteristics of inverse time ground fault protection with logarithmic inverse char acteristic 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 ...

Page 349: ...al C53000 G1140 C210 1 Release date 02 2008 349 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 ...

Page 350: ...ents 0 001 A Pickup extension time 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 A...

Page 351: ...ion of Dead Time Using binary input with time monitoring Blocking Duration 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 o...

Page 352: ... Pickup threshold 50N 1 BF 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 ...

Page 353: ... for INom 1 A 0 05 to 35 00 A Increments 0 01 A for INom 5 A 0 25 to 175 00 A Relationship I2 I1 15 to 100 Increments 1 Sensitive ground currentIGG 0 001 to 1 500 A Increments 0 001 A Pickup delay standard 0 00 to 60 00 s Increments 0 01 s Pickup delay for I2 I1 0 00 to 28800 00 s Increments 0 01 s Command delay time 0 00 to 3600 00 s Increments 0 01 s Dropout delay 0 00 to 60 00 s Increments 0 01...

Page 354: ...0 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 A 2 of setting value or 100 mA Current I2 I1 2 of setting value Times 1 of set 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 fNom 5 Hz 1 Harmonics up to 10 3rd har...

Page 355: ...le 2 or 3 phase connection 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 f...

Page 356: ...CMD_CANCEL Command cancelled 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...

Page 357: ...rsion X X X X RISE_DETECT Rise detector X X X X RS_FF RS Flipflop X X X RS_FF_MEMO RS Flipflop with state memory X X X SQUARE_ROOT Root Extractor X X X X SR_FF SR Flipflop X X X SR_FF_MEMO SR Flipflop with state memory X X X ST_AND AND gate with status X X X X ST_NOT Inverter with status X X X X ST_OR OR gate with status X X X X SUB Substraction X X X X TIMER Timer X X TIMER_SHORT Simple timer X X...

Page 358: ...ast valid pa rameter set and uses it for restarting Maximum number of all CFC charts considering one task level 16 When the limit is exceeded an error message is output by the device Consequently the device is put into monitoring mode The red ERROR LED lights up Maximum number of all CFC inputs considering all charts 400 When the limit is exceeded an error message is output by the device Consequen...

Page 359: ...6 Connection to an output 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 ...

Page 360: ...DIST_DECODE 8 UINT_TO_REAL 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 preconfigurati...

Page 361: ...5 8 Restart Threshold ΘRestart ΘL Trip in Reclose time TReclose in min RMS Current Value of Sensitive Ground Fault Detection INs in A kA primary and in mA secondary Range Tolerance 1 0 mA to 1600 mA 2 of measured value or 1 mA RTD Box See section RTD Boxes for Temperature Detection Time Window 5 15 30 or 60 minutes Frequency of Updates Adjustable Long Term Averages IAdmd IBdmd ICdmd I1dmd in A kA ...

Page 362: ...mum Time Deviation Internal Clock 0 01 Battery Lithium battery 3 V 1 Ah type CR 1 2 AA Message Battery Fault for insufficient battery charge maximum of 8 fault records saved memory maintained by buffer battery in case of loss of power supply Recording Time Total 20 s Pre event and post event recording and memory time adjustable Probing 16 samples instantaneous values per cycle Saved Number of Trip...

Page 363: ...eaker test by means of control function Creation of a test measurement report Time Synchronization DCF 77 IRIG B Signal telegram format IRIG B000 Binary Input Communication Operating Modes for Time Tracking No Operating Mode Explanations 1 Internal Internal synchronization using RTC presetting 2 IEC 60870 5 103 External synchronization using system interface IEC 60870 5 103 3 PROFIBUS FMS External...

Page 364: ...with protocol via system SCADA interface Binary Input The GOOSE communication service of IEC 61850 is qualified for switchgear interlocking The runtime of GOOSE messages with the protection relay picked up depends on the number of connected IEC 61850 cli ents As from version V4 6 of the devices applications with protective functions have to be checked with regard to their required runtime In indiv...

Page 365: ...y programmable interlocking 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 contro...

Page 366: ...PROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 366 4 22 Dimensions 4 22 1 Panel Flush and Cubicle Mounting Housing Size 1 3 Figure 4 13 Dimensional drawing of a 7SJ61 for panel flush and cubicle mounting housing size 1 3 ...

