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Functions

2.2 Phase Comparison Protection and Ground Differential Protection

SIPROTEC, 7SD80, Manual

E50417-G1140-C474-A1, Release date 09.2011

58

Pickup Values for Resistive or Solid Grounded, Resonant-grounded and Isolated Systems

At address

1202

87L Idyn>

you can set the dynamic tripping threshold. The value for

87L Idyn>

should be

set to at least 0.2 of the largest primary transformer rated current and larger than 2.5 to 3 times the capacitive
charging current of the line. If inductances can be connected in the protected zone (common-mode reactor or
transformers) for energized lines,

87L Idyn>

should be greater than the maximum expected inrush current.

The dynamic tripping threshold for closing is set in address

1203

87L Idyn close>

. The value for

87L Idyn

close>

should be

≥

87L Idyn>

, but it should equal at least 3 times the value of the capacitive charging

current of the protected line. If inductances are present in the protected zone (common-mode reactor or trans-
formers),

87L Idyn close>

should be set greater than the maximum expected inrush current.

The static tripping threshold is set in address

1204

87L Isteady>

. The static tripping threshold should be set

to a value that is larger than the transformer rated current plus at least 3 times the capacitive charging current
of the line. If inductances are present in the protected zone (common-mode reactor or transformers),

87L

Isteady>

must be set greater than the maximum expected inrush current.

At address

1205

87L I min

you can enter the threshold for releasing the pickup signal. The value should at

least correspond to the setting of

87L Idyn>

, but not exceed the largest transformer rated current of the con-

stellation.

Note

When using different transformers in the constellation, set identical primary setting values. The secondary
setting values can be different.

Time Delays

The trip time delay for

87L Isteady>

is set in address

1206

87L Trip Delay

.

With the inrush current detection activated, the time delay

87L Trip Delay

must be at least 20 ms for the

blocking by the inrush current detection to be effective. In resonant-grounded or isolated systems, transients
must have subsided before tripping takes place. The delay should be at least 3 cycles (60 ms at 50 Hz and
54 Ms at 60 Hz). For large systems, the time delay must be increased accordingly (see Figure 2-16).

At address

1208

87L: T EFdetect

you set the time after which an evolving fault is detected. The parameter

is disabled in resonant-grounded or isolated power systems. In the specified time, the 1-phase trip command
of the dynamic element

87L: T EFdetect

is not forwarded to the tripping logic.

Address

1207

87L Man. Close

allows you to set the behavior of the phase comparison protection for manual

closing for

87L Isteady>

. In this case, tripping can be

DELAYED

or

UNDELAYED

(see Figure 2-16).

At parameter

1214

87L:Inrush blk.

you can enable or disable the blocking function for the phase compar-

ison in case of inrush. If the parameter is enabled, tripping of the element

87L Idyn>

is generally delayed by

one cycle. Inrush blocking can thus become effective.

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Summary of Contents for SIPROTEC 7SD80

Page 1: ...IPROTEC Line Differential Protection 7SD80 V4 6 Manual E50417 G1140 C474 A1 Preface Contents Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Appendix A Literature Glossary Index ...

Page 2: ... editions We appreciate any suggested improvements We reserve the right to make technical improvements without notice Document version V04 00 03 Release date 09 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: ...e protective equipment automatic and control facilities and personnel of electrical facilities and power plants Applicability of this Manual This manual applies to SIPROTEC 4 Line Differential Protection 7SD80 firmware version V4 6 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 relat...

Page 4: ...00 Fax 49 180 524 2471 e mail support energy siemens com Training Courses Inquiries regarding individual training courses should be addressed to our Training Center Siemens AG Siemens Power Academy Humboldt Street 59 90459 Nuremberg Telefon 49 911 433 7415 Fax 49 911 433 7929 Internet www siemens com energy power academy e mail power academy energy siemens com Additional Standards IEEE C37 90 see ...

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

Page 7: ...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 This also applies to header bars for selection 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...

Page 8: ...ts are active or inactive at the same time Dynamic input signals edge triggered above with positive below with negative edge Formation of one analog output signal from a number of analog input signals Threshold element with setting address and parameter names Timer pickup delay T adjustable with setting address and parameter names Timer dropout delay T not adjustable Edge triggered time element wi...

Page 9: ...ata Power System Data 1 37 2 1 3 1 Setting Notes 37 2 1 3 2 Settings 40 2 1 4 Oscillographic Fault Records 41 2 1 4 1 Description 41 2 1 4 2 Setting Notes 41 2 1 4 3 Settings 42 2 1 4 4 Information List 42 2 1 5 Change Group 43 2 1 5 1 Description 43 2 1 5 2 Setting Notes 43 2 1 5 3 Settings 43 2 1 5 4 Information List 44 2 1 6 General Protection Data Power System Data 2 44 2 1 6 1 Setting Notes 4...

Page 10: ... 2 2 5 1 Description 67 2 2 6 87 Differential Protection 68 2 2 6 1 Settings 69 2 2 6 2 Information List 70 2 2 7 Differential Protection Test and Commissioning 71 2 2 7 1 Differential Protection Test 71 2 2 7 2 Differential Protection Commissioning 73 2 3 Breaker Intertrip and Remote Tripping 75 2 3 1 Description 75 2 3 2 Setting Notes 76 2 3 3 Settings 77 2 3 4 Information List 77 2 4 Backup Ove...

Page 11: ...1 Optional 133 2 9 1 Description 133 2 9 2 Setting Notes 136 2 9 3 Settings 137 2 9 4 Information List 138 2 10 Direct Local Trip 139 2 10 1 Description 139 2 10 2 Setting Notes 140 2 10 3 Settings 140 2 10 4 Information List 140 2 11 Automatic Reclosure Function 79 Optional 141 2 11 1 Description 141 2 11 2 Setting Notes 148 2 11 3 Settings 152 2 11 4 Information List 154 2 12 Circuit Breaker Tes...

Page 12: ...4 1 5 Setting Notes 176 2 14 1 6 Settings 177 2 14 1 7 Information List 178 2 14 2 74TC Trip Circuit Supervision 179 2 14 2 1 Method of Operation 179 2 14 2 2 Setting Notes 182 2 14 2 3 Settings 182 2 14 2 4 Information List 182 2 15 Flexible Protection Functions 183 2 15 1 Description 183 2 15 2 Setting Notes 187 2 15 3 Settings 191 2 15 4 Information List 193 2 16 Function Control 194 2 16 1 Pic...

Page 13: ... Max Measurement Setup 207 2 17 6 1 Description 207 2 17 6 2 Setting Notes 207 2 17 6 3 Settings 208 2 17 6 4 Information List 208 2 17 7 Demand Measurement Setup 210 2 17 7 1 Description 210 2 17 7 2 Setting Notes 210 2 17 7 3 Settings 210 2 17 7 4 Information List 211 2 17 8 Set Points Measured Values 212 2 17 8 1 Setting Notes 212 2 17 8 2 Information List 212 2 17 9 Energy 213 2 17 9 1 Energy ...

Page 14: ...Port B 260 3 3 4 Configuring Communication Modules 262 3 3 5 Checking the Status of Binary Inputs and Outputs 265 3 3 6 Checking the Protection Data Communication 268 3 3 7 Tests for Circuit Breaker Failure Protection 270 3 3 8 Checking the Instrument Transformer Connections of One Line End 272 3 3 9 Checking the Instrument Transformer Connections of Two Line Ends 277 3 3 10 Checking the Pilot Pro...

Page 15: ...Optional 317 4 14 Transmission of Binary Information and Commands 318 4 15 Monitoring Functions 319 4 16 Flexible Protection Functions 321 4 17 User defined Functions CFC 324 4 18 Additional Functions 328 4 19 Dimensions 330 4 19 1 Panel Flush Mounting and Cabinet Flush Mounting Housing Size 1 6 330 4 19 2 Panel Surface Mounting Housing Size 1 6 331 4 19 3 Bottom View 332 A Appendix 333 A 1 Orderi...

Page 16: ...A 5 2 Binary Input 351 A 5 3 Binary Output 352 A 5 4 Function Keys 352 A 5 5 Default Display 353 A 5 6 Pre defined CFC Charts 356 A 6 Protocol dependent Functions 357 A 7 Functional Scope 358 A 8 Settings 360 A 9 Information List 371 A 10 Group Alarms 393 A 11 Measured Values 394 Literature 399 Glossary 401 Index 413 ...

Page 17: ...474 A1 Release date 09 2011 17 Introduction 1 This chapter introduces the SIPROTEC 4 7SD80 and gives an overview of the device s application properties and functions 1 1 Overall Operation 18 1 2 Application Scope 21 1 3 Characteristics 23 ...

Page 18: ... 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 provides 4 current transformers and depending on the model additionally 3 voltage transformers Three current inputs serve for the input of the phase currents another current input IN may be used for measuring the ground fault current IN cur...

Page 19: ...ns They especially consist of Filtering and preparation of the measured quantities Continuous monitoring of the measured quantities Monitoring of the pickup conditions for the individual protection functions Interrogation of limit values and time sequences Control of signals for the logic functions Decision on trip and close commands Recording of messages fault data and fault values for analysis A...

