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Siemens SIPROTEC 7SD610, Manual

The Siemens SIPROTEC 7SD610 is a state-of-the-art protective relay offering advanced functionality for secure power system protection. Ensure optimal operation and configuration with our comprehensive user manual, available for free download at manualshive.com. Access the manual now and maximize the potential of your Siemens SIPROTEC 7SD610.

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SIPROTEC

Differential Protection
7SD610

V4.70

Manual

C53000-G1176-C145-6

Preface

Contents

Introduction

1

Functions

2

Mounting and Commissioning

3

Technical Data

4

Appendix

A

Literature

Glossary

Index

Summary of Contents for SIPROTEC 7SD610

Page 1: ...SIPROTEC Differential Protection 7SD610 V4 70 Manual C53000 G1176 C145 6 Preface Contents Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Appendix A Literature Glossary Index ...

Page 2: ...ions We appreciate any suggestions for improvement We reserve the right to make technical improvements without notice Document Version V04 40 01 Release date 02 2011 Copyright Copyright Siemens AG 2011 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 damag...

Page 3: ...ective protection equipment automatic and control facilities and personnel of electrical facilities and power plants Applicability of this Manual This manual applies to SIPROTEC 4 Differential Protection 7SD610 firmware version V4 70 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 rel...

Page 4: ...e local Siemens rep resentative Our Customer Support Center provides a 24 hour service Phone 49 180 524 7000 Fax 49 180 524 2471 E mail support energy siemens com Training Courses Enquiries regarding individual training courses should be addressed to our Training Center Siemens AG Siemens Power Academy TD Humboldt Street 59 90459 Nuremberg Phone 49 911 433 7005 Fax 49 911 433 7929 Internet www sie...

Page 5: ...nd 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 r...

Page 6: ...proved 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 be g...

Page 7: ...ay 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 may ...

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

Page 9: ...1 2 1 3 4 Information List 41 2 1 4 General Protection Data Power System Data 2 42 2 1 4 1 Setting Notes 42 2 1 4 2 Settings 47 2 1 4 3 Information List 48 2 2 Protection Data Interfaces and Protection Data Topology 50 2 2 1 Functional Description 50 2 2 1 1 Protection Data Topology Protection Data Communication 50 2 2 2 Operating Modes of the Differential Protection 53 2 2 2 1 Mode Log Out Device...

Page 10: ...n List 89 2 6 Direct Local Trip 90 2 6 1 Method of Operation 90 2 6 2 Setting Notes 90 2 6 3 Settings 91 2 6 4 Information List 91 2 7 Transmission of Binary Commands and Messages 92 2 7 1 Function Description 92 2 7 2 Information List 93 2 8 Instantaneous High Current Switch onto Fault Protection SOTF 95 2 8 1 Function Description 95 2 8 2 Setting Notes 97 2 8 3 Settings 99 2 8 4 Information List...

Page 11: ...etting Notes 190 2 13 3 Settings 193 2 13 4 Information List 194 2 14 Thermal Overload Protection 195 2 14 1 Method of Operation 195 2 14 2 Setting Notes 196 2 14 3 Settings 198 2 14 4 Information List 198 2 15 Monitoring Functions 199 2 15 1 Measurement Supervision 199 2 15 1 1 Hardware Monitoring 199 2 15 1 2 Software Monitoring 201 2 15 1 3 Measurement Circuit Monitoring 201 2 15 1 4 Monitoring...

Page 12: ...2 16 4 3 Information List 242 2 17 Additional Functions 243 2 17 1 Commissioning aid 243 2 17 1 1 Function Description 243 2 17 1 2 Setting Notes 245 2 17 2 Processing of Messages 246 2 17 2 1 Function Description 246 2 17 3 Statistics 249 2 17 3 1 Function Description 249 2 17 3 2 Information List 250 2 17 4 Measurement During Operation 251 2 17 4 1 Function Description 251 2 17 4 2 Information L...

Page 13: ...ounting 287 3 1 3 3 Panel Mounting 288 3 2 Checking Connections 289 3 2 1 Checking Data Connections of Serial Interfaces 289 3 2 2 Checking the Protection Data Communication 292 3 2 3 Checking the System Connections 293 3 3 Commissioning 295 3 3 1 Test Mode Transmission Block 296 3 3 2 Test Time Synchronisation Interface 296 3 3 3 Testing the System Interface 297 3 3 4 Checking the switching state...

Page 14: ...h onto Fault Protection SOTF 343 4 8 Backup Time Overcurrent Protection 344 4 9 Automatic Reclosure optional 351 4 10 Voltage Protection optional 352 4 11 Frequency Protection optional 355 4 12 Circuit Breaker Failure Protection optional 356 4 13 Thermal Overload Protection 357 4 14 Monitoring Functions 359 4 15 User defined functions CFC 360 4 16 Auxiliary functions 364 4 17 Dimensions 367 4 17 1...

Page 15: ...A 4 2 Binary Input 382 A 4 3 Binary Output 382 A 4 4 Function Keys 383 A 4 5 Default Display 383 A 4 6 Pre defined CFC Charts 384 A 5 Protocol dependent Functions 385 A 6 Functional Scope 386 A 7 Settings 387 A 8 Information List 397 A 9 Group Alarms 424 A 10 Measured Values 425 Literature 429 Glossary 431 Index 443 ...

Page 16: ...Contents SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 16 ...

Page 17: ...Release date 02 2011 17 Introduction 1 The SIPROTEC 4 7SD610 is introduced in this chapter The device is presented in its application characteris tics and functional scope 1 1 Overall Operation 18 1 2 Application Scope 21 1 3 Characteristics 24 ...

Page 18: ...Figure 1 1 shows the basic structure of the device Analog Inputs The measuring inputs MI convert the currents and voltages coming from the instrument transformers and adapt them to the level appropriate for the internal processing of the device The device has 4 current and 4 voltage inputs Three current inputs are provided for measurement of the phase currents a further measuring input I4 may be u...

Page 19: ...ns Formation of the local differential protection values phasor analysis and charge current computation and creation of the transmission protocol Decoding of the received transmission protocol synchronisation of the differential protection values and summing up of the overall differential currents and the overall charge Monitoring the communication with the device of the remote end Monitoring of l...

Page 20: ...can be realized via additional interface modules The operator or service interface allows the communication during commissioning checking and also during operation using a standard browser via a communication network For this application a special tool the WEB Monitor is provided This tool has been optimized for distance protection Protection Data Interface The protection data interface is a parti...

Page 21: ...nctions Recognition of short circuits in the protection zone even of weak current or high resistive shorting is the basic function of the device Even complex multiphase faults are precisely detected as the measured values are evaluated phase segregated The protection system is restrained against inrush currents of power trans formers When switching onto a fault at any point of a line an undelayed ...

Page 22: ...ary equipment can be restricted by appropriate settings for the switching authority remote or local and by the operating mode interlocked non interlocked with or without password validation Interlocking conditions for switching e g switchgear interlocking can be established using the integrated user defined logic Indications and Measured Values Fault Recording The operational indications provide i...

Page 23: ...d the DIGSI operating software e g to operate several devices via a central PC The system interface is used for central communication between the device and a control center It can be op erated through the RS232 the RS485 or the FO port Several standardized protocols are available for data transmission An EN 100 module allows integrating the devices into 100 MBit Ethernet communication net works o...

Page 24: ...in case of weakly loaded system extreme stability against load jumps and power swings Phase selective measurement ensures that the pickup sensitivity is independent of the fault type Suited for transformers in the protected zone order variant Detection of high resistance weak current faults due to high sensitivity of the protection functions Insensitive to inrush and charging currents also for tra...

Page 25: ...hase currents and earth current For inverse time overcurrent protection select from various characteristics based on several standards Blocking capability e g for reverse interlocking with any stage Instantaneous tripping by any stage when switching onto a fault High Current Switch onto Fault Protection Fast tripping for all faults on 100 line length Selectable for manual closure or following each...

Page 26: ... frequency limits and delay times that are independently adjustable Very insensitive to harmonics and abrupt phase angle changes Large frequency range approx 25 Hz to 70 Hz Circuit Breaker Failure Protection optional With definite time current stages for monitoring the current flow through every pole of the circuit breaker Separate pickup thresholds for phase and earth currents Independent timers ...

Page 27: ...cuit breaker position and of the interlocking conditions for switching operations Monitoring Functions Availability of the device is greatly increased because of self monitoring of the internal measurement circuits power supply hardware and software Monitoring of the current and voltage transformer secondary circuits by means of summation and symmetry checks Monitoring of communication with statis...

Page 28: ...he data for fault recording for a maximum time range of 30 s synchronized between the devices of the differential protection system Switching statistics Counting of the trip and close commands issued by the device as well as recording of the fault current data and accumulation of the interrupted fault currents Communication with central control and memory components possible via serial interfaces ...

Page 29: ...ta Topology 50 2 3 Differential Protection 65 2 4 Breaker Intertrip and Remote Tripping 78 2 5 Restricted Earth Fault Protection optional 82 2 6 Direct Local Trip 90 2 7 Transmission of Binary Commands and Messages 92 2 8 Instantaneous High Current Switch onto Fault Protection SOTF 95 2 9 Backup Time Overcurrent Protection 100 2 10 Automatic Reclosure Function optional 125 2 11 Undervoltage and Ov...

Page 30: ...is comprises e g nominal system data nominal data of instrument transformers po larity and connection type of measured values The above information is sufficient to describe the protected object to the device s main protection function i e the differential protection For the other protection functions e g overcurrent time protection you select what measured values will be processed and in which wa...

Page 31: ...l Trip address 122 DTT Direct Trip is a command that is initiated from an external device for tripping the local circuit breaker At address 126 Back Up O C you can set the characteristic group which the time overcurrent protection uses for operation In addition to the definite time overcurrent protection definite time an inverse time overcurrent protection can be configured that either operates ac...

Page 32: ...p command disappears This operating mode enables making the dead times dependent on the type of fault also for three pole reclosure cycles Tripping is always three pole The setting Trip with T action with action time provides an action time for each auto reclose cycle The action time is started by a general pickup of all protection functions If there is no trip command yet when the action time has...

Page 33: ...AR cycles 8 AR cycles ADT Disabled Disabled Auto Reclose Function 134 AR control mode Pickup w Tact Pickup w o Tact Trip w Tact Trip w o Tact Trip w o Tact Auto Reclose control mode 136 FREQUENCY Prot Disabled Enabled Disabled Over Underfrequency Protection 137 U O VOLTAGE Disabled Enabled Enabl w comp Disabled Under Overvoltage Protection 139 BREAKER FAILURE Disabled Enabled enabled w 3I0 Disable...

Page 34: ...nput IE Figure 2 1 Polarity of current transformers Nominal Values of Transformers In principle the differential protection does not require any measured voltage However voltages can be con nected These voltages allow to display and log voltages and to calculate various components of power If nec essary they can also serve for determining the life line condition in case of automatic reclosure Duri...

Page 35: ...it is used for scaling the measured data and fault recording data Connection of the Currents The device features four current measurement inputs three of which are connected to the set of current trans formers Various possibilities exist for the fourth current input I4 Connection of the I4 input to the earth current in the starpoint of the set of current transformers on the pro tected feeder norma...

Page 36: ...a circuit breaker test cycle is issued via the device It must be long enough to ensure that the circuit breaker has securely closed There is no risk in setting this time too long as the close command will in any event be terminated following a new trip command from a protection function This parameter can only be altered using DIGSI under Addition al Settings Circuit breaker test The 7SD610 allows...

Page 37: ...1 K_ALF K_ALF_N The CT error at rated current plus a safety margin is set at address 253 E ALF ALF_N It is equal to the current measuring deviation for primary nominal current intensity F1 according to VDE 0414 Part 1 or IEC 60044 It is 3 for a 5P transformer 5 for a 10P transformer The CT error at rated accuracy limit factor plus a safety margin is set at address 254 E K_ALF_N It is derived from ...

Page 38: ...ing to the above table address 251 is to be set to 1 5 if the calculated value is higher than 1 5 This results in the following setting values Address 251 K_ALF K_ALF_N 1 50 Address 253 E ALF ALF_N 3 0 Address 254 E K_ALF_N 10 0 The presettings correspond to current transformers 10P with rated burden Of course only those settings are reasonable where address 253 E ALF ALF_N is set lower than addre...

Page 39: ... the setting values as discussed in Section 2 1 4 under Topological Data for Transformers optional 2 1 2 2 Settings Addresses which have an appended A can only be changed with DIGSI under Additional Settings Addr Parameter Setting Options Default Setting Comments 201 CT Starpoint towards Line towards Busbar towards Line CT Starpoint 203 Unom PRIMARY 0 4 1200 0 kV 400 0 kV Rated Primary Voltage 204...

Page 40: ...selected scope of functions is the same for all groups Setting groups enable the user to save the corresponding settings for each application When they are needed settings may be loaded quickly All setting groups are stored in the relay Only one setting group may be active at a given time 220 I4 transformer Not connected In prot line IY starpoint In prot line I4 current transformer is 221 I4 Iph C...

Page 41: ...to the delivery state and how to switch between setting groups during operation please refer to the SIPROTEC 4 System Description Two binary inputs enable changing between the 4 setting groups from an external source 2 1 3 3 Settings 2 1 3 4 Information List Addr Parameter Setting Options Default Setting Comments 301 ACTIVE GROUP Group A Group B Group C Group D Group A Active Setting Group is 302 ...

Page 42: ...bject since it is the basis for the current com parison at the ends General line data The directional values power power factor work and related min max mean and setpoint values calculated in the operational measured values are usually defined with positive direction towards the protected object This requires that the connection polarity for the entire device was configured accordingly in the P Sy...

Page 43: ...of that winding but the voltage that corresponds to the mean value of the currents at the ends of the control range of the tap changer In this way the fault currents caused by voltage control are minimised Calculation example Transformer YNd5 35 MVA 110 kV 25 kV Y winding with tap changer 10 For the regulated winding 110 kV this results in Maximum voltage Umax 121 kV Minimum voltage Umin 99 kV Vol...

Page 44: ...cesses the status of the circuit breaker auxiliary contacts and contains also a detection based on the measured currents and voltages for opening and closing see also Section 2 16 1 In address 1130 the residual current PoleOpenCurrent is set which will definitely not be exceeded when the circuit breaker pole is open If parasitic currents e g through induction can be excluded when the circuit break...

Page 45: ... for the circuit breaker test and for the automatic reclosure to indicate the CB switching status The other binary inputs CB No 351 to 353 379 and 380 are used for detecting the status of the line address 1134 and for reset of the trip command address 1135 Address 1135 is also used by other protection functions e g energization in case of overcurrent etc For use with one circuit breaker only both ...

Page 46: ...ted within the tripping region and a further fault for example by overcurrent is recognized Even if a single phase trip command has already been issued each further fault detection will lead to three pole coupling of the trip outputs If on the other hand this address is set to with TRIP three pole coupling of the trip output three pole trip ping only occurs when more than one pole is tripped There...

Page 47: ...ly used 2 1 4 2 Settings Addresses which have an appended A can only be changed with DIGSI under Additional Settings The table indicates region specific presettings Column C configuration indicates the corresponding second ary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 1103 FullScaleVolt 0 4 1200 0 kV 400 0 kV Measurement Full Scale Voltage...

Page 48: ...n Cl 0 01 30 00 sec 0 30 sec Seal in Time after MANUAL closures 1151 SYN MAN CL w o Sync check NO NO Manual CLOSE COMMAND generation 1152 Man Clos Imp Setting options depend on configuration None MANUAL Closure Impulse after CONTROL 1155 3pole coupling with PICKUP with TRIP with TRIP 3 pole coupling 1156A Trip2phFlt 3pole 1pole leading Ø 1pole lagging Ø 3pole Trip type with 2phase faults 1161 VECT...

Page 49: ... Relay PICKUP E OUT Relay PICKUP Earth 507 Relay TRIP L1 OUT Relay TRIP command Phase L1 508 Relay TRIP L2 OUT Relay TRIP command Phase L2 509 Relay TRIP L3 OUT Relay TRIP command Phase L3 510 Relay CLOSE OUT Relay GENERAL CLOSE command 511 Relay TRIP OUT Relay GENERAL TRIP command 512 Relay TRIP 1pL1 OUT Relay TRIP command Only Phase L1 513 Relay TRIP 1pL2 OUT Relay TRIP command Only Phase L2 514...

Page 50: ...ata interface transmitter receiver Communication media Communication can be effected via different communication connections Which kind of media is used depends on the distance and on the communication media available For shorter distances a direct connection via optical fibres with a transmission rate of 512 kBit s is possible Otherwise we recommend communication con verters A transmission via mo...

Page 51: ... to the next As a result it is not possible to obtain a definite tripping time Figure 2 5 Examples for communication connections Establishing the protection data communication When the devices of a differential protection system are linked to each other and switched on they communi cate by themselves The successful connection is indicated e g with Rel2 Login when device 1 has de tected device 2 Ea...

Page 52: ...ime period this is regarded as a transmission failure A corresponding alarm is output PI1 Datafailure No 3230 Oth erwise the same reactions apply as for the data disturbance Operating time jumps that for example can occur in case of switchings in the communication network can be recognized alarm PI1 jump No 3254 and corrected by the device The differential protection system con tinues to operate w...

Page 53: ...urrents are included in the logic as differential currents The behaviour is now comparable to a time overcurrent protection The set thresholds for the differential current now evaluate the local current A device can be logged out and on as described below Using the integrated keypad Menu Control Taggings Set Logout Via DIGSI Control Taggings Logout local device Via binary inputs No 3452 Logout ON ...

Page 54: ...e is to be logged on to the line protection system Logout off or Logout OFF the following is checked Is the local circuit breaker open Is the device not operating in differential protection test mode If all requirements are met the request is accepted and the indication Logout OFF No 3484 is generated According to the request source either the indication Logout ON off OFF No 3459 or Logout ON offB...

Page 55: ...cal device can now also be tested The test mode can be activated deactivated as follows Using the integrated keypad Menu Control Taggings Set Test mode Via binary inputs No 3197 Test Diff ON No 3198 Test Diff OFF if this was allocated In DIGSI with Control Taggings Diff Test mode The test mode status of the other device of the line protection system is indicated on the local device by the indicati...

Page 56: ...ntial protection test mode Figure 2 10 Principle for external switch wiring for controlling the differential protection test mode S Switch Activating deactivating differential protection test mode 1 Binary input as NO contact 2 Binary input as NC contact If a test switch is to be used for changing to test mode we recommed the following procedure Block the differential protection via a binary input...

Page 57: ...ol Taggings Set Commissioning mode Via binary inputs No 3260 Comm Diff ON No 3261 Comm Diff OFF if this was allocated In DIGSI with Control Taggings Diff Commissioning mode Principle of function In the following the logic is shown in a simplified way Figure 2 11 Logic diagram of the commissioning mode There are two ways to set the commissioning mode The first way is to use a command commissioning ...

Page 58: ...ential protection commissioning mode Bu1 Button Deactivating differential protection commissioning mode Bu2 Button Activating differential protection commissioning mode Figure 2 13 External switch wiring for controlling the differential protection commissioning mode S Switch Activating deactivating differential protection commissioning mode 1 Binary input as NO contact 2 Binary input as NC contact...

Page 59: ...512 KBit s X 21 or communication converter for 2 MBit s G703 E1 T1 IEEE C37 94 i e communication network connection with 1 2 4 or 8 slots The setting options depend on the parameterization of the functional scope and on the device variant The data must be identical at both ends of a communication route The setting depends on the properties of the communication medium Generally the response time of...

Page 60: ...after a communication failure PI1 SYNCMODE GPS SYNC OFF means that no GPS synchronisation is available at this protection data in terface This makes sense if no runtime differences are expected e g fibre optic connection The value pa rameterized at address 4506 PROT 1 UNSYM is considered by the differential protection when calculating the restraint current PI1 SYNCMODE TEL and GPS means that the d...

Page 61: ...nerated by an external GPS receiver The 1 PPS signal is connected to port A of the device see Chapter 3 Table 3 12 The 1 PPS signal has the property that the leading edge presents a maximum deviation of 10 μs compared between 2 GPS receivers and under all GPS signal conditions This feature does not depend on the location If the deviation of max 10 μs is no longer ensured due to bad GPS receiving c...

Page 62: ...7 PI1 Data reflec OUT Prot Int 1 Own Datas received 3227 PI1 light off SP Prot Int 1 Transmitter is switched off 3229 PI1 Data fault OUT Prot Int 1 Reception of faulty data 3230 PI1 Datafailure OUT Prot Int 1 Total receiption failure 3233 DT inconsistent OUT Device table has inconsistent numbers 3234 DT unequal OUT Device tables are unequal 3235 Par different OUT Differences between common paramet...