Page 367: ...ase date 02 2008 367 4 22 2 Panel Surface Mounting Housing Size 1 3 Figure 4 14 Dimensional drawing of a 7SJ61 for panel flush mounting housing size 1 3 4 22 3 Varistor Figure 4 15 Dimensional drawing of the varistor for voltage limiting in high impedance differential protection ...

Page 368: ...Technical Data 4 22 Dimensions SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 368 ...

Page 369: ...ow the proper connections 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 370 A 2 Terminal Assignments 376 A 3 Connection Examples 385 A 4 Current Transformer Requirements 391 A 5 Defaul...

Page 370: ... A min 0 05 A 15th position only with A 7 Auxiliary Voltage Power Supply Pickup Threshold of Binary Inputs Position 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 Construction Position 9 Surface mounting case for panel 2 tier terminals top bottom B Flush mounting case plug in terminals 2 3 p...

Page 371: ...Slave electrical RS485 4 Profibus FMS Slave Optical Single Ring ST 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 9 Additional information to further system interfaces Rear Side Port B Supple mentary PROFIBUS DP Slave RS 485 L 0 A Profibus DP Slave 820 nm Optical Double Ring ST Connector 1 L 0 B 1 ...

Page 372: ...ection 46 1 46 2 46 TOC 37 Undercurrent monitoring 50BF Breaker Failure Protection 74TC Trip Circuit Monitoring Cold load pickup dynamic setting changes 50C 1 50C 2 50NC 1 50NC 2 51NC Inrush restraint 86 Lock out IEF Intermittent ground fault P A 50Ns 51Ns 87N Sensitive ground fault detection High impedance ground fault differential protection F B 2 IEF 50Ns 51Ns 87N Sens ground fault detection In...

Page 373: ... A351 D613 1 Modbus RS485 C53207 A351 D621 1 Modbus 820 nm C53207 A351 D623 1 DNP 3 0 RS 485 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 RT...

Page 374: ...inal voltage 8 terminal current block C73334 A1 C32 1 Short Circuit Links Short circuit links for terminal type Order No Voltage terminal 18 terminal or 12 terminal C73334 A1 C34 1 Current terminal 12 terminal or 8 terminal C73334 A1 C33 1 Female Plugs Connector Type Order No 2 pin C73334 A1 C35 1 3 pin C73334 A1 C36 1 Mounting Rail for 19 Racks Name Order No Angle Strip Mounting Rail C73165 A63 C...

Page 375: ...bus setup with patch cables 2 core twisted shielded length 0 3 m 1x sub D pin 9 pole on 2x RJ45 sub miniature connector 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 l...

Page 376: ...IPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 376 A 2 Terminal Assignments A 2 1 Housing for Panel Flush and Cubicle Mounting 7SJ610 D E Figure A 1 Connection diagram for 7SJ610 D E panel flush mounted or cubicle mounted ...

Page 377: ...Appendix A 2 Terminal Assignments SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 377 7SJ611 D E Figure A 2 Connection diagram for 7SJ611 D E panel flush mounted or cubicle mounted ...

Page 378: ...ease date 02 2008 378 7SJ612 D E Figure A 3 Connection diagram for 7SJ612 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 ...

Page 379: ...x A 2 Terminal Assignments SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 379 A 2 2 Housing for Panel Surface Mounting 7SJ610 B Figure A 4 Connection diagram for 7SJ610 B panel surface mounted ...

Page 380: ...Appendix A 2 Terminal Assignments SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 380 7SJ611 B Figure A 5 Connection diagram for 7SJ611 B panel surface mounted ...

Page 381: ...C210 1 Release date 02 2008 381 7SJ612 B Figure A 6 Connection diagram for 7SJ612 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 ...

Page 382: ...TEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 382 A 2 3 Terminal Assignment on Housing for Panel Surface Mounting 7SJ610 1 2 B up to release CC Figure A 7 Connection diagram for 7SJ610 1 2 B up to release CC panel surface mounted ...

Page 383: ... 2 Terminal Assignments SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 383 7SJ610 1 2 B up to release DD Figure A 8 Connection diagram for 7SJ610 1 2 B release DD and higher panel surface mounted ...

Page 384: ...Appendix A 2 Terminal Assignments SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 384 A 2 4 Connector Assignment On the Interfaces On the Time Synchronization Interface ...