Page 20: ...icate with another 7SD80 device via an optical fiber cable If you are using a copper link to create a connection to the other 7SD80 device use the voltage terminals D1 and D2 as protection interface The protection data interfaces are used to transfer the data of the measured quantities from each end of the protected zone to the opposite end Further information such as closing of the local circuit ...

Page 21: ... evaluated separately for each phase The protection is restraint against inrush currents of power transformers When switching a line onto a fault it is possible to send an instantaneous trip signal The 7SD80 line differential protection includes the differential protection functions of phase comparison protection and ground fault differential protection Both differential protection functions opera...

Page 22: ...sed via output contacts allocatable linked with user definable logic functions and or issued via serial in terfaces During a fault system fault important events and changes in conditions are saved in fault protocols Event Log or Trip Log Instantaneous fault values are also saved in the device and may be analyzed subsequently Communication The following interfaces are available for communication wi...

Page 23: ...on of the protection data transmission for disturbance failure or transfer time variations Phase Comparison Protection Differential protection for two ends with digital protection data transmission Protection for all types of short circuits in systems with any starpoint conditioning Reliable distinction between load and short circuit conditions using adaptive measurement methods also for high resi...

Page 24: ... possible Blocking options e g for reverse interlocking with any element Instantaneous tripping when closing onto a short circuit possible with any element Inrush Current Restraint Insensitive to inrush currents even in the case of feeder transformers in the protected zone and against higher frequency transients High stability also for different current transformer saturation Circuit Breaker Failu...

Page 25: ... Hz to 70 Hz Automatic Reclose Function Optional For reclosing after 3 pole open condition Two reclosing attempts With separate action times for each reclosing attempt optionally without action times With separate dead times Optionally controlled by protection element pickup with separate dead times after 1 pole 2 pole or 3 pole pickup Monitoring Functions Reliability of the device is greatly incr...

Page 26: ...peration Maintenance Indication of the local and remote measured values according to magnitude and phase angle Indication of the calculated differential and restraint currents Indication of the measured values of the communication connection as runtime and availability Additional Functions Battery buffered clock which can be synchronized via a synchronization signal DCF77 IRIGB via satellite recei...

Page 27: ...ison Protection and Ground Differential Protection 52 2 3 Breaker Intertrip and Remote Tripping 75 2 4 Backup Overcurrent 78 2 5 Inrush Restraint 98 2 6 Circuit Breaker Failure Protection 50BF 101 2 7 Thermal Overload Protection 49 112 2 8 Undervoltage and Overvoltage Protection 27 59 Optional 116 2 9 Frequency Protection 81 Optional 133 2 10 Direct Local Trip 139 2 11 Automatic Reclosure Function...

Page 28: ... the configuration procedure or the interaction of functions be modified 2 1 1 1 Description Setting the Scope of Functions Example for the configuration of the scope of functions A system consists of overhead lines and underground cables Since automatic reclosing is only needed for the overhead lines the automatic reclosing function is disabled for the relays protecting the underground cables The...

Page 29: ...ction can be configured that either operates according to an IEC characteristic 50 N 51 N IEC or to an ANSI char acteristic 50 N 51 N ANSI This selection is independent of whether the time overcurrent protection is in tended to operate as emergency protection only in case of protection communication failure or as indepen dent backup protection Device versions equipped with directional overcurrent ...

Page 30: ...ime graded protection this setting is recommended If the protec tion function which is to operate with automatic reclosure does not have a general pickup signal for starting the action times select w o Tact without action time Address 137 27 59 allows activating the voltage protection function with a variety of undervoltage and over voltage protection elements For the trip circuit supervision ente...

Page 31: ...I 50 N 51 N IEC Backup overcurrent 133 79 Auto Recl Disabled 1 AR cycle 2 AR cycles Disabled 79 Auto Reclose Function 134 AR control mode PU w ActionTime PU w o ActionT Trip w ActionT Trip w oActionT Trip w ActionT Auto Reclose control mode 136 81 O U Disabled Enabled Disabled 81 Over Underfrequency Protec tion 137 27 59 Disabled Enabled Disabled 27 59 Under Overvoltage Protec tion 139 50BF Disabl...

Page 32: ...ible Function 04 Flexible Function 05 Flexible Function 06 Flexible Function 07 Flexible Function 08 Flexible Function 09 Flexible Function 10 Flexible Function 11 Flexible Function 12 Flexible Function 13 Flexible Function 14 Flexible Function 15 Flexible Function 16 Flexible Function 17 Flexible Function 18 Flexible Function 19 Flexible Function 20 Please select Flexible Functions Addr Parameter...

Page 33: ...ce one or more protection functions have picked up but no tripping by the 7SD80 resulted because the fault was cleared by a different device e g on another line These messages are then limited to faults in the line to be protected The following figure illustrates the creation of the reset command for stored messages By the moment of the device dropout the presetting of the parameter610 FltDisp LED...

Page 34: ...of the default display appearing after startup of the device can be selected in the device data via parameter 640 Start image DD The pages available for each device version are listed in the Appendix A 5 Protection Interface Test Mode To check the communication quality of the two 7SD80 devices during commissioning set parameter 650 PDI Test Mode to ON The availability of the communication link via...

Page 35: ...d annunciation 3 14 Annunc 4 SP User defined annunciation 4 15 Test mode SP Test mode 16 DataStop SP Stop data transmission 51 Device OK OUT Device is Operational and Protecting 52 ProtActive IntSP At Least 1 Protection Funct is Active 55 Reset Device OUT Reset Device 56 Initial Start OUT Initial Start of Device 60 Reset LED OUT_Ev Reset LED 67 Resume OUT Resume 68 Clock SyncError OUT Clock Synchr...

Page 36: ...FB 320 Warn Mem Data OUT Warn Limit of Memory Data exceeded 321 Warn Mem Para OUT Warn Limit of Memory Parameter exceeded 322 Warn Mem Oper OUT Warn Limit of Memory Operation exceeded 323 Warn Mem New OUT Warn Limit of Memory New exceeded 2054 Emer mode OUT Emergency mode 32200 PDITestFOon OFF IntSP PDI Test Mode FO ON OFF 32201 PDITestCuon OFF IntSP PDI Test Mode Cu ON OFF 32202 PDI Test Mode OUT...

Page 37: ... setting defines the measuring direction of the device current in line direction is defined as positive at both line ends The reversal of this parameter also reverses the polarity of the ground current input IN Figure 2 2 Polarity of current transformers Nominal Values of Transformers In addresses 203 Vnom PRIMARY and 204 Vnom SECONDARY the device obtains information on the primary and secondary r...

Page 38: ...ial protection Address 220 is then set to I4 transformer and address 221I4 Iph CT depends on the transforma tion ratio of the starpoint transformer to the transformer set of the protected line If the input I4 is not required set Address 220 I4 transformer Not connected Address 221 I4 Iph CT is then irrelevant In this case the neutral current is calculated by summing the phase currents Rated Freque...

Page 39: ...enough to ensure that the circuit breaker has securely closed An excessive duration causes no problem since the closing command is interrupted in the event that another trip is initiated by a protection function This parameter can only be set in DIGSI at Display Additional Set tings Circuit Breaker Test 7SD80 allows a circuit breaker test during operation using a trip and close command entered on ...

Page 40: ...quency 50 Hz 60 Hz 50 Hz Rated Frequency 240A TMin TRIP CMD 0 02 30 00 sec 0 10 sec Minimum TRIP Command Dura tion 241A TMax CLOSE CMD 0 01 30 00 sec 1 00 sec Maximum Close Command Dura tion 242 T CBtest dead 0 00 30 00 sec 0 10 sec Dead Time for CB test autoreclo sure 260 Threshold BI 1 Thresh BI 176V Thresh BI 88V Thresh BI 19V Thresh BI 176V Threshold for Binary Input 1 261 Threshold BI 2 Thres...

Page 41: ...ecorded during the fault event and also calculates additional information from the measured values Currents and voltages can be presented either as primary or as secondary values Signals are additionally recorded as binary tracks marks e g pickup trip If port B of the device has been configured correspondingly the fault record data can be imported by a central controller via this interface and eva...

Page 42: ...eform Capture 403A WAVEFORM DATA Fault event Pow Sys Flt Fault event Scope of Waveform Data 410 MAX LENGTH 0 30 5 00 sec 2 00 sec Max length of a Waveform Capture Record 411 PRE TRIG TIME 0 05 0 50 sec 0 25 sec Captured Waveform Prior to Trigger 412 POST REC TIME 0 05 0 50 sec 0 10 sec Captured Waveform after Event 415 BinIn CAPT TIME 0 10 5 00 sec 0 50 sec Capture Time via Binary Input No Informa...

Page 43: ...h setting group remain the same 2 1 5 2 Setting Notes General If setting group change option is not required Group A is the default selection Then the rest of this section is not applicable If the changeover option is desired group changeover must be set to Grp Chge OPTION Enabled address 103 when the function extent is configured For the setting of the function parameters each of the required set...