Page 63: ...the com munication system The ID number thus identifies the devices in the communication system according to a device address since the exchange of information between several differential protection systems thus also for several protected objects can be executed via the same communication system If you work with different physical interfaces and communication links please make sure that every pro...

Page 64: ...meter 1106 is only displayed if parameter 143 is set to yes Address 112 DIFF PROTECTION exists 2 2 4 2 Settings 2 2 4 3 Information List Addr Parameter Setting Options Default Setting Comments 4701 ID OF RELAY 1 1 65534 1 Identification number of relay 1 4702 ID OF RELAY 2 1 65534 2 Identification number of relay 2 4710 LOCAL RELAY relay 1 relay 2 relay 1 Local relay is No Information Type of In f...

Page 65: ...suring element M which is connected to the electrical balance point remains at zero current in healthy operation When a fault occurs in the zone limited by the transformers a current i1 i2 which is proportional to the fault currents I1 I2 flowing in from both sides is fed to the measuring element As a result the simple circuit shown in Figure 2 15 ensures a reliable tripping of the protection if t...

Page 66: ...d against one another charging currents are flowing even in healthy operation and cause a difference of currents at the ends of the protected zone Espe cially when cables are used the capacitive charging currents can reach considerable magnitude Charging currents do not depend on the intensity of the measured currents In healthy operation they can be considered as being almost constant under stead...

Page 67: ...witched onto a fault Since the frequency is not yet known at this time an increased restraint will be active until the actual frequency is determined This may delay the tripping but only close to the pickup threshold i e in case of very low current faults The self restraining quantities are calculated in each device from the total sum of the possible deviations and transmitted to the other device ...

Page 68: ...t also the remaining phases of the differential stage are blocked This cross block function can be limited to a selectable duration Figure 2 19 shows the logic diagram The cross block function also affects both devices since it not only extends the inrush restraint to all three phases but also sends it to the other device via the communication link Figure 2 19 Logic diagram of the cross block func...

Page 69: ...culated differential current exceeds the pickup limit and the greatest possible measurement error the fault must be internal shaded area in Figure 2 20 Figure 2 20 Differential protection pickup characteristic Idiff stage If not only an internal fault is to cause a TRIP command but if a local current of a specific quantity is to exist additionally the value of this current can be set at address 12...

Page 70: ...te a charge value in the primary circuit Each phase is subject to the charge comparison Therefore an internal fault sequential fault in a different phase after the external fault occurred is detected immediately The functional limitation of the charge compar ison is reached in the less probable case that an internal fault sequential fault appears after the occurrence of an external fault with cons...

Page 71: ...h stage has picked up Figure 2 21 Pickup logic for the differential protection function As soon as the differential protection function registers a fault within its tripping zone the signal Diff Gen Flt general device pickup of the differential protection is issued For the differential protection function itself this pickup signal is of no concern since the tripping conditions are available at the...

Page 72: ...nsient oscillations on occurrence of a single earth fault in a resonant earthed system The output signals thus processed are combined to the output signals Diff Gen TRIP Diff TRIP 1p L1 Diff TRIP 1p L2 Diff TRIP 1p L3 Diff TRIP L123 in the tripping logic of the device The single pole information implies that tripping will take place single pole only The actual generation of the commands for the tr...

Page 73: ...ent power of a transformer in the pro tected area as described in 2 1 4 1 under margin heading topological data for transformers is described in the protection zone optional or from the addresses 1104 FullScaleCurr according to Section 2 1 4 1 under margin heading Rated Values of Protected Lines It must be equal at all ends of the protected object If setting is performed from a personal computer u...

Page 74: ...ld be increased By setting the address to the single phase pickup is suppressed entirely In an earthed system T3I0 1PHAS shall be set to 0 00 s This parameter can only be altered in DIGSI at Ad ditional Settings If it is desired that a TRIP command is generated in the event of an internal fault only if simultaneously the current of the local line end has exceeded a specific quantity then this curr...

Page 75: ...t a smaller value However if the local measured current exceeds a value set in address 2305 MAX INRUSH PEAK there will be no inrush restraint The peak value is decisive The set value should be higher than the maximum inrush current peak value that can be expected For transformers you can set the value above 2 INTransf ukTransfo by rule of thumb If a line ends on a transformer a smaller value may b...

Page 76: ... Active 3132 Diff Gen Flt OUT Diff Fault detection 3133 Diff Flt L1 OUT Diff Fault detection in phase L1 3134 Diff Flt L2 OUT Diff Fault detection in phase L2 3135 Diff Flt L3 OUT Diff Fault detection in phase L3 3136 Diff Flt E OUT Diff Earth fault detection 3137 I Diff Flt OUT Diff Fault detection of I Diff 3139 I Diff Flt OUT Diff Fault detection of I Diff 3141 Diff Gen TRIP OUT Diff General TR...

Page 77: ...et Commissioning state of Diff 3192 TestDiff remote OUT Diff Remote relay in Teststate 3193 Comm Diff act OUT Diff Commissioning state is active 3197 Test Diff ON SP Diff Set Teststate of Diff protection 3198 Test Diff OFF SP Diff Reset Teststate of Diff protec 3199 Test Diff ONoff IntSP Diff Teststate of Diff prot ON OFF 3200 TestDiffONoffBI IntSP Diff Teststate ON OFF via BI 3260 Comm Diff ON SP...

Page 78: ... devices and circuit breakers are designed for single pole tripping 2 4 1 Function Description Transmission Circuit The transmission signal can originate from two different sources Figure 2 23 If the parameter I TRIP SEND is set to YES each tripping command of the differential protection is routed immediately to the transmission function ITrp sen L1 to L3 intertrip and transmitted via the communic...

Page 79: ... ResetRemote at address 4512 is started for resetting the transfer trip signals This means that in case of communication in terruption a present receive signal maintains its last status for the time Td ResetRemote before it is reset Figure 2 24 Logic diagram of the intertrip receiving circuit Ancillary Functions Since the signals for remote tripping can be set to cause only an alarm any other desi...

Page 80: ...y stabilizes the transmission signal against dynamic interferences which may occur on the control cabling Address 1304 T ITRIP PROL BI is used to extend a signal after it has been effectively injected from an ex ternal source The reaction of a device when receiving an intertrip remote tripping signal is set at address 1302 I TRIP RECEIVE If it is supposed to cause tripping set the value Trip If th...

Page 81: ...ved at Prot Interface 1 L1 3506 ITrp rec PI1 L2 OUT I Trip Received at Prot Interface 1 L2 3507 ITrp rec PI1 L3 OUT I Trip Received at Prot Interface 1 L3 3511 ITrp sen PI1 L1 OUT I Trip Sending at Prot Interface 1 L1 3512 ITrp sen PI1 L2 OUT I Trip Sending at Prot Interface 1 L2 3513 ITrp sen PI1 L3 OUT I Trip Sending at Prot Interface 1 L3 3517 ITrp Gen TRIP OUT I Trip General TRIP 3518 ITrp TRI...

Page 82: ... that a current transformer is installed in the starpoint connection i e between the starpoint and the earthing electrode The starpoint CT and the phase CTs define the limits of the protected zone exactly 2 5 1 Application Examples Figures 2 25 and 2 26 show two application examples A prerequisite is that the I4 transformer detects the star point current of the transformer side to be protected Fig...

Page 83: ...curs outside the protected zone Figure 2 28 a starpoint current ISP will also flow But an equally large current 3 I0 must then flow through the phase current transformers Since the current direction into the protected object is defined as positive this current is in phase opposition with ISP Figure 2 28 Example for an earth fault outside a transformer with current distribution When an external non...

Page 84: ...s present Figure 2 29 Principle of restricted earth fault protection When an earth fault occurs outside the protected zone a zero sequence current also flows though the phase current transformers This is on the primary side in counter phase with the starpoint current and has equal magnitude Therefore both the magnitude of the currents and their phase relationship are evaluated for re straint purpo...

Page 85: ...et to zero i e full sensitivity during internal earth fault This result shows that for an internal fault no restraint is effective since the restraining quantity is either zero or negative Thus even small earth currents can cause tripping In contrast strong restraint becomes effective for external earth faults Figure 2 30 shows that the higher the zero sequence current transmitted by the phase cur...

Page 86: ...summation and and difference comparison Figure 2 31 Phasor diagram of the restraint quantity during external fault The restraint quantity can be influenced by a factor k This factor has a certain relationship to the limit angle ϕlimit This limit angle determines for which phase displacement between 3I0 and 3I0 the pickup value for 3I0 3I0 grows to i e no pickup occurs In 7SD610 k 4 In the aforemen...

Page 87: ... IrestREF Σ I IL1 IL2 IL3 I4 The slope of the characteristic curve can be adjusted Pickup Normally a differential protection does not need a pickup since the fault detection and the trip condition are identical But the earth fault differential protection like all protection functions has a pickup function which is required for tripping and serves as the starting point for a number of further activ...

Page 88: ... Without proper settings the device may show unexpected reactions incl tripping The sensitivity of the protection is determined by the I REF address 4111 This is the earth fault current that flows through the starpoint lead of the transformer Any other earth current which may be supplied from the network does not influence the sensitivity The set pickup value can be additionally increased in the t...

Page 89: ...Column C configuration indicates the corresponding second ary nominal current of the current transformer 2 5 5 Information List Addr Parameter C Setting Options Default Setting Comments 4101 REF PROT OFF ON OFF Restricted Earth Fault Pro tection 4111 I REF 1A 0 05 2 00 A 0 15 A Pick up value I REF 5A 0 25 10 00 A 0 75 A 4112A T I REF 0 00 60 00 sec 0 00 sec T I REF Time Delay 4113A SLOPE 0 00 0 95...

Page 90: ...e switched on and off with a setting parameter and may be blocked via binary input Figure 2 35 Logic diagram of the local external tripping 2 6 2 Setting Notes General A prerequisite for the application of the direct and remote tripping functions is that during the configuration of the scope of functions in address 122 DTT Direct Trip Enabled was applied At address 2201 FCT Direct Trip it can also...

Page 91: ...K DTT SP BLOCK Direct Transfer Trip function 4412 DTT Trip L1 SP Direct Transfer Trip INPUT Phase L1 4413 DTT Trip L2 SP Direct Transfer Trip INPUT Phase L2 4414 DTT Trip L3 SP Direct Transfer Trip INPUT Phase L3 4417 DTT Trip L123 SP Direct Transfer Trip INPUT 3ph L123 4421 DTT OFF OUT Direct Transfer Trip is switched OFF 4422 DTT BLOCK OUT Direct Transfer Trip is BLOCKED 4432 DTT TRIP 1p L1 OUT ...

Page 92: ...emote CMD1 rec to Remote CMD4 rec The remaining 24 items of information reach the device via the binary inputs Rem Signal 1 to Rem Signal24 and are correspondingly available under Rem Sig 1recv etc at the receiving side When assigning the binary inputs and outputs using DIGSI you can provide the information to be transmitted with your own designation If for example a line has a unit connected powe...

Page 93: ...ote Signal 10 input 3559 Rem Signal11 SP Remote Signal 11 input 3560 Rem Signal12 SP Remote Signal 12 input 3561 Rem Signal13 SP Remote Signal 13 input 3562 Rem Signal14 SP Remote Signal 14 input 3563 Rem Signal15 SP Remote Signal 15 input 3564 Rem Signal16 SP Remote Signal 16 input 3565 Rem Signal17 SP Remote Signal 17 input 3566 Rem Signal18 SP Remote Signal 18 input 3567 Rem Signal19 SP Remote ...

Page 94: ...Rem Sig16recv OUT Remote signal 16 received 3589 Rem Sig17recv OUT Remote signal 17 received 3590 Rem Sig18recv OUT Remote signal 18 received 3591 Rem Sig19recv OUT Remote signal 19 received 3592 Rem Sig20recv OUT Remote signal 20 received 3593 Rem Sig21recv OUT Remote signal 21 received 3594 Rem Sig22recv OUT Remote signal 22 received 3595 Rem Sig23recv OUT Remote signal 23 received 3596 Rem Sig2...

Page 95: ...rameter CBaux for I address 2406 If the parameter CBaux for I is set to local only for the first mode only the position of the local circuit breaker is considered If the circuit breaker is open at least for the time set in parameter SI Time all Cl address 1132 and an energization takes place the I stage is activated for the time set in pa rameter SI Time all Cl The I stage trips unselectively in c...

Page 96: ...lue of the currents is measured from the double setting value onwards Figure 2 37 shows the logic diagram in the upper part Therefore this stage is used when current grading is possible This is possible with a small source impedance and at the same time a high impedance of the protected object an example can be found in the advice on setting notes Section 2 8 2 The I stage is enabled automatically...

Page 97: ...ction not to pick up on the RMS value of the inrush current produced during the connection of the protected object On the other hand fault currents flowing through the protected object do not need to be considered When using a PC and DIGSI for the parameterization the values can be optionally entered as primary or sec ondary quantities For settings with secondary values the currents will be conver...

Page 98: ...of the current transformers Exemplary calculation 110 kV overhead line 150 mm2 with the data s length 60 km R1 s 0 19 Ω km X1 s 0 42 Ω km Short circuit power at the feeding end Sk 3 5 GVA subtransient since the I stage can respond to the first peak value Current transformer 600 A 5 A From that the line impedance ZL and the source impedance ZS are calculated Z1 s 0 192 0 422 Ω km 0 46 Ω km ZL 0 46 ...

Page 99: ...ation Type of In formation Comments 4253 BLOCK SOTF O C SP BLOCK Instantaneous SOTF Overcurrent 4271 SOTF O C OFF OUT SOTF O C is switched OFF 4272 SOTF O C BLOCK OUT SOTF O C is BLOCKED 4273 SOTF O C ACTIVE OUT SOTF O C is ACTIVE 4281 SOTF O C PICKUP OUT SOTF O C PICKED UP 4282 SOF O CpickupL1 OUT SOTF O C Pickup L1 4283 SOF O CpickupL2 OUT SOTF O C Pickup L2 4284 SOF O CpickupL3 OUT SOTF O C Pic...

Page 100: ...er overcurrent stage which has an additional enable input and can therefore be used as an emergen cy stage e g if the remaining stages are used as backup stages or as a stub protection One overcurrent stage with inverse time characteristic IDMT One directional overcurrent stage with a inverse time characteristic O C with IDMT These six stages are independent of each other and are freely combinable...

Page 101: ...The current voltage is used if it is 5V If none of the previously measuring values is available an already existing result of the direction determination is used or the directional stage is blocked for the respective phase For the directional 3I0 stages the measuring voltage used is determined by the parameter 2603 Direct 3I0 If with U0 I0 has been set the current zero sequence values 3U0 and 3I0 ...

Page 102: ...ropout value is approximately 7 below the pickup value but at least 1 8 of the nominal current Figure 2 39 shows the logic diagram of the I stages The stages can be blocked via the binary input BLOCK O C I Additionally the earth current can be blocked separately via a binary input BLOCK O C Ie During the single pole pause the earth current stage is always blocked to avoid a fault pickup The binary...

Page 103: ...pickup signals are listed in Table 2 3 2 Output indications associated with the trip signals are listed in Table 2 4 Definite time overcurrent stage I The logic of the overcurrent stages I is structured identically to the I stages In all references Iph must merely be replaced by Iph or 3I0 PICKUP by 3I0 The parameter 2624 I Telep BI is set to NO by default In all other respects figure 2 39 applies...

Page 104: ... and inputs or via the user definable logic CFC functions The stage is then automatically active whenever the differential pro tection is not effective e g due to a data disturbance The I stage can however also be used as a standard additional and independent overcurrent stage since it works independent of the other stages In this case the enable input I STUB ENABLE must be activated permanently v...

Page 105: ... earth current can be blocked separately via a binary input BLOCK Dir Iep During fuse failure or pickup of the Fuse Failure Monitor all stages which are parameterized as Forward or Reverse are blocked During the single pole pause the earth current stage is always blocked to avoid a fault trigger The binary input O C InstTRIP and the evaluation of the indication switch onto fault can separately aff...

Page 106: ...diagram of the I stage 1 Output indications associated with the pickup signals are listed in Table 2 3 2 Output indications associated with the trip signals are listed in Table 2 4 3 The indications O C L2 forward O C L3 forward O C L2 reverse O C L3 reverse have not been represented in the Figure however they are reported if necessary ...

Page 107: ...and a time multiplier following figure A pre selection of the available characteristics was already carried out during the configuration of the protection functions Furthermore an additional constant time delay T Ip Add or T 3I0p Add may be selected which is added to the inverse time The possible characteristics are shown in the Technical Data The following figure shows the logic diagram The setti...

Page 108: ...145 6 Release date 02 2011 108 Figure 2 42 Logic diagram of the IP stage inverse time overcurrent protection example of IEC curve 1 Output indications associated with the pickup signals are listed in Table 2 3 2 Output indications associated with the trip signals are listed in Table 2 4 ...

Page 109: ...e shown in the Technical Data The individual phase or earth specific directional indications 7240 to 7247 are used to generate the indications O C Dir forward or O C Dir reverse if a valid direction result forward or backward was deter mined for a phase or earth current These messages can then be transferred to a different device and there they can cause an immediate trip if an overcurrent stage o...

Page 110: ...se time overcurrent protection for example IEC character istics 1 Output indications associated with the pickup signals are listed in Table 2 3 2 Output indications associated with the trip signals are listed in Table 2 4 3 The indications O C L2 forward O C L3 forward O C L2 reverse O C L3 reverse have not been represented in the Figure however they are reported if necessary ...

Page 111: ...a reduced delay It can be determined via parameter setting for which stage s the instantaneous tripping following energization applies refer also to the logic diagrams Figure 2 39 2 42 and 2 40 This function is independent of the high current instantaneous tripping described in Subsection 2 8 Pickup logic and tripping logic The pickup signals of the single phases or earth and of the individual sta...

Page 112: ...e which has been tripped is also indicated refer also to Section Tripping Logic of the Entire Device I PU L1 I PU L2 I PU L3 I PU E 2 40 2 40 2 40 2 40 I STUB PICKUP 7201 I ger PU L1 I ger PU L2 I ger PU L3 I ger PU E 2 41 2 41 2 41 2 41 O C PICK I Dir 7202 Ip PU L1 Ip PU L2 Ip PU L3 Ip PU E 2 42 2 42 2 42 2 42 O C PICKUP Ip 7193 Ip ger PU L1 Ip ger PUL2 Ip ger PU L3 Ip ger PU E 2 43 2 43 2 43 2 4...

Page 113: ...RIP L2 I TRIP L2 I TRIP L2 1 I TRIP Dir L2 Ip TRIP L2 IpTRIP Dir L2 2 39 2 40 2 41 2 42 2 43 O C TRIP 1p L2 or O C TRIP L123 7213 or 7215 I TRIP L3 I TRIP L3 I TRIP L3 1 I TRIP Dir L3 Ip TRIP L3 IpTRIP Dir L3 2 39 2 40 2 41 2 42 2 43 O C TRIP 1p L3 or O C TRIP L123 7214 or 7215 I TRIP E I TRIP E I TRIP E 2 I TRIP Dir E Ip TRIP E IpTRIP Dir E 2 39 2 40 2 41 2 42 2 43 O C TRIP L123 7215 I TRIP L1 I ...

Page 114: ...F Time DELAY address 2602 can be set Typically the presetting of 0 s is correct A short delay can be useful in case of long cables for which high inrush currents can be expected or for trans formers This delay depends on the intensity and the duration of the transient overcurrents as well as on which stages were selected for the fast switch onto fault clearance Directional Stages The directional s...

Page 115: ...s with large reactances e g transformers series reactors the I stages can also be used for current grading In this case they must be set in such a way that they do not pick up in case of a fault at the end of the line The times can then be set to 0 s or to a small value When using a personal computer and DIGSI to apply the settings these can be optionally entered as primary or secondary values For...

Page 116: ...ven before auto reclosure If the I stage when switching the line onto a fault is to re trip without delay or with a short delay SOTF Time DELAY address 2602 see above under margin heading General the parameter I SOTF address 2615 is set to YES Any other stage can be selected as well for this instantaneous tripping Time Overcurrent Stages Iph 3I0 Iph Dir 3I0 Dir for Definite time Overcurrent Protec...

Page 117: ...re If the I stage when switching the line onto a fault is to re trip without delay or with a short delay SOTF Time DELAY address 2602 see above under margin heading General the parameter I SOTF address 2625 or I Dir SOTF address 2687 is set to YES We recommend however not to choose the sensitive setting for the fast tripping as switching onto a fault could cause a solid short circuit It is importa...