Page 385: ...A 3 1 Connection Examples for Current Transformers all Devices Figure A 9 Current connections to three current transformers with a starpoint connection for ground current residual 3I0 neutral current normal circuit layout Figure A 10 Current connections to two current transformers only for ungrounded or compensated networks ...

Page 386: ...verses 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 Figure A 12 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 ...

Page 387: ...ound current is taken via 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...

Page 388: ... 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 Figure A 15 High impedance differential protection for a grounded trans...

Page 389: ... Box all Devices Figure A 16 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 17 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 optionally port C or port D ...

Page 390: ...s SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 390 Figure A 18 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 ...

Page 391: ...e knee point voltage and 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 Resultin...

Page 392: ...S Classes TPX TPY TPZ K 1 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 vo...

Page 393: ...ding and function operating prin ciple For extremely small ground 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 li...

Page 394: ...511 Relay GENERAL TRIP command LED2 50 51 Ph A PU 1762 50 51 Phase A picked up LED3 50 51 Ph B PU 1763 50 51 Phase B picked up LED4 50 51 Ph C PU 1764 50 51 Phase C picked up LED5 50N 51NPickedup 1765 50N 51N picked up LED6 Failure Σ I 162 Failure Current Summation Fail I balance 163 Failure Current Balance Fail Ph Seq I 175 Failure Phase Sequence Current LED7 Not configured 1 No Function configur...

Page 395: ...elay TRIP 511 Relay GENERAL TRIP command 52Breaker 52 Breaker BO2 52Breaker 52 Breaker 79 Close 2851 79 Close command BO3 52Breaker 52 Breaker 79 Close 2851 79 Close command BO4 Failure Σ I 162 Failure Current Summation Fail I balance 163 Failure Current Balance Fail Ph Seq I 175 Failure Phase Sequence Current Binary Output Default function Function No Description BO7 Relay PICKUP 501 Relay PICKUP...

Page 396: ...f 7SJ61 for models without extended measured values 13th digit of MLFB 1 Page 3 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 de scription of Power System Data 1 Figure A 20 Default display of 7SJ61 for models with extended measured values 13th digit of MLFB 3 Pag...

Page 397: ...I A 5 6 Pre defined CFC Charts Some CFC Charts are already supplied with the SIPROTEC device Device and System Logic The NEGATOR block assigns the input signal DataStop directly to an output This is not directly possible without the interconnection of this block Figure A 22 Logical Link between Input and Output Set points MV Using modules on the running sequence measured value processing a low cur...

Page 398: ...ettings SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 398 Using modules on the running sequence measured value processing an additional overcurrent monitor is im plemented Figure A 24 Overcurrent monitoring ...

Page 399: ...ditional service interface 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 nou...

Page 400: ...abled Disabled 2nd Harmonic Inrush Restraint 127 50 1Ph Disabled Enabled Disabled 50 1Ph 131 Sens Gnd Fault Disabled Definite Time User Defined PU Log inverse A Log Inverse B Disabled sensitive Ground fault 133 INTERM EF Disabled with Ignd with 3I0 with Ignd sens Disabled Intermittent earth fault protection 140 46 Disabled TOC ANSI TOC IEC Definite Time Disabled 46 Negative Sequence Protection 141...

Page 401: ...nput 191 RTD CONNECTION 6 RTD simplex 6 RTD HDX 12 RTD HDX 6 RTD simplex Ext Temperature Input Connec tion Type FLEXIBLE FUNC 1 20 Flex Function 01 Flex Function 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 ...

Page 402: ... THRESHOLD Flx 0 001 1 500 A 0 100 A Pickup Threshold 0 P U THRESHOLD Flx 15 100 20 Pickup Threshold 0 T TRIP DELAY Flx 0 00 3600 00 sec 1 00 sec Trip Time Delay 0 T PICKUP DELAY Flx 0 00 60 00 sec 0 00 sec Pickup Time Delay 0A T DROPOUT DELAY Flx 0 00 60 00 sec 0 00 sec Dropout Time Delay 0A DROPOUT RATIO Flx 0 70 0 99 0 95 Dropout Ratio 0A DROPOUT RATIO Flx 1 01 3 00 1 05 Dropout Ratio 201 CT St...