Page 44: ...for all ends This setting will not only have an impact on the indication of the operational measured values in per cent but must also be exactly the same for each end of the protected object since it is the basis for the current comparison at the ends General Line Data The directional values power power factor work and based on work minimum maximum average and threshold values calculated in the op...

Page 45: ...es are used to determine closure of the circuit breaker whereas 52a OR I or M C implies that either the currents or the states of the circuit breaker auxiliary contacts are used to determine closure of the circuit breaker If the voltage transformers are not arranged on the line side the setting 52a OR I or M C must be used In the case of I or Man Close only the currents or the manual close signals...

Page 46: ...t be connected to the correct circuit breaker The binary inputs CB then need the correct signals for detecting the circuit breaker status In certain cases an additional CFC logic may be necessary For commands via the integrated control local control DIGSI serial interface address 1152 Man Clos Imp determines whether a close command via the integrated control function should be treated by the pro t...

Page 47: ... reversed reversed not reversed P Q operational measured values sign 1130A PoleOpenCurrent 1A 0 05 1 00 A 0 10 A Pole Open Current Threshold 5A 0 25 5 00 A 0 50 A 1131A PoleOpenVoltage 2 70 V 30 V Pole Open Voltage Threshold 1132A SI Time all Cl 0 01 30 00 sec 0 10 sec Seal in Time after ALL clo sures 1133A T DELAY SOTF 0 05 30 00 sec 0 25 sec minimal time for line open before SOTF 1134 Line Closu...

Page 48: ...l SP 52a Bkr1 aux 3pClosed for AR CB Test 411 52b Bkr1 3p Op SP 52b Bkr1 aux 3p Open for AR CB Test 501 Relay PICKUP OUT Relay PICKUP 502 Relay Drop Out OUT Relay Drop Out 503 Relay PICKUP ØA OUT Relay PICKUP Phase A 504 Relay PICKUP ØB OUT Relay PICKUP Phase B 505 Relay PICKUP ØC OUT Relay PICKUP Phase C 506 Relay PICKUP G OUT Relay PICKUP GROUND 510 Relay CLOSE OUT Relay GENERAL CLOSE command 51...

Page 49: ...minals D1 and D2 The input of the protection interface Prot Cu has an insulated design The integrated overvoltage protection reduces the insulation strength Use an external isolating transformer to increase the insulation strength The ordering data can be found in Section A 1 under Accessories If the device has 2 protection interfaces the data are preferably exchanged with the device at the other ...

Page 50: ...t has been detected in the protection interface communication the time at address 4512 Td ResetRemote is started for resetting the remote signals Please note that only the time of the device whose remote end has failed is effective Protection Interface Optical Fiber If you use an optical fiber connection switch it ON or OFF at address 4501 PDI FO Address 4502 PDI FO TER allows you to enter the per...

Page 51: ...ate 4603 PDI Cu mode 01 02 03 04 05 06 01 PDI Cu operation mode 4604 PDI Cu MAX ATT 0 46 dB 46 dB PDI Cu maximum attenuation 4605 PDI Cu S N 6 30 dB 6 dB PDI Cu min signal to noise ratio No Information Type of In formation Comments 3217 PDI FO mirror OUT PDI FO data mirror 3218 PDI Cu mirror OUT PDI Cu data mirror 3227 PDI FO stop SP PDI FO is stopped 3228 PDI Cu stop SP PDI Cu is stopped 3230 PDI...

Page 52: ...d object communicate over their protection interfaces with one device acting as master the other as slave The device configured as master can perform the time synchronization for both devices 2 2 1 1 Setting Notes Protection Data Topology At address 4701 ID OF MASTER and 4702 ID OF SLAVE you can enter the device identification number of the two protection devices at the line ends Use address 4710 ...

Page 53: ...mparison shows without any doubt that a fault is present the trip command is sent It is maintained over a set minimum command duration The phase comparison protection may trip only at one end in case of single end infeed The non feeding end can also be switched off by means of a transfer trip signal Element Idyn The dynamic filter algorithm generates the value idyn t It represents the current chan...

Page 54: ...e dynamic sign comparison is blocked If the pickup is successful an internal pickup signal is transmitted to the other device The element Idyn is blocked if the frequency deviates by more than 10 from the rated frequency The function is blocked if the communication between the two devices at the ends of the protected object fails for more than two measuring cycles This function can also be blocked...

Page 55: ...0 Manual E50417 G1140 C474 A1 Release date 09 2011 55 The pickup signals created locally signs of idyn and istat and the blocking information are sent to the device at the opposite end Figure 2 6 Phase comparison protection sending the differential protection information to the opposite end ...

Page 56: ...ith the own differential protection information and element specific pickup indications are created Figure 2 7 Phase comparison protection receiving the differential protection information from the opposite end The following figure shows the formation of the phase specific pickup of the phase comparison protection Figure 2 8 Logic diagram of phase comparison protection for pickup in a grounded sys...

Page 57: ...rotection and the differential protection tripping in Section 2 2 5 2 2 2 2 Setting Notes General The phase comparison protection can be switched ON or OFF at address 1201 87L PCC Prot This requires the differential protection to be set to Enabled at address 112 87 DIFF PROTEC For cables and long lines the capacitive charging current is decisive for determining the pickup values The charging curre...

Page 58: ...ed inrush current At address 1205 87L I min you can enter the threshold for releasing the pickup signal The value should at least correspond to the setting of 87L Idyn but not exceed the largest transformer rated current of the con stellation Note When using different transformers in the constellation set identical primary setting values The secondary setting values can be different Time Delays Th...

Page 59: ... I2 flowing in from both sides is fed to the measuring element As a result the simple circuit ensures reliable tripping of the protection if the fault current flowing into the protected zone during a fault is high enough for the measuring element M to respond Figure 2 10 Basic principle of the differential protection for a line with two ends This principle only applies to the primary system as lon...

Page 60: ... transformers within the nominal range and or the short circuit current range is multiplied with the current flowing through each end of the protected object The total value including the measured internal errors is then transmitted to the other end This is the reason why the restraint current is a replica of the greatest possible measurement error of the entire differential protection system The ...

Page 61: ...munications link interblocking If the overcurrent protection is config ured as an emergency function all devices will automatically switch to this emergency operation mode Pickup Logic The following figure illustrates the pickup logic of the ground current differential protection for grounded sys tems Figure 2 12 Ground current differential protection pickup grounded system You will find the logic...

Page 62: ...or cables and long overhead lines the charging current has to be consid ered in particular It is calculated from the operational capacitance see Section 2 2 2 2 Considering the variations of voltage and frequency the value set should be at least 2 5 to 3 times higher than the calculated charging current Moreover the pickup value should not be smaller than 15 of the primary rated current of the lar...

Page 63: ...n dicated and the affected piece of equipment is to be localized if possible eliminating the ground fault by initi ating appropriate switching operations The 7SD80 enables the precise localization of the piece of equipment line affected by the ground fault In resonant grounded systems a core balance current transformer must be used to detect the ground current Figure 2 13 Ground fault in non groun...

Page 64: ... is not suited for direction determination of the ground cur rent In this case only the ohmic active residual current which results from the losses of the Petersen coil can be used for direction determination This residual ground fault residual current is only about some per cent of the capacitive ground fault current The active and reactive component of the power is decisive for the ground fault ...

Page 65: ...ase Comparison Protection and Ground Differential Protection SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 65 Figure 2 14 Ground fault differential protection pickup isolated resonant grounded system ...

Page 66: ...f the faulted cable itself to flow through the measuring point as the latter flows directly to the fault location i e not back via the measuring point Enter about half of this ground fault current as pickup value In resonant grounded systems directional determination is made more difficult since a much larger reactive current capacitive or inductive is superimposed on the critical wattmetric activ...

Page 67: ...ivated the time delay 87N L TripDelay must be at least 20 ms for the blocking by the inrush current restraint to be effective 2 2 5 Differential Protection Pickup Logic and Tripping Logic 2 2 5 1 Description Pickup Logic Once the differential protection function has reliably registered a fault within its tripping zone the signal 87 N L Gen Flt general pickup of the differential protection is gener...

Page 68: ...Figure 2 16 Differential protection trip If the pickup signals apply for longer than the configurable trip time delay the differential protection trips 2 2 6 87 Differential Protection The following tables provide an overview of the parameters and information of the functions phase comparison protection Ground current differential protection in grounded systems ground fault differential protection...

Page 69: ...0 100 00 A 5 00 A 1206 87L Trip Delay 0 00 0 10 sec 0 00 sec Trip Delay 1207 87L Man Close DELAYED UNDELAYED DELAYED Trip response after manual close 1208 87L T EFdetect 0 00 32 00 sec 0 00 sec Evolving fault detect time 1ph faults 1214 87L Inrush blk NO YES NO Inrush blocking 1221 87N L Protect OFF ON Alarm Only ON 87N L protection 1222 87N L I DIFF 1A 0 10 20 00 A 0 30 A 3I0 DIFF Pickup value 5A...