Page 118: ...I NO the set delays are always active Instantaneous tripping by the operational auto reclosure function should only be chosen if the overcurrent pro tection is set to emergency function Since the differential protection guarantees a fast and selective tripping with or without auto reclosure the overcurrent protection as a backup protection may not perform a non selec tive trip even before auto rec...

Page 119: ...nary input was activated For I 3I0 p Tele BI NO or IPDir Telep BI NO the set delays are always active Instantaneous tripping by the operational auto reclosure function should only be chosen if the overcurrent pro tection is set to emergency function Since the differential protection guarantees a fast and selective tripping with or without auto reclosure the overcurrent protection as a backup prote...

Page 120: ... the line is switched onto a fault is also possible with the I stage Set parameter I STUB SOTF address 2635 to YES if instantaneous tripping is desired 2 9 4 Settings Addresses which have an appended A can only be changed with DIGSI under Additional Settings The table indicates region specific presettings Column C configuration indicates the corresponding second ary nominal current of the current ...

Page 121: ...e Dial 0 05 3 00 sec 0 50 sec T Ip Time Dial 2643 Time Dial TD Ip 0 50 15 00 5 00 Time Dial TD Ip 2646 T Ip Add 0 00 30 00 sec 0 00 sec T Ip Additional Time Delay 2650 3I0p PICKUP 1A 0 05 4 00 A A 3I0p Pickup 5A 0 25 20 00 A A 2652 T 3I0p TimeDial 0 05 3 00 sec 0 50 sec T 3I0p Time Dial 2653 TimeDial TD3I0p 0 50 15 00 5 00 Time Dial TD 3I0p 2656 T 3I0p Add 0 00 30 00 sec 0 00 sec T 3I0p Additional...

Page 122: ...d Direction of stage Ip Dir 2689 Ip Dir 1A 0 10 4 00 A A Ip directional Pickup 5A 0 50 20 00 A A 2690 T Ip Dir 0 05 3 00 sec 0 50 sec T Ip Dir Inv Time delay for IEC Char 2691 D Ip Dir 0 50 15 00 5 00 D 3I0p Dir Inv Time delay for ANSI Ch 2692 T Ip Add Dir 0 00 30 00 sec 0 00 sec T 3I0p Dir additional time delay 2693 Direction 3I0P Forward Reverse Forward Direction of stage 3I0p 2694 3I0p Dir 1A 0...

Page 123: ...kup O C PICKED UP 7162 O C Pickup L1 OUT Backup O C PICKUP L1 7163 O C Pickup L2 OUT Backup O C PICKUP L2 7164 O C Pickup L3 OUT Backup O C PICKUP L3 7165 O C Pickup E OUT Backup O C PICKUP EARTH 7171 O C PU only E OUT Backup O C Pickup Only EARTH 7172 O C PU 1p L1 OUT Backup O C Pickup Only L1 7173 O C Pickup L1E OUT Backup O C Pickup L1E 7174 O C PU 1p L2 OUT Backup O C Pickup Only L2 7175 O C P...

Page 124: ...Backup O C TRIP I directional 7237 O C TRIP IpDir OUT Backup O C Pickup Ip directional 7240 O C L1 forward OUT Backup O C L1 forward direction 7241 O C L2 forward OUT Backup O C L2 forward direction 7242 O C L3 forward OUT Backup O C L3 forward direction 7243 O C 3I0 forward OUT Backup O C 3I0 forward direction 7244 O C L1 reverse OUT Backup O C L1 reverse direction 7245 O C L2 reverse OUT Backup ...

Page 125: ...e faults in the network with earthed system star point If the fault still exists after reclosure arc not extinguished or metallic short circuit the protection issues a final trip In some systems several reclosing attempts are performed In the model with 1 pole tripping the 7SD610 allows phase selective 1 pole tripping A 1 and 3 pole one and multi shot automatic reclosure is integrated depending on...

Page 126: ... non delayed tripping However fast tripping of the protection may also be desired before reclosure after tripping by other short circuit protection functions For this purpose every short circuit protection which can start the automatic reclosure function has the possibility of initiating non delayed tripping in at least one stage when the automatic reclosure function is ready for the first reclosu...

Page 127: ...tion time expires the corresponding reclosure cycle is not carried out For each reclosure cycle it can be specified whether or not it should allow the initiation Following the first general pickup only those action times are relevant whose cycles allow starting because the other cycles are not allowed to initiate By means of the action times and the permission to start the recloser permission to b...

Page 128: ...ic reclosure command The only ex ception is the ADT mode where the reclaim time can be disabled by setting it to 0 s If the reclosure is success ful all functions of the automatic reclosure function return to the idle state at the end of the reclaim time a fault after expiry of the reclaim time is treated as a new fault in the power system If the reclaim time is disabled in ADT mode each new trip ...

Page 129: ...xists theoretically when two poles are open The device continuously checks the position of the circuit breaker As long as the auxiliary contacts indicate that the CB is not closed 3 pole the automatic reclosure function cannot be started This ensures that a close command can only be issued if the CB has previously tripped out of the closed state The valid dead time begins when the trip command dis...

Page 130: ...ole auxiliary contact criterion After expiry of the dead time the circuit breaker receives a close command At the same time the adjustable reclaim time is started If the reclosure is blocked during the dead time following a 1 pole trip im mediate 3 pole tripping can take place as an option forced 3 pole trip If the fault is cleared successful reclosure the reclaim time expires and all functions re...

Page 131: ...s the same in principle as in the different reclosure programs described above However if the first reclosure attempt was unsuccessful the reclosure function is not blocked but instead the next reclose cycle is started The appropriate dead time starts with the reset of the trip command or opening of the circuit breaker pole auxiliary contact criterion The circuit breaker receives a new close comma...

Page 132: ...discrepancy supervision which will trip the remaining poles after a few seconds By setting a parameter you can achieve that the tripping logic of the device immediately sends a 3 pole trip command in this case This forced 3 pole trip pre empts the pole discrepancy supervision of the CB because the forced 3 pole trip of the device is initiated as soon as the reclosure is blocked following a 1 pole ...

Page 133: ...e illustrated example of a short circuit the lines are disconnected at positions I and II In I reclosure takes place after the configured dead time If the fault has been cleared successful reclosure line A B is re connected to the voltage at busbar A through position I Device II detects this voltage and also recloses after a short delay to ensure a sufficient voltage mea suring time The fault is c...

Page 134: ...data interface The information is OR combined with the information of the binary input AR RemoteClose and made available to the automatic reclosure Figure 2 47 Connecting an External Auto Reclosure Device If the 7SD610 has to work with an external reclosure device the binary inputs and outputs provided for this purpose must be taken into consideration The following inputs and outputs are recommend...

Page 135: ...igure 2 49 Connection example with external reclosure device for 3 pole AR Control of the internal automatic reclosure by an external protection device If the 7SD610 is equipped with the internal automatic reclosure function this can also be controlled by an ex ternal protection device This is of use for example on line ends with redundant protection or additional back up protection when the secon...

Page 136: ...e 2864 AR 1p Trip Perm Internal automatic reclosure function ready for 1 pole reclose cycle i e allows 1 pole tripping logic inversion of the 3 pole coupling 2889 AR 1 CycZoneRel Internal automatic reclosure function ready for the first reclose cycle i e re leases the stage of the external protection device for reclosure the corre sponding outputs can be used for other cycles This output can be om...

Page 137: ...ample with external protection device for 3 pole reclosure AR control mode with TRIP But if the internal automatic reclose function is controlled by the pickup only possible for 3 pole tripping 110 Trip mode 3pole only the phase selective pickup signals of the external protection must be connected if distinction shall be made between different types of fault The general trip command then suffices ...

Page 138: ...xternal automatic 3 pole coupling is there fore unnecessary if the above conditions are met This prevents 2 pole tripping under all circumstances For the connection according to Figure 2 53 it must be considered that the cross connections to the second protection must be interrupted during the check of one of the two protection systems with protection monitoring equipment This is done for example ...

Page 139: ...l SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 139 Figure 2 53 Connection example for 2 protection devices with 2 automatic reclosure functions BI Binary inputs M Signal output K Command for all protection functions operating with AR ...

Page 140: ...ional SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 140 Figure 2 54 Connection example for 2 protection devices with internal automatic reclosure function and minimum cross connection Figure 2 55 Setting of the software filter time ...

Page 141: ...YES Furthermore the circuit breaker ready state can also be interrogated prior to every reclosure This is set when setting the individual reclose cycles see below To check that the ready status of the circuit breaker is regained during the dead times you can set a circuit breaker ready monitoring time under address 3409 CB TIME OUT The time is set slightly longer than the re covery time of the cir...

Page 142: ...d time If a 3 pole reclose cycle is to be initiated by tripping of the sequential fault set EV FLT MODE starts 3p AR In this case a separately adjustable 3 pole dead time is started with the 3 pole trip command due to the sequential fault This is only useful if 3 pole reclosure is also permitted Address 3408 T Start MONITOR monitors the reaction of the circuit breaker after a trip command If the C...

Page 143: ...nd connected to the device If this is not the case or the function is not used set DLC RDT WITHOUT DLC RDT DLC means that the dead line check of the line voltage is used It only allows reclosing after it has been verified in advance that the line is dead In this case the phase to earth voltage limit is set in address 3441 U dead below which the line is considered voltage free disconnected The sett...

Page 144: ... protection functions is decisive If the reclaim time is unequal to 0 s and 1 pole tripping is allowed 1 pole tripping will be prevented during the reclaim time Each fault is thus disconnected in three poles while the reclaim time is active Address 3403 T RECLAIM allows disabling the reclaim time in ADT mode In doing so the ADT cycle including its settings and release conditions is restarted after...

Page 145: ...ode with TRIP you can set different dead times for 1 pole and 3 pole reclose cycles Whether 1 pole or 3 pole tripping is triggered depends solely on the initiating protection functions 1 pole trip ping is of course only possible if the device and the corresponding protection function are also capable of 1 pole tripping Table 2 5 AR control mode with TRIP If you only want to allow a 1 pole reclose ...

Page 146: ...nal device is available for synchronism and voltage check If only 1 pole reclose cycles are executed or if no stability problems are expected during 3 pole dead times e g due to closely meshed networks or in radial networks set address 3460 to NO 2nd to 4th Reclose Cycle If several cycles have been set in the configuration of the scope of protection functions you can set individual reclosure param...

Page 147: ...ch precedes the fourth 4th reclosing attempt 3483 4 AR START Start in 4th cycle generally allowed 3484 4 AR T ACTION Action time for the 4th cycle 3486 4 AR Tdead 1Flt Dead time after 1 phase pickup 3487 4 AR Tdead 2Flt Dead time after 2 phase pickup 3488 4 AR Tdead 3Flt Dead time after 3 phase pickup 3489 4 AR Tdead1Trip Dead time after 1 pole tripping 3490 4 AR Tdead3Trip Dead time after 3 pole ...

Page 148: ...he operational information system that in the event of an upcoming system fault there will be a final trip i e without reclosure If the automatic reclosure has been started this information does not appear AR not ready No 2784 The automatic reclosure is not ready for reclosure at the moment In addition to the AR is blocked No 2783 mentioned above there are also obstructions during the course of th...

Page 149: ... 3408 T Start MONITOR 0 01 300 00 sec 0 50 sec AR start signal monitoring time 3409 CB TIME OUT 0 01 300 00 sec 3 00 sec Circuit Breaker CB Supervision Time 3410 T RemoteClose 0 00 300 00 sec 0 20 sec Send delay for remote close command 3411A T DEAD EXT 0 50 300 00 sec sec Maximum dead time extension 3420 AR WITH DIFF YES NO YES AR with differential protection 3421 AR w SOTF O C YES NO YES AR with...

Page 150: ...ed in this cycle 3462 2 AR T ACTION 0 01 300 00 sec 0 20 sec Action time 3464 2 AR Tdead 1Flt 0 01 1800 00 sec 1 20 sec Dead time after 1phase faults 3465 2 AR Tdead 2Flt 0 01 1800 00 sec 1 20 sec Dead time after 2phase faults 3466 2 AR Tdead 3Flt 0 01 1800 00 sec 0 50 sec Dead time after 3phase faults 3467 2 AR Tdead1Trip 0 01 1800 00 sec sec Dead time after 1pole trip 3468 2 AR Tdead3Trip 0 01 1...

Page 151: ...pe of In formation Comments 127 AR ON OFF IntSP Auto Reclose ON OFF via system port 2701 AR on SP AR Switch on auto reclose function 2702 AR off SP AR Switch off auto reclose function 2703 AR block SP AR Block auto reclose function 2711 AR Start SP External start of internal Auto reclose 2712 Trip L1 AR SP AR External trip L1 for AR start 2713 Trip L2 AR SP AR External trip L2 for AR start 2714 Tr...

Page 152: ...ip OUT AR dead time after 1pole trip running 2840 AR Tdead 3pTrip OUT AR dead time after 3pole trip running 2841 AR Tdead 1pFlt OUT AR dead time after 1phase fault running 2842 AR Tdead 2pFlt OUT AR dead time after 2phase fault running 2843 AR Tdead 3pFlt OUT AR dead time after 3phase fault running 2844 AR 1stCyc run OUT AR 1st cycle running 2845 AR 2ndCyc run OUT AR 2nd cycle running 2846 AR 3rdC...

Page 153: ...iate times delay Abnormally high voltages often occur e g in low loaded long distance transmission lines in islanded systems when generator voltage regulation fails or after full load shutdown of a generator with the generator discon nected from the system Even if compensation reactors are used to avoid line overvoltages by compensation of the line capacitance and thus reduction of the overvoltage...

Page 154: ...oltage The phase to phase overvoltage protection operates just like the phase to earth protection except that it detects phase to phase voltages Accordingly phase to phase voltages which have exceeded one of the stage thresholds Uph ph address 3712 or Uph ph address 3714 are also indicated Beyond this Figure 2 56 applies in principle The phase to phase overvoltage protection can also be blocked vi...

Page 155: ...ence voltage is fed to the two threshold stages U1 address 3732 and U1 ad dress 3734 see Figure 2 57 Combined with the associated time delays T U1 address 3733 and T U1 address 3735 these stages form a two stage overvoltage protection based on the positive sequence system Here too the drop out to pickup ratio can be set The overvoltage protection for the positive sequence system can also be blocke...

Page 156: ...ng the voltage at the opposite line end the device requires the line data inductance per unit length capacitance per unit length line angle line length which were entered in the Power System Data 2 Section 2 1 4 1 during configuration Compounding is only available if address 137 is set to Enabl w comp In this case the calculated voltage at the other line end is also indicated in the operational me...

Page 157: ...e protection for the negative sequence system can also be blocked via a binary input U2 BLK The stages of the negative sequence voltage protection are automatically blocked as soon as an asym metrical voltage failure was detected Fuse Failure Monitor also see Section 2 15 1 margin heading Fast Fuse Failure Monitor Non symmetrical Voltages or when tripping of the MCB for voltage transformers has be...

Page 158: ...ges or when the trip of the mcb for voltage transformers has been sig nalled via the binary input FAIL Feeder VT internal indication internal blocking The stages of the zero sequence voltage protection are automatically blocked during single pole automatic reclose dead time to avoid pickup with the asymmetrical power flow arising during this state If the device co operates with an external automat...

Page 159: ...le phase voltage As the zero sequence voltage stages operate separately and independently of the other protection overvoltage functions they can be used for any other single phase voltage Therefore the fourth voltage input U4 of the device must be assigned accordingly also see Section 2 1 2 Voltage Transformer Connection The stages can be blocked via a binary input 3U0 BLK Internal blocking is not...

Page 160: ...sbar side after a trip command and opening of the circuit breaker it becomes zero on the outgoing side For the undervoltage pro tection this results in a pickup state being present if the voltage transformers are on the outgoing side If this pickup must be reset the current can be used as an additional criterion current supervision CURR SUP Uphe address 3758 to achieve this result Undervoltage wil...

Page 161: ...ctions 2 11 Undervoltage and Overvoltage Protection optional SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 161 Figure 2 61 Logic diagram of the undervoltage protection for phase voltages ...

Page 162: ...ted phase provided that the voltage transformers are located on the outgoing side Only such stages are blocked during the single pole dead time that can actually initiate tripping according to their setting Undervoltage positive sequence system U1 The device calculates the positive sequence system according to its defining equation U1 1 3 UL1 a UL2 a2 UL3 where a ej120 The resulting positive seque...

Page 163: ... caused by the disconnected phase in case the voltage transformers are located on the outgoing side 2 11 3 Setting Notes General The voltage protection can only operate if when configuring the device scope address 137 it has been set to Enabled Compounding is only available if address 137 is set to Enabl w comp The overvoltage and undervoltage stages can detect phase to earth voltages phase to pha...

Page 164: ...ame considerations apply as for the phase voltage stages These stages can be used instead of the phase voltage stages or additionally Depending on your choice set address 3711 Uph ph to ON OFF Alarm Only or U Alarm U Trip As phase to phase voltages are monitored the phase to phase values are used for the settings Uph ph ad dress 3712 and Uph ph address 3714 For the delay times T Uph ph address 371...

Page 165: ...44 with a short delay time T U2 address 3745 for high asymmetrical voltages Note that the negative sequence system is calculated according to its defining equation U2 1 3 UL1 a2 UL2 a UL3 For symmetrical voltages and two swapped phases this is equivalent to the phase to earth voltage value The dropout to pickup ratio U2 RESET can be set in address 3749 This parameter can only be altered in DIGSI a...

Page 166: ...nd You can generate a trip command for the 2nd stage only in addition to the alarm by setting U Alarm U Trip This undervoltage protection function has two stages The Uph e stage address 3752 with a longer setting of the time T Uph e address 3753 operates in the case of minor undervoltages However the value set here must not be higher than the undervoltage permissible in operation In the presence o...

Page 167: ...ositive sequence system is calculated according to its defining equation U1 1 3 UL1 a UL2 a2 UL3 For symmetrical voltages this is equivalent to a phase to earth voltage The dropout to pickup ratio U1 RESET can be set in address 3779 This parameter can only be altered in DIGSI at Display Additional Settings If the voltage transformers are located on the line side the measuring voltages will be miss...

Page 168: ...20 0 V 150 0 V U1 Pickup 3733 T U1 0 00 100 00 sec 2 00 sec T U1 Time Delay 3734 U1 2 0 220 0 V 175 0 V U1 Pickup 3735 T U1 0 00 100 00 sec 1 00 sec T U1 Time Delay 3736 U1 Compound OFF ON OFF U1 with Compounding 3737 U1 Compound OFF ON OFF U1 with Compounding 3739A U1 RESET 0 30 0 99 0 98 U1 Reset ratio 3741 U2 OFF Alarm Only ON U Alarm U Trip OFF Operating mode U2 overvoltage prot 3742 U2 2 0 22...

Page 169: ...0 sec 2 00 sec T U1 Time Delay 3774 U1 1 0 100 0 V 0 10 0 V U1 Pickup 3775 T U1 0 00 100 00 sec 1 00 sec T U1 Time Delay 3778 CURR SUP U1 ON OFF ON Current supervision U1 3779A U1 RESET 1 01 1 20 1 05 U1 Reset ratio No Information Type of In formation Comments 234 2100 U U blk IntSP U U blocked via operation 10201 Uph e BLK SP BLOCK Uph e Overvolt phase earth 10202 Uph ph BLK SP BLOCK Uph ph Overv...

Page 170: ...Uph e TimeOut OUT Uph e TimeOut 10247 Uph e TRIP OUT Uph e TRIP command 10248 Uph e PU L1 OUT Uph e Pickup L1 10249 Uph e PU L2 OUT Uph e Pickup L2 10250 Uph e PU L3 OUT Uph e Pickup L3 10251 Uph e PU L1 OUT Uph e Pickup L1 10252 Uph e PU L2 OUT Uph e Pickup L2 10253 Uph e PU L3 OUT Uph e Pickup L3 10255 Uphph Pickup OUT Uph ph Pickup 10256 Uphph Pickup OUT Uph ph Pickup 10257 Uphph PU L12 OUT Uph...

Page 171: ...10315 Uph e TimeOut OUT Uph e TimeOut 10316 Uph e TimeOut OUT Uph e TimeOut 10317 Uph e TRIP OUT Uph e TRIP command 10318 Uph e PU L1 OUT Uph e Pickup L1 10319 Uph e PU L2 OUT Uph e Pickup L2 10320 Uph e PU L3 OUT Uph e Pickup L3 10321 Uph e PU L1 OUT Uph e Pickup L1 10322 Uph e PU L2 OUT Uph e Pickup L2 10323 Uph e PU L3 OUT Uph e Pickup L3 10325 Uph ph Pickup OUT Uph ph Pickup 10326 Uph ph Picku...