Page 403: ...ange to Another Setting Group 401 WAVEFORMTRIGGER Osc Fault Rec Save w Pickup Save w TRIP Start w TRIP Save w Pickup Waveform Capture 402 WAVEFORM DATA Osc Fault Rec Fault event Pow Sys Flt Fault event Scope of Waveform Data 403 MAX LENGTH Osc Fault Rec 0 30 5 00 sec 2 00 sec Max length of a Waveform Capture Record 404 PRE TRIG TIME Osc Fault Rec 0 05 0 50 sec 0 25 sec Captured Waveform Prior to T...

Page 404: ...1 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 measurem 50 51 Overcur Fundamental True RMS Fundamental 50 1 measurement of 1222A 51 measurem 50 51 Overcur Fundamental True RMS Fundamental 51 measurement of 1230 51 51N 50 51 Overcur 1 00 20 00 I Ip 0 01 999 00 TD 51 51N 12...

Page 405: ...adPickup No Current Breaker Contact 79 ready No Current Start Condition 1703 CB Open Time ColdLoadPickup 0 21600 sec 3600 sec Circuit Breaker OPEN Time 1704 Active Time ColdLoadPickup 1 21600 sec 3600 sec Active Time 1705 Stop Time ColdLoadPickup 1 600 sec 600 sec Stop Time 1801 50c 2 PICKUP ColdLoadPickup 1A 0 10 35 00 A 10 00 A 50c 2 Pickup 5A 0 50 175 00 A 50 00 A 1802 50c 2 DELAY ColdLoadPicku...

Page 406: ...117 50Ns 1 PICKUP Sens Gnd Fault 1A 0 05 35 00 A 2 00 A 50Ns 1 Pickup 5A 0 25 175 00 A 10 00 A 3118 50Ns 1 DELAY Sens Gnd Fault 0 00 320 00 sec 2 00 sec 50Ns 1 Time delay 3119 51Ns PICKUP Sens Gnd Fault 0 001 1 400 A 0 100 A 51Ns Pickup 3119 51Ns PICKUP Sens Gnd Fault 0 003 0 500 A 0 004 A 51Ns Pickup 3119 51Ns PICKUP Sens Gnd Fault 1A 0 05 4 00 A 1 00 A 51Ns Pickup 5A 0 25 20 00 A 5 00 A 3120 51N...

Page 407: ...6 TOC Time Dial 4010 46 TOC TIMEDIAL 46 Negative Seq 0 05 3 20 sec 0 50 sec 46 TOC Time Dial 4011 46 TOC RESET 46 Negative Seq Instantaneous Disk Emulation Instantaneous 46 TOC Drop Out 4012A 46 T DROP OUT 46 Negative Seq 0 00 60 00 sec 0 00 sec 46 Drop Out Time Delay 4101 FCT 48 66 48 66 Motorprot OFF ON OFF 48 66 Motor Startup Moni tor Counter 4102 STARTUP CURRENT 48 66 Motorprot 1A 0 50 16 00 A...

Page 408: ...KUP 50BF BkrFailure 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 50BF BkrFailure 1A 0 05 20 00 A 0 10 A 50BF Pickup earth current threshold 5A 0 25 100 00 A 0 50 A 7101 FCT 79 79M Auto Recl OFF ON OFF 79 Auto Reclose Function 7103 BLOCK MC Dur 79M Auto Recl 0 50 320 00 sec 0 1 00 sec AR blocking duration after manual close 7105 TIME RESTRAINT 79M...

Page 409: ... 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 Starts 79 Stops 79 No influence 50N 3 7200 bef 1 Cy 50 1 79M Auto Recl Set ...

Page 410: ...instant T 0 blocked T Set value T T before 4 Cycle 50 1 7237 bef 4 Cy 50N 1 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 4 Cycle 50N 1 7238 bef 4 Cy 50 2 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 4 Cycle 50 2 7239 bef 4 Cy 50N 2 79M Auto Recl Set value T T instant T 0 blocked T Set value T T before 4 Cycle 50N 2 7240 bef 4 Cy 51 79M Auto Recl ...