Page 70: ...FF 3263 Comm 87 ONoffBI IntSP 87 Commissioning state ON OFF via BI 32100 87L block SP 87L Protection blocking signal 32102 87L active OUT 87L Protection is active 32103 87L Fault A OUT 87L Fault detection A 32104 87L Fault B OUT 87L Fault detection B 32105 87L Fault C OUT 87L Fault detection C 32107 87L is blocked OUT 87L Protection is blocked 32108 87L is OFF OUT 87L Protection is switched off 32...

Page 71: ...tial protection generates a transfer trip signal The test mode can be activated deactivated as follows Operation panel Menu Control Taggings Set Test mode Via binary inputs no 3197 Test 87 ON no 3198 Test 87 OFF if this was routed 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 indication T...

Page 72: ...9 it has to be observed that binary input Test 87 ON no 3197 is parameterized as NO contact and that binary input Test 87 OFF no 3198 is parameterized as NC contact Figure 2 18 External push button wiring for controlling the differential protection test mode Bu1 Push button Switching off the differential protection test mode Bu2 Push button Switching on the differential protection test mode Figure...

Page 73: ... point of the differential protection can be changed without any risk up to the generation of a pickup Figure 2 20 Commissioning mode overview The commissioning mode is activated on a device of the protective device constellation and also affects the device at the other end of the protected object indication no 3193 Comm 87 active The commissioning mode has to be deactivated on the device on which...

Page 74: ...the way used for activating The indication Commiss 87 no 3191 is generated independently of the chosen way The following figures show possible variants for controlling the binary inputs If a switch is used for control Figure 2 23 it has to be observed that binary input Comm 87 ON no 3260 is parameterized as NO contact and that binary input Comm 87 OFF no 3261 is parameterized as NC contact Figure ...

Page 75: ... SEND is set to YES each tripping command of the differential protection is routed immediately to the transmission function ITrp sen A to C intertrip and transmitted via the protection data interfaces and communication links The send function can be triggered via binary input 85 DT 3pol remote tripping The transmission signal can be delayed with 85 DT TD BI and prolonged with 85 DT T PROL BI Figur...

Page 76: ...d it may be desirable to switch off the feeding end only In such exceptional cases the intertrip func tion is not needed Intertrip Remote Tripping The activated intertrip function starts automatically when the differential protection trips at only one end If the relevant binary inputs are allocated and activated by an external source the intertrip signal is transmitted as well In this case the sig...

Page 77: ...0 rel for the minimum ground current 3I0 2 3 3 Settings The table indicates region specific default settings Column C configuration indicates the corresponding sec ondary nominal current of the current transformer 2 3 4 Information List Addr Parameter C Setting Options Default Setting Comments 1301 85 DT SEND YES NO YES 85 DT State of transm the intertrip cmd 1302 85 DT RECEIVE Alarm only Trip Tri...

Page 78: ...fferential protection is faulty emergency operation The differential protection is blocked in this case Backup Time Overcurrent Protection If the overcurrent protection is set as backup time overcurrent protection it will work independently of the other protection and monitoring functions i e also independently of the differential protection The backup overcur rent protection can also act as the o...

Page 79: ...ther a non delayed trip of this element via binary input 5X B InstTRIP is possible YES or impossible NO This parameter is also used for fast tripping before reclosing If parameter 50 B2 Inrush address2625 is set to YES the element is blocked Figure 2 26 Logic diagram of the 50 1 element Definite Time Overcurrent Element 50 2 The logic of the overcurrent elements 50 2 is the same as the logic of th...

Page 80: ...0 3 element Inverse Time Overcurrent Element 51 The logic of the inverse overcurrent element basically operates in the same way as the other elements The time delay however is calculated based on the type of the set characteristic the intensity of the current and a time multiplier following figure A pre selection of the available characteristics was already carried out during the configuration of ...

Page 81: ...ferent inverse times and additional times can be parameterized here The following figure shows the logic diagram The setting addresses of the IEC characteristic curves are shown by way of example In the setting notes Section 2 4 4 the different setting addresses are described in detail If parameter 51 B Inrush address 2637 is set to YES the element is blocked Figure 2 28 Logic diagram of the 51 el...

Page 82: ...cation Display Output indication No 50 2 PU A 50 1 PU A 50 3 PU A 51 PU A 2 26 2 27 2 28 5X B Pickup ØA 7162 50 2 PU B 50 1 PU B 50 3 PU B 51 PU B 2 26 2 27 2 28 5X B Pickup ØB 7163 50 2 PU C 50 1 PU C 50 3 PU C 51 PU C 2 26 2 27 2 28 5X B Pickup ØC 7164 50 2 PU N 50 1 PU N 50 3 PU N 51 PU N 2 26 2 27 2 28 5X B Pickup Gnd 7165 50 1 PU A 50 1 PU B 50 1 PU C 50 1 PU N 2 26 2 26 2 26 2 26 50 N B2 PIC...

Page 83: ...ound voltages if the voltage value is 70 of the rated voltage The negative sequence system quantities V2 and I2 are used for 1 phase or 2 phase faults if I2 50 mA and V2 5 V When using the negative sequence system quantities it is the short circuit with the higher current which deter mines the direction in case of two 1 phase short circuits If none of the above measured quantities is available an ...

Page 84: ...e pickup value Figure 2 30 shows the logic diagram of the 67 1 elements They can be blocked via the binary input Addition ally the ground current element can be blocked separately via the binary input BLOCK 67N TOC The binary input 5X B InstTRIP and the evaluation of the indication switch onto fault can act sepa rately on the directional phase and or ground element Parameter 67 N B2 Pil BI address...

Page 85: ...Functions 2 4 Backup Overcurrent SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 85 Figure 2 30 Logic diagram of the 67 1 element ...

Page 86: ...d using the measured quantities and the corresponding directional characteristics The time delay however is calculated based on the type of the set characteristic the intensity of the current and the time factor 67 TOC TD ANSI or 67N TOC TD ANSI Furthermore an additional constant time delay 67 TOC AddTDel or 67N TOC AddTDel may be selected which is added to the inverse time The possible characteri...

Page 87: ...4 Backup Overcurrent SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 87 Figure 2 31 Logic diagram of the 67 TOC element directional inverse time overcurrent protection example for IEC characteristic ...

Page 88: ...e Failure An element specific parameter e g 67 N B1 on FFM allows you to define how the directional overcurrent protection acts when the measuring voltage fails The overcurrent protection then works either Non Directional or it is Internal indication Display Output indication No 67 1 PU A 67 2 PU A 67 TOC PU A 2 30 2 31 67 1 PU B 67 2 PU B 67 TOC PU B 2 30 2 31 67 1 PU C 67 2 PU C 67 TOC PU C 2 30...

Page 89: ...ercurrent protection If set to Only Emer prot the overcurrent protection operates as emergency function Set to OFF the element is disabled Direction The elements 50 1 50 2 and 50N operate directionally and non directionally The direction is set specifically for each element The setting applies collectively to the corresponding phase and ground element 50 1 3I0 address 2621 50 2 3I0 address 2611 50...

Page 90: ...by the maximum operational current Pickup due to overload must be excluded as the device operates as short circuit protection in this mode with correspond ingly short command times and not as overload protection A pickup value setting of about 10 is recommend ed for line protection and a setting of about 20 of the expected peak load is recommended for transformers and motors The ground current ele...

Page 91: ...tion is only activated in the case of the loss of the local measuring voltage The times for the ground current elements can be set shorter according to a separate time grading chart for ground currents You can set additional time delays for definite time elements with IEC characteristic 51 B AddT DELAY 67 TOC AddTDel addess 2636 51N B AddTdelay 67N TOC AddTDel addess 2641 Instantaneous Tripping vi...

Page 92: ...eristic curves Address 126 allows you to specify whether you work with IEC characteristics 50 N 51 N IEC or ANSI characteristics 50 N 51 N ANSI If you work with IEC characteristics you can select the following setting options at address 2642 Normal Inverse Very Inverse Extremely Inv LongTimeInverse If you work with ANSI characteristics you can select the following setting options at address 2643 I...

Page 93: ... Directional BLOCKED BLOCKED 67 N B1 Direct stage on Fuse Failure 2613 50 B1 PICKUP 1A 0 10 25 00 A 2 00 A 50 B1 Pickup 5A 0 50 125 00 A 10 00 A 2613 67 B1 PICKUP 0 10 25 00 A 2 00 A 67 B1 Pickup threshold 2614 50 B1 DELAY 0 00 30 00 sec 0 30 sec 50 B1 Delay 2614 67 B1 DELAY 0 00 30 00 sec 0 30 sec 67 B1 set time delay 2615 50 B1 Inrush NO YES NO 50 B1 Inrush blocking 2615 67 B1 Inrush NO YES NO 6...

Page 94: ... 50N B2 DELAY 0 00 30 00 sec 2 00 sec 50N B2 Delay 2627 67N B2 DELAY 0 00 30 00 sec 2 00 sec 67N B2 set time delay 2628 50 N B2 Pil BI NO YES NO Instantaneous trip via Pilot Prot BI 2628 67 N B2 Pil BI NO YES NO Instantaneous trip via Pilot Prot BI 2630 Op Mode 51 N B ON Only Emer prot OFF OFF Operating Mode 51 N B 2630 Op Mode67 N TOC ON Only Emer prot OFF OFF Operating Mode 67 N TOC 2631 67 N TO...