Page 172: ...age is set to a value above the rated frequency it is automatically interpreted to be an overfrequency stage f If a stage is set to a value below the rated frequency it is automatically interpreted to be an underfrequency stage f If a stage is set exactly to the rated frequency it is inactive Each stage can be blocked via binary input and also the entire frequency protection function can be blocke...

Page 173: ... the device and the setting of the frequency stages power swings may cause the frequency protection to pickup and even to trip In these cases it is reasonable to block the frequency protection once power swings are detected This can be accomplished via binary inputs and binary outputs e g power swing detection of an external distance protection or by corresponding logic oper ations using the user ...

Page 174: ...Functions 2 12 Frequency Protection optional SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 174 Figure 2 63 Logic diagram of the frequency protection ...

Page 175: ... frequency it is automatically interpreted to be an underfrequency stage f If a stage is set exactly to the rated frequency it is inactive A pickup value can be set for each stage according to above rules The addresses and possible setting ranges are determined by the nominal frequency as configured in the Power System Data 1 Section 2 1 2 1 in Rated Frequency address 230 Please note that none of ...

Page 176: ...nd by disconnecting it from the power system on time The turbo regulator regulates the machine set to the nominal speed Consequently the sta tion s own demands can be continuously supplied at nominal frequency Since the dropout threshold is 20 mHz below or above the trip frequency the resulting minimum trip frequency is 30 mHz above or below the nominal frequency A frequency increase can for examp...

Page 177: ...LOCKED OUT Frequency protection is BLOCKED 5213 Freq ACTIVE OUT Frequency protection is ACTIVE 5215 Freq UnderV Blk OUT Frequency protection undervoltage Blk 5232 f1 picked up OUT Frequency protection f1 picked up 5233 f2 picked up OUT Frequency protection f2 picked up 5234 f3 picked up OUT Frequency protection f3 picked up 5235 f4 picked up OUT Frequency protection f4 picked up 5236 f1 TRIP OUT F...

Page 178: ... breaker will open and interrupt the fault current The current monitoring stage quickly resets typical 10 ms and stops the timer T BF If the trip command is not carried out circuit breaker failure case current continues to flow and the timer runs to its set limit The circuit breaker failure protection then issues a command to trip the backup circuit breakers and interrupt the fault current The res...

Page 179: ...of the current transformer set will be used if it is connected to the device If this current is not available the device will calculate it from the phase currents using this formula 3 I0 IL1 IL2 IL3 Additionally the value calculated by 7SD610 of three times the negative sequence current 3 I2 is used for plau sibility check This is calculated according to the equation 3 I2 IL1 a2 IL2 a IL3 where a ...

Page 180: ...e current flow criterion has picked up during the trip signal from the feeder protection the circuit breaker is assumed to be open as soon as the current disappears even if the associated auxiliary contact does not yet indicate that the circuit breaker has opened Figure 2 67 This gives preference to the more reliable current criterion and avoids overfunctioning due to a defect e g in the auxiliary...

Page 181: ...to connect also the general device pickup to binary input BF release no 1432 For Buchholz protection it is recommended that both inputs are connected to the device by two separate wire pairs Nevertheless it is possible to initiate the circuit breaker failure protection in single channel mode should a sep arate release criterion not be available The binary input BF release No 1432 must then not be ...

Page 182: ...otection is initiated by the internal input Start internal w o I if the trip signal comes from the internal voltage protection or frequency protection or by the external input BF Start w o I In this case the start signal is maintained until the circuit breaker is reported to be open by the auxiliary contact criterion Initiation can be blocked via the binary input BLOCK BkrFail e g during test of t...

Page 183: ... device pickup to binary input BF release Figure 2 70 shows this connection Nevertheless it is possible to initiate the circuit breaker failure protection in single channel mode should a sep arate release criterion not be available The binary input BF release must then not be assigned to any physical input of the device during configuration If the external protection device does not provide a gene...

Page 184: ... Figure 2 67 if parameterised Chk BRK CONTACT YES The auxiliary contact criterion is also processed for each individual circuit breaker pole If however the circuit breaker auxiliary contacts are not available for each individual circuit breaker pole then a 1 pole trip command is assumed to be executed only if the series connection of the normally open NO auxiliary contacts is inter rupted This inf...

Page 185: ...Functions 2 13 Circuit Breaker Failure Protection SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 185 Figure 2 72 Initiation conditions for single pole trip commands ...

Page 186: ... omitted if the feeder protection always trips 3 pole or if the circuit breaker is not capable of 1 pole tripping If different delay times are required after a 1 pole trip or 3 pole trip it is possible to use the timer stages T1 1pole and T1 3pole according to Figure 2 74 Figure 2 73 Single stage breaker failure protection with common phase initiation Figure 2 74 Single stage breaker failure prote...

Page 187: ...ion Circuit breaker not operational There may be cases when it is already obvious that the circuit breaker associated with a feeder protection relay cannot clear a fault e g when the tripping voltage or the tripping energy is not available In such a case it is not necessary to wait for the response of the feeder circuit breaker If provision has been made for the detection of such a condition e g c...

Page 188: ... end fault is defined here as a short circuit which has occurred at the end of a line or protected object between the circuit breaker and the current transformer set This situation is shown in Figure 2 77 The fault is located as seen from the current transformers mea surement location on the bus bar side thus it will not be regarded by the feeder protection device as a feeder fault It can only be ...

Page 189: ...three circuit breaker poles Under steady state operating conditions either all three poles of the circuit breaker must be closed or all three poles must be open Discrepancy is permitted only for a short time interval during a 1 pole automatic reclose cycle The scheme functionality is shown in Figure 2 79 The signals which are processed here are the same as those used for the circuit breaker failur...

Page 190: ...et of trip coils of this circuit breaker A choice can be made whether this trip repetition shall be 1 pole or 3 pole if the initial feeder protection trip was 1 pole provided that 1 pole trip is possible This choice is made in address 3903 1p RETRIP T1 Set this parameter to YES if the first stage is to trip 1 pole otherwise set it to NO If the circuit breaker does not respond to this trip repetiti...

Page 191: ...emote end are tripped after a delay time T2 address 3906 should the fault not have been cleared within this time The timers T1 1pole address 3904 and T1 3pole address 3905 are then set to since they are not needed You can also use the first stage alone if you wish to use different delay times after 1 pole and 3 pole tripping of the feeder protection In this case set T1 1pole address 3904 and T1 3p...

Page 192: ...n via circuit breaker auxiliary contacts connected to binary inputs If during an end fault the circuit breaker is tripped by a reverse stage of the feeder protection or by the busbar protection the fault is a busbar fault as determined from the location of the current transformers the fault current will continue to flow because the fault is fed from the remote end of the feeder circuit The time T ...

Page 193: ...T BreakerFail ON OFF ON Breaker Failure Protection 3902 I BF 1A 0 05 20 00 A 0 10 A Pick up threshold I 5A 0 25 100 00 A 0 50 A 3903 1p RETRIP T1 NO YES YES 1pole retrip with stage T1 local trip 3904 T1 1pole 0 00 30 00 sec 0 00 sec T1 Delay after 1pole start local trip 3905 T1 3pole 0 00 30 00 sec 0 00 sec T1 Delay after 3pole start local trip 3906 T2 0 00 30 00 sec 0 15 sec T2 Delay of 2nd stage...

Page 194: ...krFailON offBI IntSP Breaker failure prot ON OFF via BI 1451 BkrFail OFF OUT Breaker failure is switched OFF 1452 BkrFail BLOCK OUT Breaker failure is BLOCKED 1453 BkrFail ACTIVE OUT Breaker failure is ACTIVE 1461 BF Start OUT Breaker failure protection started 1472 BF T1 TRIP 1pL1 OUT BF Trip T1 local trip only phase L1 1473 BF T1 TRIP 1pL2 OUT BF Trip T1 local trip only phase L2 1474 BF T1 TRIP ...

Page 195: ...is set the device only generates an alarm even if the end temperature is reached The overtemperatures are calculated separately for each phase in a thermal replica from the square of the as sociated phase current This guarantees a true RMS value measurement and also includes the effect of har monic content A choice can be made whether the maximum calculated overtemperature of the three phases the ...

Page 196: ...actor k is set under address 4202 K FACTOR It is determined by the relation between the permissible thermal continuous current and this nominal current The permissible continuous current is at the same time the current at which the e function of the overtemper ature has its asymptote It is not necessary to determine the tripping temperature since it results automatically from the final rise temper...

Page 197: ... 5 s t6 time this is the time in seconds for which a current of 6 times the nominal current of the protected object may flow Example Cable as above with Permissible 1 s current 13 5 kA Setting value TIME CONSTANT 29 4 min Alarm levels By setting a thermal alarm stage Θ ALARM address 4204 an alarm can be provided before the tripping tem perature is reached so that a trip can be avoided by preventiv...

Page 198: ...ny rate 2 14 3 Settings The table indicates region specific presettings Column C configuration indicates the corresponding second ary nominal current of the current transformer 2 14 4 Information List Addr Parameter C Setting Options Default Setting Comments 4201 Ther OVERLOAD OFF ON Alarm Only OFF Thermal overload protec tion 4202 K FACTOR 0 10 4 00 1 10 K Factor 4203 TIME CONSTANT 1 0 999 9 min ...

Page 199: ... ms do not disturb the operational readiness of the device see for the Technical Data The processor monitors the reference voltage of the ADC analog to digital converter The protection is sus pended if the voltages deviate outside an allowable range and persistent deviations are reported Back up Battery The buffer battery which ensures the operation of the internal clock and the storage of counter...

Page 200: ...Σ I Factor kI address 221 I4 Iph CT takes into account a possible different ratio of a separate IE transformer e g cable core balance current transformer ΣI THRESHOLD and ΣI FACTOR are setting parameters The component ΣI FACTOR Σ I takes into account permissible current proportional ratio errors of the input transformers which are particularly prevalent during large fault currents Figure 2 83 Σ I ...

Page 201: ... with complete restart An additional software watchdog ensures that malfunctions during the processing of programs are discovered This also initiates a restart of the processor system If the fault is not eliminated by the restart a second restart attempt is initiated If the fault is still present after three restart attempts within 30 s the protection system will take itself out of service and the...

Page 202: ...The smallest phase voltage is compared to the largest Asym metry is recognized if Umin Umax BAL FACTOR U as long as Umax BALANCE U LIMIT Thereby Umax is the largest of the three phase to phase voltages and Umin the smallest The symmetry factor BAL FACTOR U address 2903 represents the allowable asymmetry of the voltages while the limit value BALANCE U LIMIT address 2902 is the lower limit of the op...

Page 203: ...e current has dropped to 0 A In case of a 1 1 2 circuit breaker arrangement the current will not necessarily jump to 0 in case of a wire break because the second primary current transformer will continue to measure one part of the phase current this means that the current of the affected phase will simply jump to a different value For such circuit breaker ar rangements parameter 2935 ΔI min is use...

Page 204: ...sured a phase current of more than 2 IN A phase current of such a magnitude is a certain indicator of a power system fault A wire break detected by the aforementioned criteria is transmitted to the device at the other end of the pro tected object and immediately prompts a broken wire report The differential protection function will also be blocked provided that it has been configured accordingly I...

Page 205: ...onitoring Voltage Phase Sequence The phase rotation of the measured voltages is checked by monitoring of the voltage phase sequence UL1 before UL2 before UL3 This check takes place if each measured voltage has a minimum magnitude of UL1 UL2 UL3 40 V 3 In case of negative phase rotation the indication Fail Ph Seq No 171 is issued ...

Page 206: ...1 Detection of asymmetrical measuring voltage failure The asymmetrical measured voltage failure is characterised by its voltage asymmetry with simultaneous current symmetry If there is substantial voltage asymmetry of the measured values without asymmetry of the currents being registered at the same time this indicates the presence of an asymmetrical failure in the voltage transformer secondary ci...

Page 207: ...tage failure a short circuit in the network is assumed and the signal VT FuseFail is immediately reset If the zero sequence voltage or the negative sequence voltage exceed the presettable value FFM U min address 2911 for more than 10 s the signal VT FuseFail 10s No 169 will be generated In this status a reset of the signal VT FuseFail will no longer be effected by means of an increase of the zero ...

Page 208: ... in this state if the three phase to earth voltages subsequently fall below the threshold value FFM U max 3ph address 2913 The effect of the signals VT FuseFail No 170 and VT FuseFail 10s No 169 on the protection functions is described in the following section Effect of the measuring voltage failure Additional Measured Voltage Failure Monitoring Fail U absent If no measuring voltage is available a...

Page 209: ... mistakenly see a voltage of zero In case that load currents exist simultaneously incorrect pickup could occur If such a voltage failure is detected the protection functions that operate on the basis of undervoltage are blocked Figure 2 91 shows the effect on the protection functions in case that a measuring voltage is detected by the fuse failure monitor VT FuseFail no 170 VT FuseFail 10s no 169 ...

Page 210: ... angles must be set as shown in Figure 2 92 In this example ϕA 200 and ϕB 340 has been set If the measured phase angle ϕ S1 of the positive sequence power is within the area of the P Q plane delimited by the angles ϕA and ϕB the indication ϕ PQ Pos Seq No 130 is output The angles ϕA and ϕB can be freely set in the range between 0 and 359 The area starts at ϕA and extends in a mathematically positi...

Page 211: ...r than the value set in parameter 2943 I1 The positive sequence voltage U1 is higher than the value set in parameter 2944 U1 The angles set in address 2941 ϕA and 2942 ϕB must be at least 3 apart Incorrect parameter settings cause the indication 132 ϕ Set wrong to be output The Fuse Failure Monitor and the measured voltage failure monitoring must not have responded and binary input indication 361 ...

Page 212: ...ce is taken out of operation After three unsuccessful restart attempts the device is taken out of service The device ready relay drops out and indicates the device failure with its NC contact life contact The red LED ERROR on the device front lights up provided that there is an internal auxiliary voltage and the green LED RUN goes off If the internal auxiliary voltage supply fails all LEDs are dar...

Page 213: ... 1 5 A jumper wrong Messages Protection out of operation Error1A 5Awrong 192 Error A D conv 181 LED ERROR DOK2 drops out Adjustment values Internal EEPROM or RAM Indication Use of default values Alarm adjustm 193 As allocated Modules Module does not comply with ordering number MLFB Messages Protection out of operation Error Board BG1 7 183 189 and if applicable Error A D conv 181 DOK2 drops out Cu...

Page 214: ...ing is effective Address 2905 BAL FACTOR I is the associated balance factor i e the gradient of the balance characteristic The indication Fail I balance no 163 can be delayed at address 2909 T BAL I LIMIT These settings can only be changed using DIGSI at Additional Settings Sum monitoring Address 2906 ΣI THRESHOLD determines the limit current above which the current sum monitoring is activat ed ab...

Page 215: ...E FAIL MON the Fuse Failure Monitor e g during asymmetrical testing can be switched OFF Three phase measuring voltage failure Fuse Failure Monitor The minimal voltage below which a three phase measured voltage failure is detected is set in address 2913 FFM U max 3ph unless a current step takes place simultaneously which exceeds the limit according to address 2914 FFM Idelta 3p These settings can o...

Page 216: ...A 0 10 2 00 A 0 25 A Summated Current Moni toring Threshold 5A 0 50 10 00 A 1 25 A 2907A ΣI FACTOR 0 00 0 95 0 50 Summated Current Moni toring Factor 2908A T BAL U LIMIT 5 100 sec 5 sec T Balance Factor for Voltage Monitor 2909A T BAL I LIMIT 5 100 sec 5 sec T Current Balance Monitor 2910 FUSE FAIL MON ON OFF ON Fuse Failure Monitor 2911A FFM U min 10 100 V 30 V Minimum Voltage Thresh old U 2912A ...

Page 217: ...t 169 VT FuseFail 10s OUT VT Fuse Failure alarm 10s 170 VT FuseFail OUT VT Fuse Failure alarm instantaneous 171 Fail Ph Seq OUT Failure Phase Sequence 196 Fuse Fail M OFF OUT Fuse Fail Monitor is switched OFF 197 MeasSup OFF OUT Measurement Supervision is switched OFF 289 Failure Σi OUT Alarm Current summation supervision 290 Broken Iwire L1 OUT Alarm Broken current wire detected L1 291 Broken Iwi...

Page 218: ...mplemented for each circuit breaker pole provided the required binary inputs are available 2 15 2 1 Function Description Supervision with Two Binary Inputs When using two binary inputs these are connected according to Figure 2 95 parallel to the associated trip contact on one side and parallel to the circuit breaker auxiliary contacts on the other A precondition for the use of the trip circuit sup...

Page 219: ...ct an abnormality a fault indication is output see Figure 2 96 The repeated measurements determine the delay of the alarm message and avoid that an alarm is output during short transition periods After clearance of the failure in the trip circuit the failure alarm automatically resets with the same time delay Figure 2 96 Logic diagram of the trip circuit supervision with two binary inputs Supervis...

Page 220: ...breaker auxiliary contact if the circuit breaker is closed or through the bypass resistor R 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 permanently deactivated during operation an interruption in the trip circuit or a failure of the trip control voltage can be assumed The trip circuit supervision ...

Page 221: ...nected to the trip circuits as the trip circuit supervision does not operate during a system fault If however trip contacts from other devices are connected in parallel in the trip circuit the alarm must be delayed such that the longest trip command duration can be reliably bridged 2 15 2 3 Settings 2 15 2 4 Information List Addr Parameter Setting Options Default Setting Comments 4001 FCT TripSupe...

Page 222: ...may be required or desirable Following a manual closure onto a short circuit immediate trip of the circuit breaker is usually desired This is done e g in the overcurrent protection by bypassing the delay time of specific stages For every short circuit protection function which can be delayed at least one stage can be selected that will operate instantaneously in the event of a closing as mentioned...

Page 223: ...ure the integrated manual closure logic of the 7SD610 auto matically distinguishes between an external control command via the binary input and an automatic reclosure by the internal automatic reclosure so that the binary input Manual Close can be connected directly to the control circuit of the close coil of the circuit breaker Figure 2 100 Each closing operation that is not initi ated by the int...

Page 224: ...ed with the manual CLOSE function via parameter 1152 Man Clos Imp Figure 2 99 Figure 2 101 Manual closing with external automatic reclosure device CB Circuit breaker TC Circuit breaker close coil CBaux Circuit breaker auxiliary contact Besides the manual CLOSE detection the device records any energization of the line via the integrated line energization detection This function processes a change o...

Page 225: ...g normal operation nor in case of a fault These settings can only be changed via DIGSI at Display Additional Settings The position of the auxiliary contacts of the circuit breakers directly indicate the position of the circuit breaker If the circuit breaker is controlled single pole energization takes place if at least one contact changes from open to closed The detected energization is signalled ...

Page 226: ...um amount of information Three binary inputs are used for this purpose CB Aux L1 No 351 for the auxiliary contact of pole L1 CB Aux L2 No 352 for the auxiliary contact of pole L2 CB Aux L3 No 353 for the auxiliary contact of pole L3 The inputs No 379 and No 380 are not used in this case If the circuit breaker can be switched individually two binary inputs are sufficient if both the parallel as wel...

Page 227: ...Functions 2 16 Function Control and Circuit Breaker Test SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 227 Figure 2 103 Circuit breaker position logic ...

Page 228: ...uit breaker can be connected separately to the device For this separate binary inputs are available which should be treated the same and configured additionally if necessary These have a similar significance as the inputs described above for protection applications and are marked with CB1 to distinguish them i e CB1 3p Closed No 410 for the series connection of the NO auxiliary contacts of the CB ...

Page 229: ...Functions 2 16 Function Control and Circuit Breaker Test SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 229 Figure 2 104 Open pole detector logic ...

Page 230: ... In the case of those protection functions that allow for phase segregated pickup the pickup is output in a phase segregated manner If a protection function detects an earth fault this is also output as a common device alarm Thus the alarms Relay PICKUP L1 Relay PICKUP L2 Relay PICKUP L3 and Relay PICKUP E are available The above alarms can be allocated to LEDs or output relays For the local displ...

Page 231: ...tection ov ervoltage protection or overload protection The binary input 1p Trip Perm is configured and activated or the internal automatic reclosure function is ready for reclosure after single pole tripping In all other cases tripping is always three pole The binary input 1p Trip Perm is the logic inversion of a three pole coupling and activated by an external auto reclosure device as long as thi...

Page 232: ...in the event of three pole tripping for each of the three poles refer to Figure 2 105 At the same time the minimum trip command duration TMin TRIP CMD address 240 is started This ensures that the trip command is output to the circuit breaker for a sufficiently long time even if the tripping protection function resets very rapidly The trip commands can only be reset after all tripping protection fu...