Page 411: ...After Hour 45 After Hour On The Hour Demand Synchronization Time 8311 MinMax cycRESET Min Max meter NO YES YES Automatic Cyclic Reset Function 8312 MiMa RESET TIME Min Max meter 0 1439 min 0 min MinMax Reset Timer 8313 MiMa RESETCYCLE Min Max meter 1 365 Days 7 Days MinMax Reset Cycle Period 8314 MinMaxRES START Min Max meter 1 365 Days 1 Days MinMax Start Reset Cycle in 8315 MeterResolution Energ...

Page 412: ...0 C RTD 4 Temperature Stage 1 Pickup 9044 RTD 4 STAGE 1 RTD Box 58 482 F 212 F RTD 4 Temperature Stage 1 Pickup 9045 RTD 4 STAGE 2 RTD Box 50 250 C 120 C RTD 4 Temperature Stage 2 Pickup 9046 RTD 4 STAGE 2 RTD Box 58 482 F 248 F RTD 4 Temperature Stage 2 Pickup 9051A RTD 5 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 5 Type 9052A RTD 5 LOCATION RTD Box Oil Ambient Windin...

Page 413: ...0 C RTD 8 Temperature Stage 1 Pickup 9084 RTD 8 STAGE 1 RTD Box 58 482 F 212 F RTD 8 Temperature Stage 1 Pickup 9085 RTD 8 STAGE 2 RTD Box 50 250 C 120 C RTD 8 Temperature Stage 2 Pickup 9086 RTD 8 STAGE 2 RTD Box 58 482 F 248 F RTD 8 Temperature Stage 2 Pickup 9091A RTD 9 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 9 Type 9092A RTD 9 LOCATION RTD Box Oil Ambient Windin...

Page 414: ...2 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 Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD12 Type 9122A RTD12 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD12 Location 9123 RTD12 STAGE 1 RTD Box 50 250 C 10...

Page 415: ...r allocatable No Description 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 Gene...

Page 416: ...tch 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 Control Device CF_D 2 On Off LED BO 240 162 20 Q2 Open Close Q2 Op Cl Control Device DP On Off BI CB 240 162 1 Yes Q9 ...

Page 417: ...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 Off LED BO 009 0102 Failure EN100 Link Channel 2 Ch2 Fail Ch2 EN100 Modul 1 IntSP On Off LED BO 15 Test mode Test mode Device General SP LED...

Page 418: ... 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 175 Failure Phase Sequence Current Fail Ph Seq I Measurem Superv OUT On Off LED BO 135 191 1 Yes 177 Failure Battery empty Fail Bat tery Device General OUT On Off LED BO 178 I O Board Er...

Page 419: ...5 2117 Function 00 BLOCK TRIP Phase C 00 BL TripC Flx SP On Off On Off LED BI FC TN BO 235 2118 Function 00 is BLOCKED 00 BLOCKED Flx OUT On Off On Off LED BO 235 2119 Function 00 is switched OFF 00 OFF Flx OUT On Off LED BO 235 2120 Function 00 is ACTIVE 00 ACTIVE Flx OUT On Off LED BO 235 2121 Function 00 picked up 00 picked up Flx OUT On Off On Off LED BO 235 2122 Function 00 Pickup Phase A 00 ...

Page 420: ... 6 1 Yes 395 I MIN MAX Buffer Reset I MinMax Reset Min Max meter SP on LED BI BO 396 I1 MIN MAX Buffer Reset I1 MiMaReset Min Max meter SP on LED BI BO 403 Idmd MIN MAX Buffer Reset Idmd MiMaReset Min Max meter SP on LED BI BO 409 BLOCK Op Counter BLOCK Op Count Statistics SP On Off LED BI BO 412 Theta MIN MAX Buffer Reset Θ MiMa Reset Min Max meter SP on LED BI BO 501 Relay PICKUP Relay PICKUP P ...

Page 421: ...Sens Gnd Fault OUT On Off LED BO 151 127 2 Yes 1229 51Ns TRIP 51Ns TRIP Sens Gnd Fault OUT on m LED BO 151 129 2 Yes 1230 Sensitive ground fault detection BLOCKED Sens Gnd block Sens Gnd Fault OUT On Off On Off LED BO 151 130 1 Yes 1403 BLOCK 50BF BLOCK 50BF 50BF BkrFailure SP On Off LED BI BO 166 103 1 Yes 1431 50BF initiated externally 50BF ext SRC 50BF BkrFailure SP On Off LED BI BO 166 104 1 Y...