Page 95: ...3 00 sec 0 50 sec 67N TOC Time Dial for IEC characteristic 2640 51N B TD ANSI 0 50 15 00 5 00 51N B Time Dial for ANSI characteristic 2640 67N TOC TD ANSI 0 50 15 00 5 00 67N TOC Time Dial for ANSI char 2641 51N B AddTdelay 0 00 30 00 sec 0 00 sec 51N B Additional Time Delay 2641 67N TOC AddTDel 0 00 30 00 sec 0 00 sec 67N TOC Additional Time Delay 2642 IEC Curve Normal Inverse Very Inverse Extrem...

Page 96: ...BLOCK 51 B SP BLOCK 51 B Backup OverCurrent 7107 BLOCK 50N B1 SP BLOCK 50N B1 Backup OverCurrent 7108 BLOCK 50N B2 SP BLOCK 50N B2 Backup OverCurrent 7109 BLOCK 51N SP BLOCK 51N Backup OverCurrent 7110 5X B InstTRIP SP 50 N 51 N BackupO C InstantaneousTrip 7112 BLOCK 67 TOC SP BLOCK Backup OverCurrent 67 TOC 7114 BLOCK 67N TOC SP BLOCK Backup OverCurrent 67N TOC 7115 BLOCK 67 B1 SP BLOCK Backup Ov...

Page 97: ...B2 TRIP OUT 67 N B2 TRIP 7256 67 N TOC TRIP OUT 67 N TOC TRIP 7257 67 forward ØA OUT 67 Phase A forward 7258 67 forward ØB OUT 67 Phase B forward 7259 67 forward ØC OUT 67 Phase C forward 7260 67N forward GND OUT 67N Gnd forward 7261 67 reverse ØA OUT 67 Phase A reverse 7262 67 reverse ØB OUT 67 Phase B reverse 7263 67 reverse ØC OUT 67 Phase C reverse 7264 67N reverse GND OUT 67N Gnd forward 7265...

Page 98: ...r the inrush current detection is examined in each device in which this function has been activated The blocking condition is transmitted to the other device so that it is effective at both ends of the protected object Figure 2 32 Logic diagram of the inrush restraint for one phase Since the inrush restraint operates individually for each phase the protection is fully operative when the trans form...

Page 99: ...red for restraint can be parameterized In order to be able to achieve a higher degree of restraint in case of exceptionally unfavorable inrush conditions you may also set 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...

Page 100: ...2 2nd HARMONIC 10 45 15 2nd harmonic in of fundamen tal 2303 CROSS BLOCK NO YES NO Cross Block 2305 MAX INRUSH PEAK 1 1 25 0 A 15 0 A Maximum inrush peak value 2310 CROSSB 2HM 0 00 60 00 sec 0 00 sec Time for Crossblock with 2nd har monic No Information Type of In formation Comments 3102 2nd Harmonic A OUT Tolerance invalid in phase A 3103 2nd Harmonic B OUT Tolerance invalid in phase B 3104 2nd H...

Page 101: ...reaker will open and interrupt the fault current The current monitoring element quickly resets typical 10 ms and stops the timer T BF If the trip command is not carried out breaker failure case current continues to flow and the timer runs to its set limit The breaker failure protection then issues a command to trip the backup breakers and interrupt the fault current The reset time of the feeder pr...

Page 102: ...rrent the ground current residual current IE 3 I0 is preferably used If the residual current from the neutral of the current transformer set is connected to the device it is used If the residual current is not available the device calculates it with the formula 3 I0 IA IB IC Additionally the value calculated by 7SD80 of three times the negative sequence current 3 I2 is used for plau sibility check...

Page 103: ... Failure Protection 50BF SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 103 Figure 2 36 Current flow monitoring with plausibility currents 3 I0 and 3 I2 1 only usable visible if address 139 is set to enabled w 3I0 ...

Page 104: ... current flow criterion according to Figure 2 36 is present the breaker failure pro tection is initiated and the corresponding time delay s is are started If the current criterion is not satisfied for any of the phases the circuit breaker auxiliary contact can be interro gated according to figure 2 37 After a 3 pole trip command the circuit breaker has only operated correctly when no current flows...

Page 105: ...onditions for the breaker failure protection are those discussed above De pending on the application of the feeder protection common phase or phase segregated initiation conditions may occur Tripping by the breaker failure protection is always 3 pole T2 is used as time delay With two element breaker failure protection the trip command of the feeder protection is usually repeated after a first time...

Page 106: ...et to 0 is started Figure 2 40 Thus the adjacent circuit breakers bus bar are tripped immediately in case the feeder circuit breaker is not operational Figure 2 40 Circuit breaker faulty Transfer Trip to the Remote End Circuit Breaker The device has the facility to provide an additional intertrip signal to the circuit breaker at the remote line end in the event that the local feeder circuit breake...

Page 107: ... end fault protection has the task to recognize this situation and to transmit a trip signal to the remote end s of the protected object to clear the fault For this purpose the output command 50BF EndFltTrip is avail able to trigger a signal transmission device e g power line carrier radio wave or optical fiber if applicable together with other commands that need to be transferred or when using di...

Page 108: ...is not available in the device this criterion cannot be pro cessed In this case set address 3909 Chk BRK CONTACT to NO Two Element Breaker Failure Protection With two element operation the trip command is repeated after a time delay T1 to the local feeder breaker normally to a different set of trip coils of this breaker If the circuit breaker does not respond to this trip repetition the adjacent c...

Page 109: ...tripped after the time delay 50BF 2 Delay address 3906 has elapsed The time 50BF 1 Delay 3p address 3905 is set to because it is not needed The time delay to be set should be based on the maximum circuit breaker operating time plus the dropout time of the current flow monitoring element plus a safety margin which takes into consideration the tolerance of the time delay Figure 2 44 illustrates the ...

Page 110: ...ault 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 EndFault Delay address 3922 is started when during the time of pickup condition of the feeder protection the circuit breaker auxiliary contacts indicate open poles and at the same time current flow is ...

Page 111: ...h off breaker fail prot 1403 BLOCK 50BF SP BLOCK 50BF 1404 50BF 3I0 SP 50BF use 3I0 threshold 1415 50BF Start 3p SP 50BF External start 3pole 1424 50BFSTRTonlyT2 SP 50BF Start only delay time T2 1432 50BF release SP 50BF External release 1439 50BF STARTw oI SP 50BF External start 3p w o current 1440 BkrFailON offBI IntSP Breaker failure prot ON OFF via BI 1451 50BF OFF OUT 50BF is switched OFF 145...

Page 112: ...this case only an alarm is output when the final 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 considers the effect of har monic content A choice can be made whether the maximum calculated overtemperature of the three phases the average ...

Page 113: ...k is set under address 4202 49 K FACTOR It is determined by the relation between the permissible thermal continuous current and this rated 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 temperature...

Page 114: ... t6 time this is the time in seconds for which a current of 6 times the rated 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 Warning Temperature Level By setting a thermal alarm stage 49 Θ ALARM address 4204 an alarm can be provided before the tripping temperature is reached so that a trip can be avoided by ...

Page 115: ... chosen at any rate 2 7 3 Settings The table indicates region specific default settings Column C configuration indicates the corresponding sec ondary nominal current of the current transformer 2 7 4 Information List Addr Parameter C Setting Options Default Setting Comments 4201 FCT 49 OFF ON Alarm Only OFF 49 Thermal overload pro tection 4202 49 K FACTOR 0 10 4 00 1 10 49 K Factor 4203 TIME CONSTA...

Page 116: ...ge regulation fails or after full load shutdown of a generator 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 the overvoltage will endanger the insulation if the reactors fail e g due to fault clearance The line must be de energized within a very short time The undervoltage protection c...

Page 117: ...hase to phase overvoltage protection operates just like the phase to ground protection except that it detects phase to phase voltages Accordingly phase to phase voltages which have exceeded one of the element thresholds 59 1 Vpp PICKUP address 3712 or 59 2 Vpp PICKUP address 3714 are also indi cated Apart from that Figure 2 46 also applies generally The phase phase overvoltage protection can also ...

Page 118: ...ed to the two threshold elements 59 1 V1 PICKUP address 3732 and 59 2 V1 PICKUP address 3734 see Figure 2 47 Combined with the associated time delays 59 1 V1 DELAY address 3733 and 59 2 V1 DELAY address 3735 these elements form a two element overvoltage protection for the positive sequence system Here too the dropout ratio can be set The overvoltage protection for the positive sequence system can ...

Page 119: ...2 V2 DELAY address 3745 these elements form a two element overvoltage protection for the negative sequence system Here too the dropout ratio can be set Figure 2 48 Logic diagram of the overvoltage protection for the negative sequence voltage system V2 The overvoltage protection for the negative sequence system can also be blocked via a binary input 59 V2 BLOCK The elements of the negative sequence...