Page 233: ...ckets are used for protection testing it can be switched off with the setting Pickup Reset Figure 2 105 Storage and termination of the trip command Reclosure Interlocking When a protection function has tripped the circuit breaker it is often desired to prevent reclosing until the trip ping cause has been found 7SD610 enables this via the integrated reclosure interlocking The interlocking state LOC...

Page 234: ... or unintentional operation The interlocking state can also be controlled by internal sources using CFC e g a function key operation of the device or using DIGSI on a PC For each case please ensure that the corresponding logic operations security measures etc are taken into account when routing the binary inputs and outputs and may have to be considered when creating the user defined logic functio...

Page 235: ... the case during the reclaim time of the automatic reclosure cycle when the automatic reclosure is blocked or switched off or due to other reasons is not ready for automatic reclosure e g tripping only occurred after the action time expired Figure 2 108 shows time diagrams for manual trip and close as well as for short circuit tripping with a single failed automatic reclosure cycle Figure 2 108 Br...

Page 236: ...n and Circuit Breaker Test Where the circuit breaker auxiliary contacts indicate the status of the circuit breaker or of its poles to the device via binary inputs the test cycle can only be initiated if the circuit breaker is closed The information regarding the position of the circuit breakers is not automatically derived from the position logic according to the above section For the circuit brea...

Page 237: ...pontaneous fault indications on the display No Information Type of In formation Comments CB1tst L1 CB1 TEST trip close Only L1 CB1tst L2 CB1 TEST trip close Only L2 CB1tst L3 CB1 TEST trip close Only L3 CB1tst 123 CB1 TEST trip close Phases L123 7325 CB1 TESTtrip L1 OUT CB1 TEST TRIP command Only L1 7326 CB1 TESTtrip L2 OUT CB1 TEST TRIP command Only L2 7327 CB1 TESTtrip L3 OUT CB1 TEST TRIP comma...

Page 238: ...nly makes sense if address 625 T MIN LED HOLD is set to 0 Figure 2 111 Creation of the reset command for saved LED relays 2 16 3 2 Switching Statistics The number of trips initiated by the device 7SD610 are counted If the device is capable of single pole tripping a separate counter for each circuit breaker pole is provided Furthermore for each trip command the interrupted current for each pole is ...

Page 239: ... open after each startup of the device can be selected via parameter 640 Start image DD The available representation types for the measured value are listed in the Appendix 2 16 3 4 Settings Addresses which have an appended A can only be changed with DIGSI under Additional Settings 2 16 3 5 Information List Addr Parameter Setting Options Default Setting Comments 610 FltDisp LED LCD Target on PU Ta...

Page 240: ...tON OFF IntSP Protection ON OFF via system port 140 Error Sum Alarm OUT Error with a summary alarm 144 Error 5V OUT Error 5V 160 Alarm Sum Event OUT Alarm Summary Event 177 Fail Battery OUT Failure Battery empty 181 Error A D conv OUT Error A D converter 183 Error Board 1 OUT Error Board 1 184 Error Board 2 OUT Error Board 2 185 Error Board 3 OUT Error Board 3 186 Error Board 4 OUT Error Board 4 1...

Page 241: ...rogeneous environments In 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 16 4 2 Setting Notes Interface Selection No settings are required for operation of the Ethernet system interface module IEC 61850 EN100 Modul 1 If the device is equipped with such a module see MLFB the module ...

Page 242: ...he device can be simulated using the mouse pointer This feature can be disabled If the device is equipped with an EN100 module operation by DIGSI or the WEB Monitor is possible via Ether net This is done by simply setting the IP configuration of the device accordingly Parallel operation of DIGSI and WEB Monitor via different interfaces is possible WEB Monitor The WEB Monitor is a comprehensive com...

Page 243: ...hermore the browser enables a clear display of the most important measured data The measured values list can be selected from the navigation toolbar separately for the local and the remote device In each case a list with the desired information is displayed see Figures 2 112 and 2 114 Figure 2 113 Local measured values in the WEB Monitor Examples for measured values ...

Page 244: ...ions buffer event log Fault indications buffer trip log Spontaneous Indications You can print these lists with the Print event buffer button 2 17 1 2 Setting Notes The parameters of the WEB Monitor can be set separately for the front operator interface and the service in terface The relevant IP address of the interface is the one that is used for communication with the PC and the WEB Monitor Make ...

Page 245: ...if the self check feature of the microprocessor detects an abnormal occurrence or if the auxiliary voltage fails When auxiliary voltage is present but the relay has an internal malfunction the red LED ERROR lights up and the processor blocks the relay DIGSI enables you to selectively control each output relay and LED of the device and in doing so check the correct connection to the system In a dia...

Page 246: ...her be printed out or stored elsewhere for later evaluation A system fault starts with the detection of the fault by the fault detection of any protection function and ends with the reset of the fault detection of the last protection function or after the expiry of the auto reclose reclaim time so that several unsuccessful reclose cycles are also stored cohesively Accordingly a system fault may co...

Page 247: ...e Faults in the power system are indicated with Network Fault and the present fault number The fault indications contain detailed information on the response during system faults Fault Indications Following a system fault it is possible to retrieve important information regarding its progress such as pickup and trip The system clock accurately provides the absolute time when the fault first occurr...

Page 248: ...auto reclosure function 2 17 3 1 Function Description Counters and memories The counters and memories of the statistics are saved by the device Therefore the information will not get lost in case the auxiliary voltage supply fails The counters however can be reset to zero or to any value within the setting range Switching statistics can be viewed on the LCD of the device or on a PC running DIGSI a...

Page 249: ...s VI Number of breaker TRIP commands 1001 TripNo L1 VI Number of breaker TRIP commands L1 1002 TripNo L2 VI Number of breaker TRIP commands L2 1003 TripNo L3 VI Number of breaker TRIP commands L3 1027 Σ IL1 VI Accumulation of interrupted current L1 1028 Σ IL2 VI Accumulation of interrupted current L2 1029 Σ IL3 VI Accumulation of interrupted current L3 1030 Max IL1 VI Max fault current Phase L1 10...

Page 250: ...o earth voltages 3U0 UL1 UL2 UL3 All three voltage inputs must be phase earth connected for this Both devices connected via the protection interface form a joint frequency value constellation frequency This value is displayed as the operational measured value Frequency It allows to display a frequency even in devices in which local frequency measurement is not possible The constellation frequency ...

Page 251: ...V Rated operational voltage 32 3U0 Displacement Voltage kV V Rated operational voltage 32 ϕ UL1 UL2 ϕ UL2 UL3 ϕ UL3 UL1 Phase angle of the phase voltages towards each other ϕ UL1 IL1 ϕ UL2 IL2 ϕ UL3 IL3 Phase angle of the phase voltages towards the phase currents U1 U2 Positive and negative sequence com ponent of the voltages kV V Rated operational voltage 32 UX UEN Voltage at measuring input U4 V...

Page 252: ...VT 634 U1 MV U1 positive sequence 635 U2 MV U2 negative sequence 641 P MV P active power 642 Q MV Q reactive power 643 PF MV Power Factor 644 Freq MV Frequency 645 S MV S apparent power 679 U1co MV U1co positive sequence compounding 684 U0 MV U0 zero sequence 801 Θ Θtrip MV Temperat rise for warning and trip 802 Θ ΘtripL1 MV Temperature rise for phase L1 803 Θ ΘtripL2 MV Temperature rise for phase...

Page 253: ...mation List Measured Values Referred to IDiffL1 IDiffL2 IDiffL3 Calculated differential currents of the three phases Nominal operational current 1 IRestL1 IRestL2 IRestL3 Calculated restraining currents of the three phases Nominal operational current 1 IDiff 3I0 Calculated differential current of the zero sequence system Nominal operational current 1 No Information Type of In formation Comments 77...

Page 254: ...ossible devices are shown here by evaluating the device 1 see table 2 14 Information on the second device is given in the Appendix The computation of this measured values constellation is also performed during an existing system fault at an interval of approx 2 s The locally measured current voltage is used as a reference for the angle The angle values of the remote ends refer to the locally measu...

Page 255: ... SIGRA 4 The latter graphically represents the data recorded during the system fault and calculates additional information such as the impedance or r m s values from the measured values A selection may be made as to whether the currents and voltages are represented as primary or secondary values Binary signal traces marks of particular events e g fault detection trip ping are also represented If t...

Page 256: ...acity during the auto reclosure dead time s This parameter can only be altered with DIGSI at Ad ditional Settings The actual storage time begins at the pre fault time PRE TRIG TIME address 411 ahead of the reference instant and ends at the post fault time POST REC TIME address 412 after the storage criterion has reset The maximum recording duration to each fault MAX LENGTH is set at address 410 Th...

Page 257: ... above all a protection device The accuracy of the metered values depends on the instrument transformers normally protection core and the device tolerances The metering is therefore not suited for tariff purposes The counters can be reset to zero or any initial value see also SIPROTEC 4 System Description Table 2 15 Operational metered values 2 17 9 2 Setting Notes Retrieving parameters The SIPROT...

Page 258: ...List No Information Type of In formation Comments Meter res IntSP_Ev Reset meter 888 Wp puls PMV Pulsed Energy Wp active 889 Wq puls PMV Pulsed Energy Wq reactive 916 WpΔ Increment of active energy 917 WqΔ Increment of reactive energy 924 Wp MVMV Wp Forward 925 Wq MVMV Wq Forward 928 Wp MVMV Wp Reverse 929 Wq MVMV Wq Reverse ...

Page 259: ...escription under Control of Switchgear 2 18 1 Control Authorization 2 18 1 1 Type of Commands Commands to the Process These commands are directly output to the switchgear to change their process state Commands for the operation of circuit breakers of isolators and earthing disconnectors Step commands e g for raising and lowering transformer taps Setpoint commands with configurable time settings e ...

Page 260: ...peration interlocking against parallel switching operation Protection blocking blocking of switching operations by protection functions Fixed commands 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 Configuration in process if setting modification is in process commands are rejec...

Page 261: ...interlocking disable command via PROFIBUS Interlocked non interlocked Switching The configurable command checks in the SIPROTEC 4 devices are also called standard interlocking These checks can be activated via DIGSI interlocked switching tagging or deactivated non interlocked De interlocked or non interlocked switching means that the configured interlock conditions are not tested Interlocked switc...

Page 262: ...checks for each switchgear which were set during the configuration of inputs and outputs see SIPROTEC 4 System Description An overview for processing the interlocking conditions in the relay is shown in Figure 2 119 Figure 2 119 Standard interlockings 1 Source of Command REMOTE includes LOCAL LOCAL Command using substation controller REMOTE Command via telecontrol station to power system managemen...

Page 263: ...indicated Figure 2 120 Example of configured interlocking conditions Control Logic via CFC For bay interlocking a release logic can be created using CFC Via specific release conditions the information released or bay interlocked are available e g object Release CD Close and Release CD Open with the information values ON OFF 2 18 1 4 Information List Interlocking Commands Command Display Switching ...

Page 264: ...en Brk Close IntSP Interlocking Breaker Close Disc Open IntSP Interlocking Disconnect switch Open Disc Close IntSP Interlocking Disconnect switch Close E Sw Open IntSP Interlocking Earth switch Open E Sw Cl IntSP Interlocking Earth switch Close Q2 Op Cl CF_D2 Q2 Open Close Q2 Op Cl DP Q2 Open Close Q9 Op Cl CF_D2 Q9 Open Close Q9 Op Cl DP Q9 Open Close Fan ON OFF CF_D2 Fan ON OFF Fan ON OFF DP Fan...

Page 265: ... the serial digital interface The acknowledgement of commands is therefore not executed by a response indication as it is done with the local command but by ordinary command and feedback information recording Feedback monitoring Command processing time monitors all commands with feedback Parallel to the command a monitoring time period command runtime monitoring is started which checks whether the...

Page 266: ...nformation Type of In formation Comments Door open SP Cabinet door open CB wait SP CB waiting for Spring charged Err Mot U SP Error Motor Voltage ErrCntrlU SP Error Control Voltage SF6 Loss SP SF6 Loss Err Meter SP Error Meter Tx Temp SP Transformer Temperature Tx Danger SP Transformer Danger No Information Type of In formation Comments SysIntErr IntSP Error Systeminterface ...

Page 267: ...Functions 2 18 Command Processing SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 267 ...

Page 268: ...Functions 2 18 Command Processing SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 268 ...

Page 269: ...ng of protection and control systems with the management of power systems and with the relevant safety rules and guidelines Under certain circumstances adaptations of the hardware to the particular power system data may be necessary The primary tests require the protected object line transformer etc to carry load 3 1 Mounting and Connections 270 3 2 Checking Connections 289 3 3 Commissioning 295 3...

Page 270: ... in Appendix A 3 It must be checked that the setting of the P System Data 1 Section 2 1 2 1 was made in accordance to the device connections Currents Appendix A 3 shows current transformer connection examples in dependence on network conditions For normal connection address 220 I4 transformer In prot line must be set and furthermore address 221 I4 Iph CT 1 000 When using separate earth current tra...

Page 271: ...up Bit0 the other input for Set Group Bit1 To control two setting groups one binary input set for Set Group Bit0 is sufficient since the binary input Set Group Bit1 which is not assigned is considered to be not controlled The status of the signals controlling the binary inputs to activate a particular setting group must remain con stant as long as that particular group is to remain active The foll...

Page 272: ...en when circuit breaker auxiliary contact Aux1 is open and the command relay has dropped out The value of this resistor must be such that in the circuit breaker open condition Aux1 is open and Aux2 is closed the circuit breaker trip coil TC is no longer picked up and binary input BI1 is still picked up if the command relay contact is open Figure 3 2 Principle of the trip circuit supervision with o...

Page 273: ...th activated BI 1 8 mA UBI min Minimum control voltage for BI 17 V for delivery setting for nominal voltages of 24 48 60 V 73 V for delivery setting for nominal voltages of 110 125 220 250 V 154 V for delivery setting for nominal voltages of 220 250 V UCTR Control voltage for trip circuit RTC DC resistance of circuit breaker trip coil UCBTC LOW Maximum voltage on the circuit breaker trip coil that...

Page 274: ...ing Section at margin heading Processor Board C CPU 2 Rated Currents The input transformers of the device are set to a nominal current of 1 A or 5 A by burden switching The jumpers are factory set according to the name plate sticker The assignment of the jumpers to the nominal current and the spatial arrangement of the jumpers are described in the following section under the margin heading In put ...

Page 275: ... the voltage supply fails and the miniature fuse of the internal power supply Their spatial arrangement is shown in the figure of the processor module The ratings of the fuse are printed on the board next to the fuse When replacing the fuse please observe the guidelines given in the SIPROTEC 4 System Description in the chapter Maintenance and Corrective Maintenance 3 1 2 2 Disassembly Work on the ...

Page 276: ...e connectors under voltage The order of the boards is shown in Figure 3 3 Release the connector of the ribbon cable between processor module C CPU 2 and front cover at the front cover itself To do this spread the latches on the upper and lower end of the plug connector to release the plug connector of the ribbon cable Disconnect the ribbon cables between the processor board C CPU 2 No 1 in Figure ...

Page 277: ...ble 3 2 the quiescent state of the life contact accord ing to Table 3 3 the selected control voltages of the binary inputs BI1 to BI5 according to Table 3 4 and the integrated RS232 RS485 interface according to Table 3 5 to 3 7 The location and ratings of the miniature fuse F1 and of the buffer battery G1 are shown in the following figure Before checking the integrated RS232 RS485 interface it may...

Page 278: ...AC 250 V By repositioning jumpers the interface RS485 can be modified into a RS232 interface and vice versa Jumpers X105 to X110 must be set to the same position Table 3 5 Jumper settings of the integrated RS232 RS485 Interface on the C CPU 2 processor board The jumpers are preset at the factory according to the configuration ordered Jumper Nominal voltage DC 24 V to 48 V DC 60 V to 125 V DC 110 V...

Page 279: ...setting can be selected optionally We recommend to use a standard RS232 modem connection cable converter 9 pin to 25 pin Note For a direct connection to DIGSI with interface RS232 jumper X111 must be plugged in position 2 3 If there are no external terminating resistors in the system the last devices on a RS485 bus must be configured via jumpers X103 and X104 Table 3 7 Jumper settings of the Termi...

Page 280: ...figuration settings Table 3 8 Jumper settings for Control Voltages of the binary inputs BI6 and BI7 on the input output board C I O 11 1 Factory settings for devices with power supply voltages of DC 24 V to 125 V 2 Factory settings for devices with power supply voltages of DC 110 V to 250 V 3 Use only with pickup voltages of DC 220 V to 250 V and AC 230 V Binary input Jumper 17 V Threshold 1 73 V ...

Page 281: ... one jumper X61 to X64 for each input trans former of the phase currents and in addition the common jumper X60 Jumper X64 is plugged in position IE Jumpers X71 X72 and X73 on the input output board C I O 11 are used for setting the bus address and must not be changed The following Table lists the jumper presettings Table 3 9 Jumper settings of Bus Address of the input output board C I O 11 Slot of...

Page 282: ...s SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 282 3 1 2 4 Interface Modules Exchanging Interface Modules The interface modules are located on the processor board C CPU 2 No 1 in Figure 3 3 Figure 3 7 C CPU 2 board with interface modules ...

Page 283: ... to interface RS485 and vice versa see Figures 3 8 and 3 9 Figure 3 7 shows the C CPU 2 PCB with the layout of the modules The following figure shows the location of the jumpers of interface RS232 on the interface module Surface mounted devices with fibre optics connection have their fibre optics module fitted in the console housing on the case bottom The fibre optics module is controlled via an R...

Page 284: ...he half duplex mode Please use the connection cable with order number 7XV5100 4 Jumper setting 1 2 This setting makes the modem signals available i e for a direct RS232 connection between the SIPROTEC 4 device and the modem this setting can be selected optionally We recommend to use a standard RS232 modem connection cable converter 9 pin to 25 pin Note For a direct connection to DIGSI with interfa...

Page 285: ...DBUS interfaces The terminating resistors are located on the interface module which is on the processor module C CPU 2 no 1 in Figure 3 3 or directly on the PCB of the processor module C CPU 2 see margin heading Processor module C CPU 2 Table 3 7 The interface modules are displayed in Figure 3 9 and in Figure3 10 For the configuration of the terminating resistors both jumpers have to be plugged in...

Page 286: ...ing For 7SD610 Picture 3 12 4 covers and 4 holes exist Remove the 4 covers at the corners of the front cover Thus 4 elongated holes are revealed in the mounting bracket and can be accessed Insert the device into the control panel section and tighten it with 4 screws For dimensions refer to Section 4 17 Replace the 4 covers Connect a solid low impedance protective earthing at the rear of the device...

Page 287: ...Tighten fast the eight screws of the angle brackets in the rack or cabinet Connect a solid low impedance protective earthing at the rear of the device with at least one M4 screw The cross section of the earth wire must be equal to the cross section of any other control conductor connected to the device The cross section of the earth wire must be at least 2 5 mm 2 Make the connections on the device...

Page 288: ...must be equal to the cross sectional area of any other control conductor connected to the device It must thus be at least 2 5 mm2 Alternatively there is the possibility to connect the aforementioned earthing to the lateral earthing surface with at least one M4 screw Make the connections according to the circuit diagram via screw terminals connections for optical fibres and electrical communication...

Page 289: ... the Ethernet interface of the device The position of the connectors is depicted in the fol lowing figures Figure 3 14 9 pin D subminiature female connectors Figure 3 15 Ethernet connector Operator Interface When the recommended communication cable is used correct connection between the SIPROTEC 4 device and the PC is automatically ensured See the Appendix A 1 for an ordering description of the ca...

Page 290: ...terfaces 1 Pin 7 may also carry the RS232 RTS signal on an RS485 interface Pin 7 must therefore not be connected RS485 Termination The RS485 interface is capable of half duplex service with the signals A A and B B with a common relative potential C C GND It is necessary to check that the terminating resistors are connected to the bus only at the last unit and not at other devices on the bus The ju...

Page 291: ...ng to EN 60825 1 For the protection data communication refer to the following section The transmission via fiber optics is particularly insensitive to electromagnetic interference and thus ensures gal vanic isolation of the connection Transmit and receive connections are shown with the symbols for trans mit and for receive The character idle state for the optical fibre interface is Light off If th...

Page 292: ...st be connected to the data input of the other device and vice versa Transmission and receiving connections are identified with the symbols for trans mit and for receive The visual check of the assignment of the transmission and reception channels is important For short distances laser class 1 is fulfilled if FO5 modules and the recommended fibres are used In other cases the laser output may be hi...