Page 422: ... 50 1 BLOCK 50 1 50 51 Overcur SP LED BI BO 60 2 1 Yes 1723 BLOCK 51 BLOCK 51 50 51 Overcur SP LED BI BO 60 3 1 Yes 1724 BLOCK 50N 2 BLOCK 50N 2 50 51 Overcur SP LED BI BO 60 4 1 Yes 1725 BLOCK 50N 1 BLOCK 50N 1 50 51 Overcur SP LED BI BO 60 5 1 Yes 1726 BLOCK 51N BLOCK 51N 50 51 Overcur SP LED BI BO 60 6 1 Yes 1730 BLOCK Cold Load Pickup BLOCK CLP ColdLoadPickup SP LED BI BO 1731 BLOCK Cold Load ...

Page 423: ...LED BO 60 57 2 Yes 1825 51 TRIP 51 TRIP 50 51 Overcur OUT on m LED BO 60 58 2 Yes 1831 50N 2 picked up 50N 2 picked up 50 51 Overcur OUT On Off LED BO 60 59 2 Yes 1832 50N 2 Time Out 50N 2 TimeOut 50 51 Overcur OUT LED BO 60 60 2 Yes 1833 50N 2 TRIP 50N 2 TRIP 50 51 Overcur OUT on m LED BO 160 93 2 No 1834 50N 1 picked up 50N 1 picked up 50 51 Overcur OUT On Off LED BO 60 62 2 Yes 1835 50N 1 Time ...

Page 424: ...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 coordi nation OFF ZSC OFF 79M Auto Recl SP On Off LED BI BO 2730 Circuit breaker RE...

Page 425: ...62 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 phase reclosing se quence 79 L L Sequence 79M Auto Re...

Page 426: ...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 Negative...

Page 427: ...Yes 6822 Rotor locked Rotor locked 48 66 Motorprot OUT on LED BO 169 55 2 Yes 6823 Startup supervision Pickup START SUP pu 48 66 Motorprot OUT On Off LED BO 169 56 1 Yes 6851 BLOCK 74TC BLOCK 74TC 74TC TripCirc SP LED BI BO 6852 74TC Trip circuit superv trip relay 74TC trip rel 74TC TripCirc SP On Off LED BI BO 170 51 1 Yes 6853 74TC Trip circuit superv bkr relay 74TC brk rel 74TC TripCirc SP On O...

Page 428: ...InRush OFF InRush OFF 50 51 Overcur OUT On Off LED BO 60 92 1 Yes 7557 InRush BLOCKED InRush BLK 50 51 Overcur OUT On Off On Off LED BO 60 93 1 Yes 7558 InRush Ground detected InRush Gnd Det 50 51 Overcur OUT On Off LED BO 60 94 2 Yes 7563 BLOCK InRush BLOCK InRush 50 51 Overcur SP LED BI BO 7564 Ground InRush picked up Gnd InRush PU 50 51 Overcur OUT On Off LED BO 60 88 2 Yes 7565 Phase A InRush ...

Page 429: ...t 3 StartupCurrent3 Mot Statistics VI 10042 Startup Voltage 3 StartupVoltage3 Mot Statistics VI 10043 Startup Duration 4 StartDuration4 Mot Statistics VI 10044 Startup Current 4 StartupCurrent4 Mot Statistics VI 10045 Startup Voltage 4 StartupVoltage4 Mot Statistics VI 10046 Startup Duration 5 StartDuration5 Mot Statistics VI 10047 Startup Current 5 StartupCurrent5 Mot Statistics VI 10048 Startup ...

Page 430: ... RTD 7 Temperature stage 1 picked up RTD 7 St 1 p up RTD Box OUT On Off LED BO 14173 RTD 7 Temperature stage 2 picked up RTD 7 St 2 p up RTD Box OUT On Off LED BO 14181 Fail RTD 8 broken wire shorted Fail RTD 8 RTD Box OUT On Off LED BO 14182 RTD 8 Temperature stage 1 picked up RTD 8 St 1 p up RTD Box OUT On Off LED BO 14183 RTD 8 Temperature stage 2 picked up RTD 8 St 2 p up RTD Box OUT On Off LE...