Page 120: ...ltage protec tion for the zero sequence system Here too the dropout ratio can be set 59G RESET address 3729 Fur thermore a restraint delay can be configured which is implemented by repeated measuring approx 3 periods The overvoltage protection for the zero sequence system can also be blocked via a binary input 59 3V0 BLOCK The elements of the zero sequence voltage protection are automatically bloc...

Page 121: ...erent behavior of the undervoltage protection when the line is de energized While the voltage usually remains present or reappears on the busbar side after a trip command and opening of the circuit breaker it becomes zero on the outgoing side For the undervoltage protection this results in a pickup state being present if the voltage transformers are on the outgoing side If this pickup must be rese...

Page 122: ...ions 2 8 Undervoltage and Overvoltage Protection 27 59 Optional SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 122 Figure 2 50 Logic diagram of the undervoltage protection for phase voltages ...

Page 123: ...ve Sequence System V1 The device calculates the positive sequence system according to its defining equation V1 1 3 VA a VB a2 VC where a ej120 The resulting positive sequence voltage is fed to the two threshold elements 27 1 V1 PICKUP address 3772 and 27 2 V1 PICKUP address 3774 see Figure 2 51 Combined with the associated time delays 27 1 V1 DELAY address 3773 and 27 2 V1 DELAY address 3775 these...

Page 124: ...o ground voltages phase to phase voltages or the symmetrical positive sequence system of the voltages the symmetrical negative sequence system or the zero sequence voltage can also be used for overvoltage Any combination is possible Detection procedures that are not required are switched OFF Note For overvoltage protection it is particularly important to observe the setting notes Never set an over...

Page 125: ...address 3713 and 59 2 Vpp DELAY address 3715 the same con siderations apply as above The same is true for the dropout ratios address 3719 59 Vpp RESET The latter setting can only be altered in DIGSI at Display Additional Settings Overvoltage Positive Sequence System V1 The positive sequence voltage elements can be used instead of or in addition to previously mentioned over voltage elements Accordi...

Page 126: ...e set in DIGSI at Display Additional Settings Please con sider that sensitive settings combined with short pickup times are not recommended The dropout to pickup ratio 59G RESET can be set in address 3729 This parameter can only be set in DIGSI at Display Additional Settings Undervoltage Phase to Ground The phase voltage elements can be switched ON or OFF in address 3751 27 Vph g Mode In addition ...

Page 127: ...ositive sequence undervoltage elements can be used instead of or in addition to previously mentioned undervoltage elements Accordingly set address 3771 27 V1 Mode to ON OFF Alarm Only or V Alarm V Trip Basically the same considerations apply as for the other undervoltage elements Especially in case of stability problems the positive sequence system is advantageous since the positive sequence syste...

Page 128: ...2 0 220 0 V 150 0 V 59 1 Pickup Overvoltage phase phase 3713 59 1 Vpp DELAY 0 00 100 00 sec 2 00 sec 59 1 Time Delay 3714 59 2 Vpp PICKUP 2 0 220 0 V 175 0 V 59 2 Pickup Overvoltage phase phase 3715 59 2 Vpp DELAY 0 00 100 00 sec 1 00 sec 59 2 Time Delay 3719A 59 Vpp RESET 0 30 0 99 0 98 Reset ratio 3721 59G 3V0 or Vx OFF Alarm Only ON V Alarm V Trip OFF Operating mode 3V0 overvoltage 3722 59G 1 3...

Page 129: ...al 3753 27 1 Vph DELAY 0 00 100 00 sec 2 00 sec 27 1 Time Delay 3754 27 2 Vph PICKUP 1 0 100 0 V 0 10 0 V 27 2 Pickup Undervoltage phase neutral 3755 27 2 Vph DELAY 0 00 100 00 sec 1 00 sec 27 2 Time Delay 3758 CURR SUP 27 Vph ON OFF ON Current supervision Vph g 3759A 27 Vph RESET 1 01 1 20 1 05 Reset ratio 3761 27 Vph ph Mode OFF Alarm Only ON V Alarm V Trip OFF Operating mode Vph ph under voltag...

Page 130: ...9 Vphg OFF OUT 59 Vphg Overvolt is switched OFF 10216 59 Vphg BLK OUT 59 Vphg Overvolt is BLOCKED 10217 59 Vphph OFF OUT 59 Vphph Overvolt is switched OFF 10218 59 Vphph BLK OUT 59 Vphph Overvolt is BLOCKED 10219 59 3V0 OFF OUT 59 3V0 Overvolt is switched OFF 10220 59 3V0 BLK OUT 59 3V0 Overvolt is BLOCKED 10221 59 V1 OFF OUT 59 V1 Overvolt is switched OFF 10222 59 V1 BLK OUT 59 V1 Overvolt is BLO...

Page 131: ...hph Pickup A B 10267 59 2 Vpp PU BC OUT 59 2 Vphph Pickup B C 10268 59 2 Vpp PU CA OUT 59 2 Vphph Pickup C A 10270 59 1 3V0 Pickup OUT 59 1 3V0 Pickup 10271 59 2 3V0 Pickup OUT 59 2 3V0 Pickup 10272 59 1 3V0TimeOut OUT 59 1 3V0 TimeOut 10273 59 2 3V0TimeOut OUT 59 2 3V0 TimeOut 10274 59 3V0 TRIP OUT 59 3V0 TRIP command 10280 59 1 V1 Pickup OUT 59 1 V1 Pickup 10281 59 2 V1 Pickup OUT 59 2 V1 Pickup...

Page 132: ...C OUT 27 2 Vphg Pickup C 10325 27 1 Vpp Pickup OUT 27 1 Vphph Pickup 10326 27 2 Vpp Pickup OUT 27 2 Vphph Pickup 10327 27 Vpp PU AB OUT 27 Vphph Pickup A B 10328 27 Vpp PU BC OUT 27 Vphph Pickup B C 10329 27 Vpp PU CA OUT 27 Vphph Pickup C A 10330 27 1 VppTimeOut OUT 27 1 Vphph TimeOut 10331 27 2 VppTimeOut OUT 27 2 Vphph TimeOut 10332 27 Vpp TRIP OUT 27 Vphph TRIP command 10333 27 1 Vpp PU AB OUT...

Page 133: ... cy element f or as underfrequency element f with individual thresholds and time delays This ensures vari able matching to the application purpose If an element is set to a value above the rated frequency it is automatically interpreted to be an overfrequen cy element f If an element is set to a value below the rated frequency it is automatically interpreted to be an underfre quency element f If a...

Page 134: ...stems frequency deviations may also be caused by power swings Depending on the power swing frequency the mounting location of the device and the setting of the frequency elements power swings may cause the frequency protection to pick up 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 b...

Page 135: ...Functions 2 9 Frequency Protection 81 Optional SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 135 Figure 2 52 Logic diagram of frequency protection for 50 Hz rated frequency ...

Page 136: ... under frequency If an element is set to a value above the rated frequency it is automatically interpreted to be an overfrequen cy element f If an element is set to a value below the rated frequency it is automatically interpreted to be an underfre quency element f If an element is set exactly to the rated frequency it is inactive A pickup value can be set for each element according to above rules...

Page 137: ...ected before the frequency protection trips Further application examples exist in the field of power stations The frequency values to be set mainly depend on the specifications of the power system power station operator In this context the underfrequency protection also ensures the power station s own demand by disconnecting it from the power system in time The turbo regulator regulates the machin...

Page 138: ... Type of In formation Comments 5203 BLOCK 81O U SP BLOCK 81O U 5206 BLOCK 81 1 SP BLOCK 81 1 5207 BLOCK 81 2 SP BLOCK 81 2 5208 BLOCK 81 3 SP BLOCK 81 3 5209 BLOCK 81 4 SP BLOCK 81 4 5211 81 OFF OUT 81 OFF 5212 81 BLOCKED OUT 81 BLOCKED 5213 81 ACTIVE OUT 81 ACTIVE 5215 81 UnderV Blk OUT 81 Undervoltage Block 5232 81 1 picked up OUT 81 1 picked up 5233 81 2 picked up OUT 81 2 picked up 5234 81 3 p...

Page 139: ...delayed alarmed and routed to one or several output relays 2 10 1 Description External Tripping of the Local Circuit Breaker The external tripping can be switched on and off with a setting parameter and may be blocked via binary input The tripping logic of the device ensures that the conditions for the tripping logic are satisfied The phase currents and the ground current must exceed a configurabl...

Page 140: ...uit breaker is therefore ensured even if the initiating signal pulse is very short This param eter can only be set in DIGSI at Display Additional Settings 2 10 3 Settings The table indicates region specific default settings Column C configuration indicates the corresponding sec ondary nominal current of the current transformer 2 10 4 Information List Addr Parameter C Setting Options Default Settin...

Page 141: ...losing arc has not disappeared there is a metallic fault then the pro tective elements will re trip the circuit breaker The 7SD80 can also be implemented with an external automatic reclosing device In this case the signal ex change between 7SD80 and the external reclosing device must be effected via binary inputs and outputs It is also possible to initiate the integrated auto reclose function by a...