Page 293: ...final location The plant must first be switched off and earthed Connection examples for current transformer connections are provided in Appendix A 3 Please observe the plant diagrams too Proceed as follows in order to check the system connections Protective switches for the power supply and the measured voltages must be switched off Check the continuity of all current and voltage transformer conne...

Page 294: ...auxiliary voltage supply protection check the voltage level and if applicable the po larity of the voltage at the device terminals or at the connection modules The measured steady state current should correspond to the quiescent power consumption of the device Transient movement of the ammeter merely indicates the charging current of capacitors Remove the voltage from the power supply by opening t...

Page 295: ...onditions to be firmly established before the device is re energized The limit values given in Technical Data must not be exceeded neither during testing nor during commission ing For tests with a secondary test equipment ensure that no other measurement voltages are connected and the trip and close commands to the circuit breakers are blocked unless otherwise specified DANGER Hazardous voltages d...

Page 296: ...PROTEC 4 System Description describes how to activate and deactivate test mode and blocked data transmission Note that when DIGSI is being used the program must be in the Online operating mode for the test features to be used 3 3 2 Test Time Synchronisation Interface If external time synchronization sources are used the data of the time source antenna system time generator are checked see Section ...

Page 297: ...oning Do not under any circumstances check them by means of the testing mode during real operation performing transmission and reception of messages via the system interface Note After termination of the hardware test the device will reboot Thereby all annunciation buffers are erased If required these buffers should be extracted with DIGSI prior to the test The interface test is carried out using ...

Page 298: ...smitted to the central station test in Setpoint the desired options in the list which appears Make sure that each checking process is carried out carefully without causing any danger see above and refer to DANGER Click on Send and check whether the transmitted information reaches the control centre and shows the desired reaction Data which are normally linked via binary inputs first character are ...

Page 299: ...via the system interface Note After termination of the hardware test the device will reboot Thereby all annunciation buffers are erased If required these buffers should be extracted with DIGSI 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 fu...

Page 300: ...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 means that e g a TRIP command coming from a protection function or a control command from the operator panel to an output relay cannot be executed Proceed as follows in order to check the output relay Make sure that the switching operations c...

Page 301: ...he LEDs The light emitting diodes LEDs may be tested in a similar manner to the other input output components As soon as the first state change of any LED has been triggered all LEDs are separated from the internal device functionality and can only be controlled via the hardware test function This means e g that no LED is illumi nated anymore by a protection function or by pressing the LED reset b...

Page 302: ... If you choose to work with the WEB Monitor please note the Help files referring to the WEB Monitor You can either connect the PC to the device locally using the operator interface at the front or the service in terface at the back of the PC Figure 3 18 Or you can log into the device using a modem via the service in terface example in Figure 3 19 Figure 3 18 PC interfacing directly to the device e...

Page 303: ...ee the message PI1 Data fault No 3229 In this case recheck the fibre optical cable link Have the devices been linked correctly and no cables been mixed up Are the cables free from mechanical damage intact and the connectors locked Otherwise repeat check Continue with the margin heading Consistency of Topology and Parameterization Checking a Link with a Communication Converter If a communication co...

Page 304: ...SI Address 4502 CONNEC 1 OVER F optic direct when you are testing protection data interface 1 Check the operating indications or in the spontaneous annunciations Message 3217 PI1 Data reflec Protection interface 1 data reflection ON when you test protec tion data interface 1 If the indication is not transmitted check for the following Has the 7SD610 fibre optical transmitting terminal output been ...

Page 305: ... of all transmission media Therefore check the statistic information of the device Check the following indications Indication No 7753 PI1A m availability per minute and indication No 7754 PI1A h availability per hour indicate the availability of protection data interface 1 The value of No 7753 PI1A m should attain a minimum per minute availability of 99 85 after two minutes of operation The value ...

Page 306: ... topology invalid are displayed in a red bar The display of the circuit breaker positions is integrated into the topology display Closed circuit breakers are displayed in green opened circuit breakers are displayed in red and circuit breakers in an undefined state are displayed in grey An LED is used to select whether the communication topology or the protection topology is to be displayed for the...

Page 307: ...rotection data interface statistics of the device The values for the trans fer times and the availability are displayed Both RX and TX direction of the transmission delay times are dis played symmetric conditions are assumed if there is no GPS synchronisation In this case the values dis played for the transfer time are identical Status Colour of the connection display Remark OK green The connectio...

Page 308: ...sconnectors and busbar disconnectors should be open so that the breaker can be operated without risk Caution Also for tests on the local circuit breaker of the feeder a trip command to the surrounding circuit breakers can be issued for the busbar Non observance of the following measure can result in minor personal injury or property damage First disable the trip commands to the adjacent busbar bre...

Page 309: ...s Trip command dependent on settings Start by 3 pole trip command of the external protection via all three binary inputs L1 L2 and L3 Binary input functions BF Start L1 BF Start L2 and BF Start L3 and if necessary BF release in spontaneous or fault indications 3 pole trip command For 3 pole initiation Start by 3 pole trip command of the external protection Binary input functions BF Start 3pole and...

Page 310: ...s of One Line End If secondary test equipment is connected to the device it is to be removed or if applying test switches should be in normal operation position Note It must be taken into consideration that tripping can occur even at the opposite end of the protected object if wrong connections were made Before energizing the protected object at one end short circuit protection must be ensured at ...

Page 311: ...a value that is 3 larger The measurements have to be repeated after correcting the connections In general the phase rotation is clockwise If the system has an anti clockwise phase rotation this must be identical at all ends of the protected object The phase assignment of the measured quantities has to be checked and if required corrected after the line has been switched off The measurement must th...

Page 312: ...he absolute values so that the correct phase sequence and polarity of individual transformers can also be seen The WEB Monitor allows convenient readout of all measured values with visualization by means of phasor diagrams Figure 3 24 The current amplitudes must be approximately the same All three angles ϕ ILx ILy must be approximately 120 If the measured values are not plausible the connections m...

Page 313: ...ically swapped phases can easily be detected The measured power values on the actual device or in DIGSI enable you to verify that they correspond to the load direction Figure 3 26 P positive if active power flows into the protected object P negative if active power flows toward the busbar Q positive if reactive power flows into the protected object Q negative if reactive power flows toward the bus...

Page 314: ... may have to be repeated after correcting the connections The above described tests of the measured quantities also have to be performed at the other end of the tested current path The current and voltage values as well as the phase angles of the other end can also be read out locally as percentage values Please observe that currents flowing through the object without charging currents ideally hav...

Page 315: ...y the current from the current transformer in the phase from which the voltage in the voltage path is missing is connected the other CTs are short circuited If the line carries resistive inductive load the protection is in principle subject to the same conditions that exist during an earth fault in the direction of the line The voltages can be read on the display at the front or called up in the P...

Page 316: ...r in DIGSI in the measured values The differential currents must be low at least one scale less than the currents flowing through If high charging currents are to be expected in long overhead lines or cables these are additionally included in the differential currents The maximum values of the read measured values for the charging current 3 values are converted to Ampere and entered in I DIFF The ...

Page 317: ...or this purpose This remote trip signal may be derived from both an internally gen erated trip signal as well as from any signal coming from an external protection or control device If an internal signal is used the initiation of the transmitter must be checked If the signal transmission path is the same and has already been checked as part of the previous sections it need not be checked again her...

Page 318: ...s No 351 to 353 379 and 380 according to the possibilities of the auxiliary contacts additionally the corre sponding No 366 to 368 or 410 and or 411 must be allocated according to the possibilities of the auxiliary con tacts In the CB test only the latter ones are analyzed See also Section 2 16 2 Furthermore the ready state of the circuit breaker for the CB test must be indicated to the binary inp...

Page 319: ... case a fault record is triggered e g via binary input when the protected object is energized Such a test fault record triggered externally i e not caused by pickup of a protection function is processed like a normal oscillographic record i e a fault log with number is generated which univocally identifies an oscillo graphic record However these recordings are not displayed in the trip log as they...

Page 320: ...Further details on this subject are described in 1 The indication buffers are deleted under Main Menu Annunciation Set Reset so that in the future they only contain information on actual events and states The numbers in the switching statistics should be reset to the values that were existing prior to the testing The counters of the operational measured values e g operation counter if available ar...

Page 321: ...l protection topology 334 4 3 Differential Protection 338 4 4 Restricted Earth Fault Protection 340 4 5 Breaker Intertrip and Remote Tripping Direct Local Trip 341 4 6 Transmission of Binary Information optional 342 4 7 Instantaneous High Current Switch onto Fault Protection SOTF 343 4 8 Backup Time Overcurrent Protection 344 4 9 Automatic Reclosure optional 351 4 10 Voltage Protection optional 35...

Page 322: ... s 150 A for 10 s 4 IN continuous dynamic pulse 1250 A half cycle 1 Condition for maximum fault current current transformers must not be saturated stationary 2 Condition The operational accuracy limit factor must at least be 30 or a non saturated period t AL of at least 1 4 must be ensured n 30 or t AL 1 4 AC cycle 3 Condition Maximum ratio between primary currents of current transformers at the e...

Page 323: ...ak to peak IEC60255 11 15 of the nominal auxiliary voltage Power Input Quiescent Approx 6 5 W Energized Approx 10 W Plus approx 1 5 W per interface module Bridging time for failure short circuit of DC auxiliary voltage 50 ms at UAux 48 V and UAux 110 V 20 ms at UAux 24 V and UAux 60 V Voltage Supply via Integrated Converter Nominal auxiliary voltage AC UAux AC 115 V 230 V AC 230 V release CC and h...

Page 324: ...geable via jumpers For nominal voltages DC 24 V 48 V and DC 60 V 110 V 125 V Uhigh DC 19 V Ulow DC 10 V For nominal voltages DC 110 V 125 V 220 V 250 V Uhigh DC 88 V Ulow DC 44 V For nominal voltages DC 220 V 250 V Uhigh DC 176 V Ulow DC 88 V Current consumption energized Approx 1 8 mA Independent of the control voltage Maximum Permissible Voltage DC 300 V Impulse filter on input 220 nF coupling c...

Page 325: ...current per contact close and hold 30 A for 0 5 s NO contact Permissible total current on common path contacts 5 A continuous 30 A for 0 5 s Permissible relative closing time Operating time approx 8 ms 5 ms 8 ms Alarm relay 1 With 1 NC contact or 1 NO contact switchable Switching capacity MAKE 1000 W VA OPEN 30 VA 40 W ohmic 25 VA at L R 50 ms Switching voltage 250 V Permissible Current per Contac...

Page 326: ...E1 Transmission distance 15 m 50 feet RS232 RS485 FO Acc to ordered version Isolatede interface for data transfer Operation with DIGSI RS232 RS485 RS232 RS485 according to ordered variant Connection for flush mounting housing Rear panel mounting location C 9 pole D subminiature female connector Shielded data cable For Panel Surface Mounted Case Shielded data cable at the terminal at the case botto...

Page 327: ...connector Test voltage 500 V 50 Hz Transmission rate min 4800 Baud max 38400 Baud Factory setting 19200 Bd Bridgeable distance Max 1 km Fibre optic cable FO FOC connector type ST connector Connection for flush mounting housing rear panel mounting location B For Panel Surface Mounted Case in console housing at case bottom Optical wavelength λ 820 nm Laser Class I according to EN 60825 1 2 using gla...

Page 328: ...tate status for No charac ter Light OFF Max number of modules in optical rings with 500 kB s or 1500 kB s 41 DNP3 0 MODBUS RS485 Connection for flush mounting housing Rear panel slot B 9 pole D subminiature female connector Connection for surface mounting housing in console housing Test voltage 500 V 50 Hz Transmission rate Up to 19200 Baud Bridgeable distance Max 1 km DNP3 0 MODBUS FO FOC connect...

Page 329: ...ram format IRIG B000 GPS Connection for flush mounting housing rear panel mounting location A 9 pole D subminiature female connector for surface mounting case at two tier terminals on the case bottom Nominal signal voltages DCF77 IRIG B Selectable 5 V 12 V or 24 V Nominal signal voltages GPS 24 V Test voltage 500 V 50 Hz Signal levels and burdens DCF77 IRIG B Nominal signal input voltage 5 V 12 V ...

Page 330: ...255 22 1 Class III and VDE 0435 Section 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 frequency sweep IEC 60255 22 3 Class III IEC 61000 4 3 Class III IEEE Std C37 90 2 2004 10 V m and 2...

Page 331: ...lue polarity alternating 100 kHz 1 MHz Ri 200 Ω Standard EN 61000 6 3 generic standard Radio noise voltage to lines only auxiliary voltage IEC CISPR 22 150 kHz to 30 MHz Limit class B 1 Interference field strength IEC CISPR 22 30 MHz to 1000 MHz Limit class B 1 Harmonic currents on the network lead at 230 VAC IEC 61000 3 2 IEC 61000 3 2 Class A limits are observed Voltage fluctuations and flicker ...

Page 332: ... or 13 F to 185 F Permissible temporary operating temperature tested for 96 h 20 C to 70 C or 4 F to 158 F legibility of display may be restricted from 131 F 55 C Recommended for permanent operation according to IEC 60255 6 5 C to 55 C or 23 F to 131 F when max half of the inputs and outputs are subjected to the max permissible values Limit Temperatures for Storage 25 C to 55 C or 13 F to 131 F Li...

Page 333: ...s no special measures are normally required For substations with lower operating voltages no special measures are normally required When removed many com ponents are electrostatically endangered when handling the EEC standards standards for Electrostatically Endan gered Components must be observed The modules boards and device are not endangered when the device is com pletely assembled Housing 7XP...

Page 334: ...dules for protection data interface depending on the order variant FO5 FO30 IEEE C37 94 Distance maximum 1 5 km or 0 9 miles Connector Type ST connector Optical wavelength λ 820 nm Fibre Type Multimode 62 5 μm 125 μm Transmit output peak Min Type max 50 μm 125 μm NA 0 21 62 5 μm 125 μm NA 0 2751 19 8 dBm 16 0 dBm 15 8 dBm 12 0 dBm 12 8 dBm 9 0 dBm Receiver sensitivity peak Optical power for high l...

Page 335: ... glass fibre 62 5 μm 125 μm and 50 μm 125 μm Reach for multimode optical fibre an optical signal attenuation of 3 dB km is used for calculating light with a wavelength of λ 820 nm Attenuators required no FO17 Distance maximum 24 km or 14 9 miles Connector Type LC duplex connector SFF IEC 61754 20 Standard Protocol full duplex Baudrate 155 MBits s Receiver interfacing AC Optical wavelength λ 1300 n...

Page 336: ...ed in Monomodefaster min 5 0 dBmavg max 0 dBmavg Receiver sensitivity min 34 0 dBmavg max 34 5 dBmavg Optical budget 29 0 dB Laser Class 1 according to EN 60825 1 2 Using glass fibre 9 µm 125 µm Reach for multimode optical fibre an optical signal attenuation of 0 3 dB km is used for calculating light with a wavelength of λ 1300 nm Attenuators required for distances of less than 25 km 15 5 miles 1 ...

Page 337: ... see Appendix A 1 Section Accessories Supported network interfaces G703 1 with 64 kbit s G703 T1 with 1 455 Mbit s G703 E1 with 2 048 Mbit s X 21 mit 64 kBit s oder 128 kBit s oder 512 kBit s Pilot wires with 128 Kbits s Connection to communication converter see Table above under module FO5 Transmission rate 64 kbit s with G703 1 1 455 Mbit s for G703 T1 2 048 Mbit s for G703 E1 512 kbit s or 128 ...

Page 338: ...stage disabled Increment 0 01 A IN 5 A 4 00 to 500 00 A or stage disabled Tolerances 5 of set value or 1 IN per end The operating times depend on the communication speed The following data require a transfer rate of 512 kbit s Pickup trip times of the I DIFF stages at 50 or 60 Hz approx minimum 16 ms typical 20 ms Dropout time of the I DIFF stages approx typical 35 ms to 50 ms Pickup trip times of...

Page 339: ...ions delay time differences har monics synchronous quality jitter Restraint ratio 2 Inrush stabilization I2fN IfN 0 to 45 Steps 1 Max current for restraint IN 1 A 1 1 A to 25 0 A Increment 0 1 A IN 5 A 5 5 A to 125 0 A Crossblock Function Can be switched on off Max action time for crossblock CROSSB 2HM 0 00 s to 60 00 s or 0 crossblock disabled or active until dropout Increments 0 01 s Matching of...

Page 340: ...Differential current IREF for IN 1 A 0 05 A to 2 00 A Increment 0 01 for IN 5 A 0 25 A to 10 00 A Threshold angle ϕLimit 100 fixed Trip Characteristic see Figure below Pickup tolerance for ϕ 3I0 3I0 90 and address 221 I4 Iph CT and address 4113 SLOPE 5 0 01 IN Delay time TEDS 0 00 s to 60 00 s or no trip Increments 0 01 s Expiry tolerances 1 of set value or 10 ms The set times are pure delay times...

Page 341: ...0 s to 30 00 s or ineffective Increments 0 01 s Time tolerance 1 of setting value or 10 ms The set times are pure delay times Tripping of remote ends by a command that is coupled into a binary input The operating times depend on the communication speed The following data require a transmission rate of 512 kBit s Operating times total approx minimum 12 ms typical 17 ms Dropout times total approx ty...

Page 342: ...mes refer to the entire signal path from entry via binary inputs until output of commands via output relays Operating times total approx minimum 13 ms typical 17 ms Dropout times total approx typical 24 ms Number of possible remote signals 24 The operating times depend on the communication speed The following data require a transmission rate of 512 kBit s The operating times refer to the entire si...

Page 343: ... Fault Protection SOTF Pickup Times High current pickup I for IN 1 A 0 10 A to 15 00 A or disabled Increment 0 01 A for IN 5 A 0 50 A to 75 00 A or disabled High current pickup I for IN 1 A 1 00 A to 25 00 A or disabled Increment 0 01 A for IN 5 A 5 00 A to 125 00 A or disabled Dropout to pickup ratio Approx 90 Pickup tolerance 3 of setting value or 1 of IN Shortest trip time Approx 10 ms ...

Page 344: ...Ph ger 3I0 ger Inverse time stages IDMT IP 3I0P IPger 3I0Pger one of the characteristics according to 4 2 to Figure 4 4 can be selected Pickup value Iph phases for IN 1 A 0 10 A to 25 00 A or ineffective Increment 0 01 A for IN 5 A 0 50 A to 125 00 A or ineffective Pickup value 3I0 PICKUP earth for IN 1 A 0 05 A to 25 00 A or ineffective Increment 0 01 A for IN 5 A 0 25 A to 125 00 A or ineffectiv...

Page 345: ... IN 1 A 0 05 A to 25 00 A or disabled Increment 0 01 A for IN 5 A 0 25 A to 125 00 A or disabled Delays T Iph STUB 0 00 s to 30 00 s or ineffective Increments 0 01 s T 3I0 STUB 0 00 s to 30 00 s or ineffective Increments 0 01 s Pickup thresholdIph Dir directional phases for IN 1 A 0 10 A to 25 00 A or disabled Increment 0 01 A for IN 5 A 0 50 A to 125 00 A or disabled Pickup threshold3I0 Dir Earth...

Page 346: ...etting value or 15 ms 5 of setting value or 15 ms Defined times 1 of setting value or 10 ms Pickup value Ip Dir I directional phases for IN 1 A 0 10 A to 4 00 A or disabled Increment 0 01 A for IN 5 A 0 50 A to 20 00 A or disabled Pickup threshold3I0p Dir Earth directional for IN 1 A 0 05 A to 4 00 A or disabled Increment 0 01 A for IN 5 A 0 25 A to 20 00 A or disabled Time factors directional sta...

Page 347: ...d D3I0P 1 s 5 of setting value or 15 ms 5 of setting value or 15 ms Defined times 1 of setting value or 10 ms Pickup value Ip Dir I directional phases for IN 1 A 0 10 A to 4 00 A or disabled Increment 0 01 A for IN 5 A 0 50 A to 20 00 A or disabled Pickup value 3I0p Dir I directional earth for IN 1 A 0 05 A to 4 00 A or disabled Increment 0 01 A for IN 5 A 0 25 A to 20 00 A or disabled Time factor...

Page 348: ...l Data 4 8 Backup Time Overcurrent Protection SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 348 Figure 4 2 Trip time characteristics of inverse time overcurrent stage acc IEC phases and earth ...

Page 349: ...ata 4 8 Backup Time Overcurrent Protection SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 349 Figure 4 3 Trip time characteristics of inverse time overcurrent stage acc ANSI IEEE phases and earth ...

Page 350: ...ata 4 8 Backup Time Overcurrent Protection SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 350 Figure 4 4 Trip time characteristics of inverse time overcurrent stage acc ANSI IEEE phases and earth ...