Page 431: ...P C Statistics VI 16014 Sum Squared Current Integral Phase A ΣI 2t A Statistics VI 16015 Sum Squared Current Integral Phase B ΣI 2t B Statistics VI 16016 Sum Squared Current Integral Phase C ΣI 2t C Statistics VI 16018 Threshold Sum Squa Curr Int exceeded Thresh ΣI 2t SetPoint Stat OUT On Off LED BO 16019 52 Breaker Wear Start Criteria 52 Wear start P System Data 2 SP On Off LED BI BO 16020 52 Wea...

Page 432: ... 31009 Q9 operationcounter Q9 OpCnt Control Device VI No Description 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 ...

Page 433: ...83 184 185 186 187 188 189 191 193 Error 5V Error 0V Error 5V Error PwrSupply Fail Battery I O Board 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 162 163 175 264 267 Failure Σ I Fail I balance Fail Ph Seq I Fail RTD Box 1 Fail RTD Box 2 161 Fail I Superv 162 163 Failure Σ I Fail I balance ...

Page 434: ...nt CFC CD DD 830 INs Senstive Ground Fault Current INs Measurement CFC CD DD 831 3Io zero sequence 3Io Measurement CFC CD DD 833 I1 positive sequence Demand I1 dmd Demand meter CFC CD DD 837 I A Demand Minimum IAdmdMin Min Max meter CFC CD DD 838 I A Demand Maximum IAdmdMax Min Max meter CFC CD DD 839 I B Demand Minimum IBdmdMin Min Max meter CFC CD DD 840 I B Demand Maximum IBdmdMax Min Max meter...

Page 435: ... Temperature of RTD 7 Θ RTD 7 Measurement 134 146 No 9 7 CFC CD DD 1075 Temperature of RTD 8 Θ RTD 8 Measurement 134 146 No 9 8 CFC CD DD 1076 Temperature of RTD 9 Θ RTD 9 Measurement 134 146 No 9 9 CFC CD DD 1077 Temperature of RTD10 Θ RTD10 Measurement 134 146 No 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 1...

Page 436: ...Appendix A 11 Measured Values SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 436 ...

Page 437: ...C 4 System Description E50417 H1140 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 e C53000 B1174 C158 ...

Page 438: ...Literature SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 438 ...

Page 439: ...bytes BP_xx Bit pattern indication 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 pur...

Page 440: ...ch a con tainer Control display 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...

Page 441: ...nd moved from one data area 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 ...

Page 442: ... is sampled This information 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 ...

Page 443: ...nd sub modules using ModPara 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 intermedi...

Page 444: ...nd scope of the information 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 dev...

Page 445: ...oth partners of a modem connection 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 initializa tion 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...

Page 446: ...C 4 device Phone book User 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 PRO...

Page 447: ...face on the devices for connecting 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 su...

Page 448: ...device as the source object 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 Top...

Page 449: ...communication objects and 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 ...

Page 450: ...Glossary SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 450 ...

Page 451: ...ace 285 Checking System SCADA interface 286 Checking System Connections 288 Checking Termination 286 Checking Time Synchronization Interface 287 Checking User Defined Functions 297 Circuit Breaker Maintenance 363 Circuit Breaker Monitoring 169 Circuit Breaker Status Recognition 168 Climatic Stress Tests 316 Clock 363 Commissioning Aids 363 Communication Interfaces 309 Construction Panel Surface Mo...

Page 452: ...rent Protection 55 Inverse Time Overcurrent Protection 51 N 320 L Limits for CFC blocks 358 Limits for User defined Functions 358 Load Jam Protection 343 Local Measured Values Monitoring 362 Long Term Averages 361 M Malfunction Responses of the Monitoring Functions 144 Measurement Supervision 134 Mechanical Stress Tests 315 Min Max report 361 Minimum Inhibit Time 109 Monitoring of the Circuit Brea...

Page 453: ...TD Boxes 355 Temperature Detectors 355 Temperatures 316 Terminating the Trip Signal 212 Termination 286 Termination of Bus capable Interfaces 263 Test System Interface 291 Thermal Overload Protection 49 344 Thermal replica 124 Thresholds for Temperature Indications 355 Time Allocation 362 Time Overcurrent Protection 48 Time overcurrent protection Pickup value 88 Transformer data 88 Time Overcurren...

Page 454: ...Index SIPROTEC 7SJ61 Manual C53000 G1140 C210 1 Release date 02 2008 454 ...

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