Page 142: ...uring the dead time Also for reasons of selectivity see above faults that are usually cleared after a time delay should not lead to reclosing The automatic reclosing function of the 7SD80 can be operated with or without action times configuration pa rameter AR control mode address 134 see Section 2 1 1 2 No starting signal is necessary from the pro tection functions or external protection devices ...

Page 143: ...res the automatic reclosing function returns to its qui escent state and is ready for a new fault in the network If the circuit breaker is closed manually by the control discrepancy switch connected to a binary input the local control functions or via one of the serial interfaces the automatic reclosing is blocked for a manual close blocking time BLOCK MC Dur address 3404 If a trip command occurs ...

Page 144: ...y the protection If the fault is cleared successful reclosure the restraint time expires and all functions return to their quiescent state The fault is terminated If the fault has not been eliminated unsuccessful reclosure the short circuit protection initiates a final trip fol lowing a protection stage active without reclosure Any fault during the restraint time leads to a final trip After unsucc...

Page 145: ...MODE starts 3p AR The separately settable dead time for sequential faults starts with the clearance of the sequential fault after the dead time the circuit breaker receives a close command If reclosing is blocked due to an evolving fault without the protection device issuing a trip command e g in the case of evolving fault detection with pickup the device can send a trip command intertrip Intertri...

Page 146: ...y the trip command of the external protection see also above at Control Mode of the Automatic Reclosure The interaction is controlled via binary outputs and binary inputs 2889 79 1 CycZoneRel Internal automatic reclosure ready for the first reclose cycle i e releases the element of the external protection decisive for reclosure the corresponding output can be used for the second cycle This output ...

Page 147: ...IPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 147 Figure 2 57 Connection example with external protection device for fault detection dependent dead time dead time control by pickup signals of the protection device AR control mode with PICKUP ...

Page 148: ...er after a TRIP CLOSE TRIP cycle If the circuit breaker is not ready again by the time this timer expires no reclosure takes place the automatic reclosure function is blocked dynamically Waiting for the circuit breaker to be ready again can lead to an increase of the dead times To avoid uncon trolled prolongation it is possible to set a maximum prolongation of the dead time in this case in address...

Page 149: ...e position of the circuit breaker auxiliary contact or the disappearance of the trip command If a circuit breaker failure protection internal or external is used on the feeder this time should be shorter than the time delay of the circuit breaker failure protection so that no reclosure takes place if the circuit breaker fails Note To enable that the busbar is tripped by the breaker failure protect...

Page 150: ...or the 3 pole dead time after clearance of the evolving fault 1 AR DeadT EV address 3458 Stability aspects are also decisive here Normally the setting con straints are similar to address 3457 1 AR Dead 3Trip Under address 3459 1 AR 52 CLOSE it can be determined whether the readiness of the circuit breaker cir cuit breaker ready is interrogated before this first reclosure With the setting YES the d...

Page 151: ...nal protection functions can use this information to release accelerated or over reaching trip stages prior to the corresponding reclose cycle 79 is blocked No 2783 The automatic reclosure is blocked e g circuit breaker not ready This information indicates to the operational information system that in the event of an upcoming system fault there will be a final trip i e without reclosure If the aut...

Page 152: ... 0 00 300 00 sec 0 20 sec Send delay for remote close command 3411A Max DEAD EXT 0 50 300 00 sec sec Maximum dead time extension 3420 AR WITH DIFF YES NO YES AR with differential protection 3423 AR w INT TRIP YES NO YES AR with intertrip 3424 AR w DTT YES NO YES AR with DTT direct transfer trip 3425 AR w 50 N B YES NO YES AR with 50 N B backup overcur rent 3450 1 AR START YES NO YES Start of AR al...

Page 153: ...time after 2phase faults 3466 2 AR DeadT 3Flt 0 01 1800 00 sec 0 50 sec Dead time after 3phase faults 3468 2 AR Dead 3Trip 0 01 1800 00 sec 0 50 sec Dead time after 3pole trip 3469 2 AR DeadT EV 0 01 1800 00 sec 1 20 sec Dead time after evolving fault 3470 2 AR 52 CLOSE YES NO NO 52 ready interrogation before re closing Addr Parameter Setting Options Default Setting Comments ...

Page 154: ...closer is blocked 2784 79 not ready OUT 79 Auto recloser is not ready 2787 CB not ready OUT 79 Circuit breaker 1 not ready 2788 79 T CBreadyExp OUT 79 CB ready monitoring window expired 2796 79 on off BI IntSP 79 Auto recloser ON OFF via BI 2801 79 in progress OUT 79 in progress 2809 79 T Start Exp OUT 79 Start signal monitoring time expired 2810 79 TdeadMax Exp OUT 79 Maximum dead time expired 28...

Page 155: ...ble with the address 1150 SI Time Man Cl This setting can only be changed using DIGSI at Additional Settings The following figure shows the logic diagram Figure 2 58 Logic diagram of the manual CLOSE procedure Reclosing via the integrated local control or control using DIGSI can have the same effect as manual reclosure parameter 1152 Section 2 1 6 1 under margin heading Circuit Breaker Status If t...

Page 156: ...e manual CLOSE function via parameter 1152 Man Clos Imp Figure 2 58 Figure 2 60 Manual closing with external automatic reclosure device 52 Circuit breaker 52TC Circuit breaker trip coil 52 Aux Auxiliary contact of the circuit breaker Besides the manual CLOSE detection the device records any energization of the line via the integrated line energization detection This function processes a change of ...

Page 157: ...ndicator for line energization as such changes can neither occur during 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 indicates directly the position of the circuit breaker The detected energization is signaled through the indication Line closure no 590 Parameter 113...

Page 158: ...es connection of the poles auxiliary NC contacts is available the corresponding binary input is routed to 52b 3p Open no 380 The output signals of the circuit breaker position logic can be processed by the individual protection and sup plementary functions The output signals are blocked if the signals transmitted from the circuit breaker are not plausible for example the circuit breaker cannot be ...

Page 159: ...ies connection of the NC auxiliary contacts 2 12 3 Circuit Breaker Test The 7SD80 differential protection enables the trip circuits and circuit breakers to be tested conveniently For the test a 3 pole TRIP CLOSE cycle and the close command CB1 TEST close 7329 are performed via the test program The output indication CB1 TESTtripABC 7328 must be routed to the command relays used to control the circu...

Page 160: ...T CB1 TEST TRIP command ABC 7329 CB1 TEST close OUT CB1 TEST CLOSE command 7345 CB TEST running OUT CB TEST is in progress 7346 CB TSTstop FLT OUT_Ev CB TEST canceled due to Power Sys Fault 7347 CB TSTstop OPEN OUT_Ev CB TEST canceled due to CB already OPEN 7348 CB TSTstop NOTr OUT_Ev CB TEST canceled due to CB was NOT READY 7349 CB TSTstop CLOS OUT_Ev CB TEST canceled due to CB stayed CLOSED 7350...

Page 161: ...ion can be assigned via CFC to a transmission input and transmit ted to the remote end s The up to 16 binary inputs Rem Signal 1 to Rem Signal16 must be routed and are available ac cordingly at Rem Sig 1 Rx etc on the receiving side When allocating the binary inputs using DIGSI you can give the information items to be transmitted individual names The device indications e g Master Login can be used...

Page 162: ...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 3573 Rem Sig 1 Rx OUT Remote signal 1 received 3574 Rem Sig 2 Rx OUT Remote signal 2 received 3575 Rem Sig 3 Rx OUT Remote signal 3 received 3576 Rem Sig 4 Rx OUT Remote signal 4 received 3577 Rem Sig 5 Rx OUT Remote signal 5 rec...

Page 163: ... for nominal auxiliary voltage 110 V Buffer Battery The buffer battery which ensures operation of the internal clock and storage of counters and annunciations if the auxiliary voltage fails is periodically checked for its charge status If there is less than the allowed minimum voltage the annunciation Fail Battery is output Memory Components All working memories RAM are checked during system start...

Page 164: ...ing parameters The component Σ I FACTOR Σ I takes into account the permitted current proportional ratio errors of the input transducers which are particularly prevalent during large short circuit currents Figure 2 64 Σ I is the sum of all currents Σ I IA IB IC kI IE Once a summation current fault is detected outside the context of a system disturbance the differential protec tion is blocked This f...

Page 165: ...this limit is exceeded an indication is generated 191 Error Offset and integrated into the warning group indication 160 As increased offset values impair the measurements we recommend sending the device to the OEM plant for corrective action should this indication persist 2 14 1 3 External Transformer Circuits Interruptions or short circuits in the secondary circuits of the current and voltage tra...

Page 166: ...to the largest Imbalance is recognized if Vmin Vmax BAL FACTOR V as long as Vmax BALANCE V LIMIT Where Vmax being the largest of the 3 phase to phase voltages and Vmin the smallest The balance factor BAL FACTOR V address 2903 represents the permitted imbalance of the conductor voltages while the limit value BALANCE V LIMIT address 2902 is the lower limit of the operating range of this monitoring s...