Page 351: ...o 1800 00 s Increments 0 01 s Reclaim time after reclosure 0 50 s to 300 00 s Increments 0 01 s Blocking time after dynamic blocking 0 5 s Blocking time after manual closing 0 50 s to 300 00 s 0 Increments 0 01 s Start signal monitoring time 0 01 s to 300 00 s Increments 0 01 s Circuit breaker monitoring time 0 01 s to 300 00 s Increments 0 01 s Adaptive dead time With voltage measurement or with ...

Page 352: ...lue or 10 ms Overvoltage UPhPh 2 0 V to 220 0 V Increments 0 1 V Delay TUPhPh 0 00 s to 100 00 s Increments 0 01 s Overvoltage UPhPh 2 0 V to 220 0 V Increments 0 1 V Delay TUPhPh 0 00 s to 100 00 s Increments 0 01 s Drop off to pickup ratio 0 30 to 0 99 Increment 0 01 Pickup time Approx 40 ms Dropout time Approx 35 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of set value or 10 ms Ove...

Page 353: ...elay T3U0 0 00 s to 100 00 s Increments 0 01 s Overvoltage U0 1 0 V to 220 0 V Increments 0 1 V Delay T3U0 0 00 s to 100 00 s Increments 0 01 s Drop off to pickup ratio 0 30 to 0 99 Increment 0 01 Pickup time With repeated measurement Approx 75 ms Without repeated measurement Approx 40 ms Dropout time With repeated measurement Approx 75 ms Without repeated measurement Approx 35 ms Tolerances Volta...

Page 354: ...o 1 01 to 1 20 Increment 0 01 Current criterion Can be switched on off Pickup time Approx 40 ms Dropout time Approx 35 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of set value or 10 ms Undervoltage U1 1 0 V to 100 0 V Increments 0 1 V Delay TU1 0 00 s to 100 00 s Increments 0 01 s Undervoltage U1 1 0 V to 100 0 V Increments 0 1 V Delay TU1 0 00 s to 100 00 s Increments 0 01 s Drop off...

Page 355: ... 50 Hz Increments 0 01 Hz Pickup times f f Approx 85 ms Dropout times f f Approx 30 ms Delay times T 0 00 s to 600 00 s Increments 0 01 s The set times are pure delay times Note on dropout times Dropout was enforced by current 0 A and voltage 0 V Enforcing the dropout by means of a frequency change below the dropout threshold extends the dropout times Δf pickup value dropout value Approx 20 mHz In...

Page 356: ...ection can also operate without the indicated circuit breaker auxiliary contacts but the func tion range is then reduced Auxiliary contacts are necessary for the circuit breaker failure protection for tripping without or with a very low current flow e g Buchholz protection and for stub fault protection and circuit breaker pole discrepancy supervision For circuit breaker failure protection Internal...

Page 357: ... min Thermal Alarm ΘAlarm ΘTrip 50 to 100 of the trip overtemperature Increments 1 Current Overload IAlarm for IN 1 A 0 10 A to 4 00 A Increments 0 01 A for IN 5 A 0 50 A to 20 00 A Calculation method temperature rise Maximum temperature rise of 3 phases Average of temperature rise of 3 phases Temperature rise from maximum current Θ ΘTrip Θ ΘAlarm I IAlarm Drops out with ΘAlarm Approx 0 99 Approx ...

Page 358: ...Technical Data 4 13 Thermal Overload Protection SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 358 Figure 4 5 Trip time characteristics of the overload protection ...

Page 359: ...Increment 0 01 BAL ULIMIT 10 V to 100 V Increment 1 V T BAL ULIMIT 5 s to 100 s Increments 1 s Voltage phase sequence UL1 leads UL2 leads UL3 as long as UL1 UL2 UL3 40 V v3 Asymmetrical measuring voltage failure Fuse Failure Monitor 3 U0 FFM U OR 3 U2 FFM U AND simultaneously 3 I0 FFM I AND 3 I2 FFM I FFM U 10 V to 100 V Increments 1 V FFM I for IN 1 A 0 10 A to 1 00 A Increment 0 01 A for IN 5 A ...

Page 360: ...sured value comparison X X X X CONNECT Connection X X X COUNTER Counter X X X X CV_GET_STATUS Information status of the metered value decoder X X X X D_FF D Flipflop X X X D_FF_MEMO Status Memory for Restart X X X X DI_GET_STATUS Information status double point indication decoder X X X X DI_SET_STATUS Double point indication with status encoder X X X X DI_TO_BOOL Double Point to Boolean conversion...

Page 361: ...ion X Description Limit Comments Maximum number of all CFC charts considering all task levels 32 When the limit is exceeded an error message is output by the device Conse quently the device is put into monitoring mode The red ERROR LED lights up Maximum number of all CFC charts considering one task level 16 Only error message evolving error in processing procedure Maximum number of all CFC inputs ...

Page 362: ...evice i e 5 ms otherwise the blocks will not start with the starting impulse issued Maximum Number of TICKS in the Task Levels 1 When the sum of TICKS of all blocks exceeds the limits before mentioned an error message is output by CFC Description Limit Comments Maximum number of concurrent changes to planned inputs per task level Chart inputs per task level 50 When the limit is exceeded an error m...

Page 363: ...tion to an input signal 6 Connection to an output signal 7 Additional for each chart 1 Operating sequence module CMD_CHAIN 34 Flipflop D_FF_MEMO 6 Loop module LOOP 8 Decoder DM_DECODE 8 Dynamic OR DYN_OR 6 Addition ADD 26 Subtraction SUB 26 Multiplication MUL 26 Division DIV 54 Square root SQUARE_ROOT 83 Timer TIMER_SHORT 8 Timer LONG_TIMER 11 Blinker lamp BLINK 11 Counter COUNTER 6 Adaptor REAL_T...

Page 364: ...voltage and nominal current Operational Measured Values for Powers S P Q apparent active and reactive power in MVA MW Mvar primary and SN operational nominal power 3 UN IN Tolerance for S 1 of SN at I IN and U UN in range 50 to 120 Tolerance for P 1 of PN at I IN and U UN in range 50 to 120 and ABS cos ϕ in range 0 7 Tolerance for Q 1 of QN at I IN and U UN in range 50 to 120 and ABS cos ϕ in rang...

Page 365: ... rate at fN 60 Hz 0 83 ms Availability of transmission for applications with protec tion data interface Availability in min and h Delay time of transmission Resolution 0 01 ms Number of trip events caused by the device Separately for each breaker pole if single pole tripping is possi ble Number of automatic reclosures initiated by the device Separate for 1 pole and 3 pole AR Separately for 1st AR ...

Page 366: ...ter 2 IEC 60870 5 103 External synchronisation using system interface IEC 60870 5 103 or Timing Master 3 Time signal IRIG B External synchronisation via IRIG B telegram format IRIG B000 or Timing Master 4 Time signal DCF 77 External synchronisation via DCF 77 or Timing Master 5 Time signal synchro box External synchronisation using SIMEAS Sync box or Timing Master 6 Pulse via binary input External...

Page 367: ...ROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 367 4 17 Dimensions 4 17 1 Housing for Panel Flush Mounting or Cubicle Installation Figure 4 6 Dimensions of a device for panel flush mounting or cubicle installation size 1 3 ...

Page 368: ...Technical Data 4 17 Dimensions SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 368 4 17 2 Panel Surface Mounting Figure 4 7 Dimensions of a device for panel surface mounting size 1 3 ...

Page 369: ...n diagrams default settings as well as tables with all parameters and information for the device with its maximum extent A 1 Ordering Information and Accessories 370 A 2 Terminal Assignments 377 A 3 Connection Examples 379 A 4 Default Settings 382 A 5 Protocol dependent Functions 385 A 6 Functional Scope 386 A 7 Settings 387 A 8 Information List 397 A 9 Group Alarms 424 A 10 Measured Values 425 ...

Page 370: ...r of Binary Inputs and Outputs BI Binary Inputs BO Output Relays Pos 9 Flush mounting housing with screwed terminals 1 3 x 19 7 BI 5 BO 1 life contact B Surface mounting housing with two tier terminals 1 3 x 19 7 BI 5 BO 1 life contact F Flush mounting housing with plug in terminals 1 3 x 19 with plug in terminals 7 BI 5 BO 1 life contact K Region specific Default Language Settings and Function Ve...

Page 371: ...pecification M 9 Additional Specification M for DIGSI modem interface and protection data interface 1 device rear port C and D Pos 23 Pos 24 Port C DIGSI Modem Browser electrical RS232 1 Port C DIGSI Modem Browser electrical RS485 2 Port D FO5 optical 820 nm 2 ST connectors length of optical fibre up to 1 5 km for FO direct connection or communication networks using multimode fibre A Port D FO6 op...

Page 372: ...l backup time delay overcurrent protection emergency overcurrent protection with breaker failure protection S Function 3 Pos 15 4 remote commands 24 remote signals Transformer inside protection zone Voltage frequency protection Restricted earth fault protection without without without without A without without With without B without With without without E without with with without F with without w...

Page 373: ...er 60 km 37 5 miles 1 7XV5461 0BH00 Wide area fibre optical repeater 100 km 62 miles 1 7XV5461 0BJ00 Wide area fibre optical repeater 170 km 105 5 miles 1 7XV5461 0BM00 Bidirectional fibre optical repeater 40 km 25 miles The communication is performed via fibre optic cables 2 7XV5461 0BK00 Bidirectional fibre optical repeater 40 km 25 miles The communication is performed via fibre optic cables 2 7...

Page 374: ...receiver with antenna and cable 7XV5664 0AA00 Power supply 7XV5810 0BA00 Time synchronization system 7XV5656 0BA00 Bus cable for GPS synch 7XV5105 0AA00 External Converters Optical interfaces for Profibus and DNP 3 0 are not possible with surface mounting housings Please order in this case a device with the appropriate electrical RS485 interface and the additional OLM converters listed below Note ...

Page 375: ...ector 820 nm multimode optical fibre maximum length 3 5 km for surface mounting housing C53207 A406 D50 1 FO17 with LC duplex connector 1300 nm monomode optical fibre maximum length 24 km 15 miles C53207 A351 D655 1 FO18 with LC duplex connector 1300 nm monomode optical fibre maximum length 60 km 37 5 miles C53207 A351 D656 1 FO19 with LC duplex connector 1550 nm monomode optical fibre maximum len...

Page 376: ... 19 Racks Name Order No a pair of mounting rails one for top one for bottom C73165 A63 D200 1 Battery Lithium battery 3 V 1 Ah type CR 1 2 AA Order No VARTA 6127 101 501 Interface Cable An interface cable and the DIGSI operating software are required for the communication between the SIPRO TEC 4 device and a PC or laptop The PC or laptop must run MS WINDOWS 95 MS WINDOWS 98 MS WINDOWS NT 4 MS WIND...

Page 377: ...SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 377 A 2 Terminal Assignments A 2 1 Housing for Panel Flush and Cubicle Mounting 7SD610 B K Figure A 1 General diagram for 7SD610 B K panel flush mounted or cubicle mounted ...

Page 378: ...x A 2 Terminal Assignments SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 378 A 2 2 Housing for panel surface mounting 7SD610 F Figure A 2 Connection diagram for 7SD610 F panel surface mounted ...

Page 379: ...rrent residual 3I0 neutral current normal circuit layout Figure A 4 Current connections to three current transformers with separate earth current transformer summation current transformer or toroidal current transformer Important The cable shield must be earthed on the cable side In case of an earthing of the current transformers on the busbar side the current polarity of the device is changed via...

Page 380: ...C 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 380 Figure A 5 Restricted earth fault protection on an earthed transformer winding Figure A 6 Restricted earth fault protection on a non earthed transformer winding with neutral reactor ...

Page 381: ...ease date 02 2011 381 A 3 2 Voltage Transformer Examples Figure A 7 Voltage connections to three wye connected voltage transformers normal circuit layout Figure A 8 Voltage connections to three wye connected voltage transformers with additional broken delta windings da dn winding ...

Page 382: ...tion Binary Input Allocated Func tion Function No Description BI1 Intertrip 3pol 3504 I Trip Intertrip 3 pole signal input BI2 Reset LED 5 Reset LED BI3 Diff block 3525 Differential protection blocking signal BI4 DTT Trip L123 4417 Direct Transfer Trip INPUT 3ph L123 BI5 BLOCK O C I 7104 BLOCK Backup OverCurrent I BLOCK O C I 7105 BLOCK Backup OverCurrent I BLOCK O C Ip 7106 BLOCK Backup OverCurre...

Page 383: ...es and ordered variants A 4 5 Default Display 4 line Display Table A 5 This selection is available as start page which may be configured Function Keys Allocated Function F1 Display of Operational Annunciations F2 Operating Measured Values Primary F3 An overview of the last eight network faults F4 Not pre assigned Page 1 Page 2 Page 3 Page 4 Page 5 ...

Page 384: ...5 6 Release date 02 2011 384 A 4 6 Pre defined CFC Charts Device and System Logic A negator block of the slow logic PLC1 BEARB is created from the binary input DataStop into the internal single point indication Unblock DT Figure A 9 Logical Link between Input and Output ...

Page 385: ... CFC Pre defined User defined mes sages in CFC Time synchronisation Via protocol DCF77 IRIG B GPS interface Protection data inter face binary input Via protocol NPT DCF77 IRIG B Interface Protection data interface Binary input Via DCF77 IRIG B GPS interface Protection data inter face binary input Via protocol DCF77 IRIG B GPS interface Protection data inter face binary input Messages with time sta...

Page 386: ...les 7 AR cycles 8 AR cycles ADT Disabled Disabled Auto Reclose Function 134 AR control mode Pickup w Tact Pickup w o Tact Trip w Tact Trip w o Tact Trip w o Tact Auto Reclose control mode 136 FREQUENCY Prot Disabled Enabled Disabled Over Underfrequency Protection 137 U O VOLTAGE Disabled Enabled Enabl w comp Disabled Under Overvoltage Protection 139 BREAKER FAILURE Disabled Enabled enabled w 3I0 D...

Page 387: ...sformer is 221 I4 Iph CT P System Data 1 0 010 5 000 1 000 Matching ratio I4 Iph for CT s 230 Rated Frequency P System Data 1 50 Hz 60 Hz 50 Hz Rated Frequency 236 Distance Unit P System Data 1 km Miles km Distance measurement unit 240A TMin TRIP CMD P System Data 1 0 02 30 00 sec 0 10 sec Minimum TRIP Command Dura tion 241A TMax CLOSE CMD P System Data 1 0 01 30 00 sec 1 00 sec Maximum Close Comm...

Page 388: ...s Line Length 1130A PoleOpenCurrent P System Data 2 1A 0 05 1 00 A 0 10 A Pole Open Current Threshold 5A 0 25 5 00 A 0 50 A 1131A PoleOpenVoltage P System Data 2 2 70 V 30 V Pole Open Voltage Threshold 1132A SI Time all Cl P System Data 2 0 01 30 00 sec 0 10 sec Seal in Time after ALL closures 1133A T DELAY SOTF P System Data 2 0 05 30 00 sec 0 25 sec minimal time for line open before SOTF 1134 Li...

Page 389: ...SpeedDIS YES NO NO High Speed Distance blocked if Diff A 2201 FCT Direct Trip DTT Direct Trip ON OFF OFF Direct Transfer Trip DTT 2202 Trip Time DELAY DTT Direct Trip 0 00 30 00 sec 0 01 sec Trip Time Delay 2301 INRUSH REST Diff Prot OFF ON OFF Inrush Restraint 2302 2nd HARMONIC Diff Prot 10 45 15 2nd harmonic in of fundamen tal 2303 CROSS BLOCK Diff Prot NO YES NO Cross Block 2305 MAX INRUSH PEAK...

Page 390: ...me Dial 2643 Time Dial TD Ip Back Up O C 0 50 15 00 5 00 Time Dial TD Ip 2646 T Ip Add Back Up O C 0 00 30 00 sec 0 00 sec T Ip Additional Time Delay 2650 3I0p PICKUP Back Up O C 1A 0 05 4 00 A A 3I0p Pickup 5A 0 25 20 00 A A 2652 T 3I0p TimeDial Back Up O C 0 05 3 00 sec 0 50 sec T 3I0p Time Dial 2653 TimeDial TD3I0p Back Up O C 0 50 15 00 5 00 Time Dial TD 3I0p 2656 T 3I0p Add Back Up O C 0 00 3...

Page 391: ... 10 100 V 50 V Voltage Threshold for Balance Monitoring 2903A BAL FACTOR U Measurem Superv 0 58 0 95 0 75 Balance Factor for Voltage Monitor 2904A BALANCE I LIMIT Measurem Superv 1A 0 10 1 00 A 0 50 A Current Balance Monitor 5A 0 50 5 00 A 2 50 A 2905A BAL FACTOR I Measurem Superv 0 10 0 95 0 50 Balance Factor for Current Monitor 2906A ΣI THRESHOLD Measurem Superv 1A 0 10 2 00 A 0 25 A Summated Cu...

Page 392: ...r remote close command 3411A T DEAD EXT Auto Reclose 0 50 300 00 sec sec Maximum dead time extension 3420 AR WITH DIFF Auto Reclose YES NO YES AR with differential protection 3421 AR w SOTF O C Auto Reclose YES NO YES AR with switch onto fault over current 3423 AR WITH I TRIP Auto Reclose YES NO YES AR with intertrip 3424 AR w DTT Auto Reclose YES NO YES AR with direct transfer trip 3425 AR w Back...

Page 393: ...1800 00 sec 0 50 sec Dead time after 3phase faults 3478 3 AR Tdead1Trip Auto Reclose 0 01 1800 00 sec sec Dead time after 1pole trip 3479 3 AR Tdead3Trip Auto Reclose 0 01 1800 00 sec 0 50 sec Dead time after 3pole trip 3480 3 AR Tdead EV Auto Reclose 0 01 1800 00 sec 1 20 sec Dead time after evolving fault 3481 3 AR CB CLOSE Auto Reclose YES NO NO CB ready interrogation before re closing 3482 3 A...

Page 394: ...oltage Prot 2 0 220 0 V 175 0 V Uph ph Pickup 3715 T Uph ph Voltage Prot 0 00 100 00 sec 1 00 sec T Uph ph Time Delay 3719A Uphph RESET Voltage Prot 0 30 0 99 0 98 Uph ph Reset ratio 3721 3U0 or Ux Voltage Prot OFF Alarm Only ON U Alarm U Trip OFF Operating mode 3U0 or Ux ov ervoltage 3722 3U0 Voltage Prot 1 0 220 0 V 30 0 V 3U0 Pickup or Ux 3723 T 3U0 Voltage Prot 0 00 100 00 sec 2 00 sec T 3U0 T...

Page 395: ...y 3774 U1 Voltage Prot 1 0 100 0 V 0 10 0 V U1 Pickup 3775 T U1 Voltage Prot 0 00 100 00 sec 1 00 sec T U1 Time Delay 3778 CURR SUP U1 Voltage Prot ON OFF ON Current supervision U1 3779A U1 RESET Voltage Prot 1 01 1 20 1 05 U1 Reset ratio 3901 FCT BreakerFail Breaker Failure ON OFF ON Breaker Failure Protection 3902 I BF Breaker Failure 1A 0 05 20 00 A 0 10 A Pick up threshold I 5A 0 25 100 00 A 0...

Page 396: ... protection interface 1 4502 CONNEC 1 OVER Prot Interface F optic direct Com conv 64 kB Com conv 128 kB Com conv 512 kB C37 94 1 slot C37 94 2 slots C37 94 4 slots C37 94 8 slots F optic direct Connection 1 over 4505A PROT 1 T DELAY Prot Interface 0 1 30 0 ms 30 0 ms Prot 1 Maximal permissible delay time 4506A PROT 1 UNSYM Prot Interface 0 000 3 000 ms 0 100 ms Prot 1 Diff in send and receive time...

Page 397: ...scill Record the following applies UPPER CASE NOTATION M definitely set not allocatable lower case notation m preset allocatable not preset allocatable blank neither preset nor 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 ...

Page 398: ...Yes Earth Switch EarthSwit Control Device CF_D 2 on off BO 240 164 20 Earth Switch EarthSwit Control Device DP on off BI CB 240 164 1 Yes Interlocking Breaker Open Brk Open Control Device IntSP Interlocking Breaker Close Brk Close Control Device IntSP Interlocking Disconnect switch Open Disc Open Control Device IntSP Interlocking Disconnect switch Close Disc Close Control Device IntSP Interlocking...

Page 399: ...BI BO 8 Setting Group Select Bit 1 Set Group Bit1 Change Group SP LED BI BO 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 11 User defined annunciation 1 Annunc 1 Device SP LED BI BO 192 27 1 Yes 12 U...

Page 400: ...Sum Alarm Device OUT on off LED BO 192 47 1 Yes 144 Error 5V Error 5V Device OUT on off LED BO 135 164 1 Yes 160 Alarm Summary Event Alarm Sum Event Device OUT LED BO 192 46 1 Yes 161 Failure General Current Supervi sion Fail I Superv Measurem Superv OUT LED BO 192 32 1 Yes 163 Failure Current Balance Fail I balance Measurem Superv OUT on off LED BO 135 183 1 Yes 164 Failure General Voltage Superv...

Page 401: ...f LED BO 135 197 1 Yes 234 2100 U U blocked via operation U U blk Voltage Prot IntSP on off LED BO 285 Power factor alarm cosϕ alarm Set Points MV OUT on off LED BO 289 Alarm Current summation super vision Failure Σi Measurem Superv OUT on off LED BO 135 250 1 Yes 290 Alarm Broken current wire de tected L1 Broken Iwire L1 Measurem Superv OUT on off LED BO 135 137 1 Yes 291 Alarm Broken current wir...

Page 402: ...378 CB faulty CB faulty P System Data 2 SP LED BI BO 379 CB aux contact 3pole Closed CB 3p Closed P System Data 2 SP LED BI BO 150 78 1 Yes 380 CB aux contact 3pole Open CB 3p Open P System Data 2 SP LED BI BO 150 79 1 Yes 381 Single phase trip permitted from ext AR 1p Trip Perm P System Data 2 SP on off LED BI BO 382 External AR programmed for 1phase only Only 1ph AR P System Data 2 SP on off LED...

Page 403: ...y Definitive TRIP Definitive TRIP P System Data 2 OUT on on LED BO 150 180 2 Yes 545 Time from Pickup to drop out PU Time P System Data 2 VI 546 Time from Pickup to TRIP TRIP Time P System Data 2 VI 560 Single phase trip was coupled 3phase Trip Coupled 3p P System Data 2 OUT on LED BO 150 210 2 No 561 Manual close signal detected Man Clos Detect P System Data 2 OUT on LED BO 150 211 1 No 562 CB CL...

Page 404: ... L1 Breaker Failure SP on off LED BI BO 1436 BF External start L2 BF Start L2 Breaker Failure SP on off LED BI BO 1437 BF External start L3 BF Start L3 Breaker Failure SP on off LED BI BO 1439 BF External start 3pole w o current BF Start w o I Breaker Failure SP on off LED BI BO 1440 Breaker failure prot ON OFF via BI BkrFailON offBI Breaker Failure IntSP on off LED BO 1451 Breaker failure is swit...

Page 405: ... 1 Yes 1517 Th Overload Pickup before trip Th O L Pickup Therm Overload OUT on off LED BO 167 17 1 Yes 1521 Th Overload TRIP command Th O L TRIP Therm Overload OUT on LED BO 167 21 2 Yes 2054 Emergency mode Emer mode Device OUT on off on off LED BO 192 37 1 Yes 2701 AR Switch on auto reclose function AR on Auto Reclose SP LED BI BO 40 1 1 Yes 2702 AR Switch off auto reclose function AR off Auto Re...

Page 406: ... 40 45 2 Yes 2751 AR External pickup 2phase for AR start Pickup 2ph AR Auto Reclose SP on LED BI BO 40 46 2 Yes 2752 AR External pickup 3phase for AR start Pickup 3ph AR Auto Reclose SP on LED BI BO 40 47 2 Yes 2781 AR Auto reclose is switched off AR off Auto Reclose OUT on off LED BO 40 81 1 Yes 2782 AR Auto reclose is switched on AR on Auto Reclose IntSP LED BO 192 16 1 Yes 2783 AR Auto reclose ...

Page 407: ...yc3p Auto Reclose OUT LED BO 40 153 1 Yes 2854 AR Close command 2nd cycle and higher AR Close 2 Cyc Auto Reclose OUT LED BO 192 129 1 No 2861 AR Reclaim time is running AR T Recl run Auto Reclose OUT LED BO 40 161 1 Yes 2862 AR successful AR successful Auto Reclose OUT LED BO 40 162 1 Yes 2864 AR 1pole trip permitted by inter nal AR AR 1p Trip Perm Auto Reclose OUT LED BO 40 164 1 Yes 2865 AR Sync...

Page 408: ...Prot OUT on off m LED BO 92 99 2 Yes 3142 Diff TRIP Only L1 Diff TRIP 1p L1 Diff Prot OUT on off m LED BO 92 100 2 Yes 3143 Diff TRIP Only L2 Diff TRIP 1p L2 Diff Prot OUT on off m LED BO 92 101 2 Yes 3144 Diff TRIP Only L3 Diff TRIP 1p L3 Diff Prot OUT on off m LED BO 92 102 2 Yes 3145 Diff TRIP L123 Diff TRIP L123 Diff Prot OUT on off m LED BO 92 103 2 Yes 3146 Diff TRIP 1pole Diff TRIP 1pole Di...

Page 409: ... Diff Prot IntSP on off LED BO 3215 Incompatible Firmware Versions Wrong Firmware Prot Interface OUT on LED BO 3217 Prot Int 1 Own Datas received PI1 Data reflec Prot Interface OUT on off LED BO 3227 Prot Int 1 Transmitter is switched off PI1 light off Prot Interface SP on off LED BI BO 3229 Prot Int 1 Reception of faulty data PI1 Data fault Prot Interface OUT on off LED BO 93 135 1 Yes 3230 Prot ...

Page 410: ... 94 not supported by module PI1 C37 94 n a Prot Interface OUT on off LED BO 3452 Logout state ON Logout ON Diff Topo SP on off LED BI BO 3453 Logout state OFF Logout OFF Diff Topo SP on off LED BI BO 3458 System operates in a open Chaintopology Chaintopology Diff Topo OUT on off LED BO 93 142 1 Yes 3459 Logout state ON OFF Logout ON off Diff Topo IntSP on off LED BO 3460 Logout state ON OFF via BI...

Page 411: ...es 3522 I Trip TRIP 1pole ITrp TRIP 1pole Intertrip OUT on off LED BO 3523 I Trip TRIP 3pole ITrp TRIP 3pole Intertrip OUT on off LED BO 3525 Differential protection blocking signal Diff block Diff Prot SP on off LED BI BO 3526 Differential blocking received at PI1 Diffblk rec PI1 Diff Prot OUT on off LED BO 3528 Differential blocking sending via PI1 Diffblk sen PI1 Diff Prot OUT on off LED BO 354...

Page 412: ...l16 Remote Signals SP on off LED BI BO 3565 Remote Signal 17 input Rem Signal17 Remote Signals SP on off LED BI BO 3566 Remote Signal 18 input Rem Signal18 Remote Signals SP on off LED BI BO 3567 Remote Signal 19 input Rem Signal19 Remote Signals SP on off LED BI BO 3568 Remote Signal 20 input Rem Signal20 Remote Signals SP on off LED BI BO 3569 Remote Signal 21 input Rem Signal21 Remote Signals S...

Page 413: ...ignal 19 received Rem Sig19recv Remote Signals OUT on off LED BO 93 176 1 Yes 3592 Remote signal 20 received Rem Sig20recv Remote Signals OUT on off LED BO 93 177 1 Yes 3593 Remote signal 21 received Rem Sig21recv Remote Signals OUT on off LED BO 93 178 1 Yes 3594 Remote signal 22 received Rem Sig22recv Remote Signals OUT on off LED BO 93 179 1 Yes 3595 Remote signal 23 received Rem Sig23recv Remo...

Page 414: ... off LED BI BO 4417 Direct Transfer Trip INPUT 3ph L123 DTT Trip L123 DTT Direct Trip SP on off LED BI BO 4421 Direct Transfer Trip is switched OFF DTT OFF DTT Direct Trip OUT on off LED BO 51 21 1 Yes 4422 Direct Transfer Trip is BLOCKED DTT BLOCK DTT Direct Trip OUT on off on off LED BO 51 22 1 Yes 4432 DTT TRIP command Only L1 DTT TRIP 1p L1 DTT Direct Trip OUT on LED BO 51 32 2 No 4433 DTT TRI...

Page 415: ...ncy protection TimeOut Stage f3 Time Out f3 Frequency Prot OUT LED BO 5243 Frequency protection TimeOut Stage f4 Time Out f4 Frequency Prot OUT LED BO 5803 BLOCK restricted earth fault prot BLOCK REF REF SP LED BI BO 5811 Restricted earth fault is switched OFF REF OFF REF OUT on off LED BO 76 11 1 Yes 5812 Restricted earth fault is BLOCKED REF BLOCKED REF OUT on off on off LED BO 76 12 1 Yes 5813 ...

Page 416: ...SP on off on off LED BI BO 64 10 1 Yes 7111 BLOCK direct Backup Over Current I BLOCK Dir I Back Up O C SP on off LED BI BO 64 11 1 Yes 7112 BLOCK direct Backup Over Current Ip BLOCK Dir Ip Back Up O C SP on off LED BI BO 64 12 1 Yes 7113 BLOCK direct Backup Over Current Ie BLOCK Dir Ie Back Up O C SP on off LED BI BO 64 13 1 Yes 7114 BLOCK direct Backup Over Current Iep BLOCK Dir Iep Back Up O C S...

Page 417: ...p O C Pickup L123 O C Pickup L123 Back Up O C OUT on LED BO 64 84 2 No 7185 Backup O C Pickup L123E O C PickupL123E Back Up O C OUT on LED BO 64 85 2 No 7191 Backup O C Pickup I O C PICKUP I Back Up O C OUT on m LED BO 64 91 2 Yes 7192 Backup O C Pickup I O C PICKUP I Back Up O C OUT on m LED BO 64 92 2 Yes 7193 Backup O C Pickup Ip O C PICKUP Ip Back Up O C OUT on m LED BO 64 93 2 Yes 7201 O C I ...

Page 418: ... 7248 Backup O C forward direction O C Dir forward Back Up O C OUT LED BO 7249 Backup O C reverse direction O C Dir reverse Back Up O C OUT LED BO 7325 CB1 TEST TRIP command Only L1 CB1 TESTtrip L1 Testing OUT on off LED BO 153 25 1 Yes 7326 CB1 TEST TRIP command Only L2 CB1 TESTtrip L2 Testing OUT on off LED BO 153 26 1 Yes 7327 CB1 TEST TRIP command Only L3 CB1 TESTtrip L3 Testing OUT on off LED...

Page 419: ...73 21 1 Yes 10222 U1 Overvolt is BLOCKED U1 BLK Voltage Prot OUT on off on off LED BO 73 22 1 Yes 10223 U2 Overvolt is switched OFF U2 OFF Voltage Prot OUT on off LED BO 73 23 1 Yes 10224 U2 Overvolt is BLOCKED U2 BLK Voltage Prot OUT on off on off LED BO 73 24 1 Yes 10225 Uph e Undervolt is switched OFF Uph e OFF Voltage Prot OUT on off LED BO 73 25 1 Yes 10226 Uph e Undervolt is BLOCKED Uph e BL...

Page 420: ...ph PU L23 Voltage Prot OUT on off LED BO 73 58 2 Yes 10259 Uph ph Pickup L3 L1 Uph ph PU L31 Voltage Prot OUT on off LED BO 73 59 2 Yes 10260 Uph ph TimeOut Uphph Time Out Voltage Prot OUT LED BO 10261 Uph ph TimeOut Uphph TimeOut Voltage Prot OUT LED BO 10262 Uph ph TRIP command Up hph TRIP Voltage Prot OUT on LED BO 73 62 2 Yes 10263 Uph ph Pickup L1 L2 Uphph PU L12 Voltage Prot OUT LED BO 73 13...

Page 421: ...rot OUT on off LED BO 73 111 2 Yes 10312 Uph e Pickup L1 Uph e PU L1 Voltage Prot OUT on off LED BO 73 112 2 Yes 10313 Uph e Pickup L2 Uph e PU L2 Voltage Prot OUT on off LED BO 73 113 2 Yes 10314 Uph e Pickup L3 Uph e PU L3 Voltage Prot OUT on off LED BO 73 114 2 Yes 10315 Uph e TimeOut Uph e Time Out Voltage Prot OUT LED BO 10316 Uph e TimeOut Uph e Tim eOut Voltage Prot OUT LED BO 10317 Uph e T...

Page 422: ...h Speed Distance Active HSD Active HighSpeedDIS OUT on off LED BO 10820 High Speed Distance General PickUp HSD G PU HighSpeedDIS OUT on off LED BO 10821 High Speed Distance Pick Up L1E HSD PU L1E HighSpeedDIS OUT on off LED BO 10822 High Speed Distance Pick Up L2E HSD PU L2E HighSpeedDIS OUT on off LED BO 10823 High Speed Distance Pick Up L3E HSD PU L3E HighSpeedDIS OUT on off LED BO 10824 High Sp...

Page 423: ... Device VI 31002 Q2 operationcounter Q2 OpCnt Control Device VI 31008 Q8 operationcounter Q8 OpCnt Control Device VI 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 S...

Page 424: ...65 167 168 169 170 171 177 190 191 193 183 184 185 186 187 188 189 Failure Σi Fail I balance Fail Σ U Ph E Fail U balance Fail U absent VT FuseFail 10s VT FuseFail Fail Ph Seq Fail Battery Error Board 0 Error Offset Alarm adjustm Error Board 1 Error Board 2 Error Board 3 Error Board 4 Error Board 5 Error Board 6 Error Board 7 161 Fail I Superv 289 163 Failure Σi Fail I balance 164 Fail U Superv 16...

Page 425: ... CD DD 635 U2 negative sequence U2 Measurement CFC CD DD 641 P active power P Measurement 134 129 No 9 7 CFC CD DD 642 Q reactive power Q Measurement 134 129 No 9 8 CFC CD DD 643 Power Factor PF Measurement 134 129 No 9 13 CFC CD DD 644 Frequency Freq Measurement 134 129 No 9 9 CFC CD DD 645 S apparent power S Measurement CFC CD DD 679 U1co positive sequence compounding U1co Measurement CFC CD DD ...

Page 426: ...Measure relay1 CFC CD DD 7765 Angle IL2_rem IL2_loc ΦI L2 Measure relay1 CFC CD DD 7766 IL3 of Operational nominal current IL3_opN Measure relay1 CFC CD DD 7767 Angle IL3_rem IL3_loc ΦI L3 Measure relay1 CFC CD DD 7769 UL1 of Operational nominal voltage UL1_opN Measure relay1 CFC CD DD 7770 Angle UL1_rem UL1_loc ΦU L1 Measure relay1 CFC CD DD 7771 UL2 of Operational nominal voltage UL2_opN Measure...

Page 427: ...ssion delay rec PI1 TD R Statistics 134 121 No 9 1 CFC CD DD 7876 Prot Interface 1 Transmission delay send PI1 TD S Statistics 134 121 No 9 2 CFC CD DD 30654 Idiff REF Operational nominal current Id iffREF IDiff IRest CFC CD DD 30655 Irest REF Operational nominal current Ir estREF IDiff IRest CFC CD DD No Description Function IEC 60870 5 103 Configurable in Matrix Type Information Number Compatibi...

Page 428: ...Appendix A 10 Measured Values SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 428 ...

Page 429: ...0417 H1176 C098 A9 4 SIPROTEC SIGRA 4 Manual E50417 H1100 C070 A4 5 Digital Distance Protection Basics and Applications Edition 2 completely revised and extended version May 14 2008 Language German ISBN 10 389578320X ISBN 13 987 3895783203 6 Application Examples for SIPROTEC Protection Devices E50001 K4451 A101 A1 7 Case Studies for SIPROTEC Protection Devices and Power Quality E50001 K4452 A101 A...

Page 430: ...Literature SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 430 ...

Page 431: ...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 graphical 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 pu...

Page 432: ...le of such a con tainer Control display The display which is displayed on devices with a large graphic display after you have pressed the control key is called the 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 display is part of the configuration Data pane The right hand area of the proje...

Page 433: ... one data area to another Earth The conductive earth whose electric potential can be set equal to zero at every point In the area of earth elec trodes the earth can have a potential deviating from zero The term Earth reference plane is often used for this state Earth verb This term means that a conductive part is connected via an earthing system to the earth Earthing Earthing is the total of all m...

Page 434: ...int indication ExSI_F External single point indication via an ETHERNET connection device specific Transient information Single point indication Field devices Generic term for all devices assigned to the field level Protection devices combination devices bay control lers Floating Without electrical connection to the Earth FMS communication branch Within an FMS communication branch the users communi...

Page 435: ...ds which exist in a ModPara project The actual field infor mation of each field is stored in a HV field description file Within the HV project description file each field is allocated such a HV field description file by a reference to the file name HV project description All the data is exported once the configuration and parameterization of PCUs and sub modules using ModPara has been completed Th...

Page 436: ... an inter relay communication Each user of the combination and all the necessary communication parameters are defined in this object The type and scope of the information exchanged between 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 transient Transient i...

Page 437: ... designa tion This is the equivalent of an order number The type and version of a SIPROTEC 4 device are coded in the order number Modem connection This object type contains information on both 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 initialization commands and ...

Page 438: ... information On line When working in online mode there is a physical connection to a SIPROTEC 4 device This connection can be implemented as a direct connection as a modem connection or as a PROFIBUS FMS connection OUT Output indication Parameter set The parameter set is the set of all parameters that can be set for a SIPROTEC 4 device Phone book User addresses for a modem connection are saved in ...

Page 439: ...er a cleanup also reassigns the VD addresses The consequence is that all SIPROTEC 4 devices have to be reinitialized RIO file Relay data Interchange format by Omicron RSxxx interface Serial interfaces RS232 RS422 485 SCADA Interface Rear serial interface on the devices for connecting to a control system via IEC or PROFIBUS Service port Rear serial interface on the devices for connecting DIGSI for ...

Page 440: ...on system base V4 SIPROTEC 4 device This object type represents a real SIPROTEC 4 device with all the setting values and process data it contains SIPROTEC 4 variant This object type represents a variant of an object of type SIPROTEC 4 device The device data of this variant may well differ from the device data of the original object However all variants derived from the original object have the sam...

Page 441: ...an communicate with one another in an Inter Relay Communication combination The individual participating devices are called users VD A VD Virtual Device includes all 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 b...

Page 442: ...Glossary SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 442 ...

Page 443: ...rvice interface 289 Switching the configured resources 318 Time Synchronisation Interface 291 Check System Connections 293 Check System interface 290 Checking a Connection 303 Checking Instrument transformer connection two line ends 311 Operator interface 289 Phase rotation 310 Voltage connection 310 Circuit Breaker Position Detection 226 Test Programs 236 Tripping Test 318 Circuit breaker Externa...

Page 444: ... 67 High speed charge comparison 69 Inrush restraint 67 75 339 Interblocking 70 Measured quantity evaluation 68 Pickup 71 Pickup value charge comparison stage 74 Pickup values 74 Protection data interfaces 334 Restraint 66 Self restraint 339 Tolerances 67 Topology 334 Tripping logic 72 Direct connection 50 Direct Voltage 323 Display of measured values 251 E Earth fault Earth fault 86 Restraint 85 ...

Page 445: ...6 Interfaces 63 Interlocking 262 Interrupted currents 249 Intertrip 80 341 Inverse Time Stage Overcurrent Protection IEC Characteristic 346 Inverse Time Stage Time Overcurrent Protection ANSI Characteristic 347 K k factor 196 L Limits for CFC blocks 361 Limits for user defined functions 361 Line energization recognition 222 Live Contact 274 M Measured Value Acquisition Currents 200 Voltages 201 Me...

Page 446: ...losure Blocking 128 Reduced Dead Time 351 Reduced dead time 143 Reference Voltages 199 Remote commands 92 342 Remote indications 92 Remote measured values 255 Remote Tripping 341 Remote tripping 80 Replacing Interfaces 275 Requirements for current transformers 322 Reset of Stored LED Relays 238 Restraint current values 254 Restricted Earth Fault Protection 25 Operating Time 340 Setting ranges 340 ...

Page 447: ...h ANSI charac teristics Time Overcurrent Stage 118 IPDir inverse time O C protection with IEC character istics Time Overcurrent Stage 117 Iph Definite time O C Protection 116 Iph Dir Definite time O C Protection 116 Time Synchronisation Interface 291 Time synchronization 63 Time synchronization interface 329 Topology exploration 92 Transformer Satturation range 83 Transformers Current matching 339...

Page 448: ...Index SIPROTEC 7SD610 Manual C53000 G1176 C145 6 Release date 02 2011 448 ...

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