Page 167: ...and the results of the broken wire monitoring supplied by the device at the other end of the protected object At each sampling moment the function checks whether there is a jump in one of the three phase currents if there is it generates the suspected wire break signal There is a suspected local wire break if a jump has been detected in the affected phase and the current has dropped to 0 A WARNING...

Page 168: ...f the protected object may have measured a phase current of more than 2 INom A phase current of such a magnitude is a certain indicator of a power system fault When a wire break has been detected according to the above criteria it is signaled via the protection data in terface to the device at the other end of the protected object and leads immediately to a wire break message The differential prot...

Page 169: ...71 is issued Rapid Measuring Voltage Failure Fuse Failure Monitor In the event of a measuring voltage failure due to a short circuit fault or a broken conductor in the voltage trans former secondary circuit certain measuring loops may mistakenly see a voltage of zero Simultaneously exist ing load currents may then cause spurious pickup If fuses are used instead of a secondary miniature circuit bre...

Page 170: ... sequence current are below the settable threshold FFM I max address 2912 In ungrounded systems address 207 SystemStarpoint the zero sequence voltage is no reliable criterion since a considerable zero sequence voltage occurs also in case of a simple ground fault where a significant zero sequence current does not necessarily flow Therefore the zero sequence voltage is not evaluated in such systems ...

Page 171: ...falling below a threshold value The signal VT FuseFail can also be generated indepen dently of the magnitude of the phase currents Figure 2 70 Fuse Failure Monitor part 2 detection of the 3 phase measuring voltage failure A 3 phase failure of the secondary measuring voltages can be distinguished from an actual system fault by the fact that the currents have no significant change in the event of a ...

Page 172: ...n Impact of the Measuring Voltage Failure Additional Measuring Voltage Failure Monitoring Fail V absent If no measuring voltage is available after power on of the device e g because the voltage transformers are not connected the absence of the voltage can be detected and reported by an additional monitoring function If the circuit breaker auxiliary contacts are used they should be used for monitor...

Page 173: ... protection is parameterized accordingly refer to Section 2 4 In the event of a measuring voltage failure due to a short circuit or a broken conductor in the voltage transformer secondary circuit individual or all measuring loops may mistakenly see a voltage of zero Simultaneously existing load currents may then cause spurious pickup When such a measuring voltage failure is detected those protecti...

Page 174: ...s taken out of operation After three unsuccessful restart attempts the device is also shut down The device ready relay drops out and indicates the device failure with its NC contact life status contact The red ERROR LED on the device front lights up provided that there is an internal auxiliary voltage and the green RUN LED goes off If the internal auxiliary voltage supply fails all LEDs are dark T...

Page 175: ...ues Internal EEPROM or RAM Indication Using default values Alarm adjustm 193 As routed Modules Module does not comply with order number MLFB Indications Protection out of operation Error Board 1 5 183 187 and if applicable Error A D conv 181 DOK2 drops out Current sum Internal measured value acquisition Indication Total blocking of the differ ential protection Failure Σi 289 As routed Current symm...

Page 176: ...isplay Additional Settings Summation Monitoring Address 2906 Σ I THRESHOLD determines the limit current above which the current sum monitor is activated absolute portion only relative to INom The relative portion relative to the maximum conductor current for ac tivating the current sum monitor is set at address 2907 Σ I FACTOR These settings can only be changed via DIGSI at Display Additional Sett...

Page 177: ...Additional Settings The table indicates region specific default settings Column C configuration indicates the corresponding sec ondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 2901 MEASURE SUPERV ON OFF ON Measurement Supervision 2902A BALANCE V LIMIT 10 100 V 50 V Voltage Threshold for Balance Monitoring 2903A BAL FACTOR V 0 58 0 95 0 75...

Page 178: ... Voltage absent 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 ...

Page 179: ...mplemented for each circuit breaker pole provided the required binary inputs are available 2 14 2 1 Method of Operation Monitoring with Two Binary Inputs When using two binary inputs these are connected according to Figure 2 73 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 super...

Page 180: ...is reported see Figure 2 74 The repeated measurements help to determine the delay of the alarm message and to avoid that an alarm is output during short time transition periods After the fault in the trip circuit is removed the alarm is reset automatically after the same time Figure 2 74 Logic diagram of the trip circuit monitoring with two binary inputs Monitoring with One Binary Input The binary...

Page 181: ...e circuit 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 faulted 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 monitor do...

Page 182: ...s 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 14 2 3 Settings 2 14 2 4 Information List Addr Parameter Setting Options Default Setting Comments 4001 FCT 74TC ON OFF OFF 74TC TRIP Circuit ...

Page 183: ...rotective Function ANSI No Mode of Operation Three phase Single phase Current I RMS value of fundamental com ponent Overcurrent protection Undercurrent monitoring 50 50G 37 X X Irms True RMS r m s value Overcurrent protection Thermal overload protec tion Undercurrent monitoring 50 50G 49 37 X X 3I0 Zero sequence system Time overcurrent protec tion ground 50N X I1 Positive sequence component X I2 N...

Page 184: ...ctive for currents below 0 03 IN Operating Mode Measured Quantity Measurement Method The flexible function can be tailored to assume a specific protective function for a concrete application in pa rameters OPERRAT MODE MEAS QUANTITY MEAS METHOD and PICKUP WITH Parameter OPERRAT MODE can be set to specify whether the function works 3 phase 1 phase or no reference i e without a fixed phase reference...

Page 185: ...ction of the threshold violation If the function is enabled the pickup will start the trip time delay and the fault log This is not the case if set to Alarm only If the threshold violation persists after the trip time delay has elapsed the trip will be initiated upon its expiration no 235 2126 00 TRIP The timeout is reported via no 235 2125 00 Time Out Expiry of the trip time delay can be blocked ...

Page 186: ...ondition will be reported immediately starting the trip time delay Other wise the logic is the same as depicted in Figure 2 77 Interaction with Other Functions The flexible protection functions interact with a number of other functions such as the Breaker failure protection The breaker failure protection is started automatically if the function initiates a trip The trip will however only take plac...

Page 187: ...ent protection Single phase functions evaluate only the individual measuring value This can be an individual phase value e g VB or a ground variable VN or IN Setting no reference determines the evaluation of measured variables irrespective of a single or three phase connection of current and voltage Table 2 6 provides an overview regarding which variables can be used in which mode of operation Mea...

Page 188: ...o phase voltage independently of parameter VOLTAGE SYSTEM Positive sequence system negative sequence system zero sequence system To implement certain applications the positive sequence system or the negative sequence system can be parameterized as measurement method Examples are I2 unbalanced load protection V2 voltage unbalance When selecting the zero sequence system additional zero current or ze...

Page 189: ...he function is used as monitoring function and not as pro tection function If the ratio of the positive sequence current to the negative sequence current I2 I1 is evalu ated the T PICKUP DELAY should at least be set to 20 ms Operating Method Measurand Notes 1 phase Current voltage Parameter MEAS METHOD Setting selection Fundamental component The fundamental component is evaluated harmonics are sup...

Page 190: ...tandard dropout ratio of protection functions is 0 95 default setting If the function is used as power protection a dropout ratio of at least 0 9 should be set The same applies to the utilization of the symmetrical components of current and volt age If the dropout ratio is decreased it would be sensible to test the pickup of the function regarding possible chatter The dropout difference of the fre...

Page 191: ...e 1 phase no reference 3 phase Mode of Operation 0 MEAS QUANTITY Please select Current Voltage P forward P reverse Q forward Q reverse Power factor Frequency df dt rising df dt falling Binary Input Please select Selection of Measured Quantity 0 MEAS METHOD Fundamental True RMS Positive seq Negative seq Zero sequence Ratio I2 I1 Fundamental Selection of Measurement Method 0 PICKUP WITH Exceeding Dr...

Page 192: ... THRESHOLD 1A 0 5 10000 0 W 200 0 W Pickup Threshold 5A 2 5 50000 0 W 1000 0 W 0 P U THRESHOLD 0 99 0 99 0 50 Pickup Threshold 0 P U THRESHOLD 15 100 20 Pickup Threshold 0 T TRIP DELAY 0 00 3600 00 sec 1 00 sec Trip Time Delay 0 T PICKUP DELAY 0 00 60 00 sec 0 00 sec Pickup Time Delay 0 T PICKUP DELAY 0 00 60 00 sec 0 00 sec Pickup Time Delay 0A T DROPOUT DELAY 0 00 60 00 sec 0 00 sec Dropout Time...

Page 193: ...ripA SP Function 00 BLOCK TRIP Phase A 235 2116 00 BL TripB SP Function 00 BLOCK TRIP Phase B 235 2117 00 BL TripC SP Function 00 BLOCK TRIP Phase C 235 2118 00 BLOCKED OUT Function 00 is BLOCKED 235 2119 00 OFF OUT Function 00 is switched OFF 235 2120 00 ACTIVE OUT Function 00 is ACTIVE 235 2121 00 picked up OUT Function 00 picked up 235 2122 00 pickup A OUT Function 00 Pickup Phase A 235 2123 00...

Page 194: ... series of internal and external functions that occur subsequently The following internal functions are controlled by general device pickup Opening of fault case From general device pickup to general device drop out all fault messages are entered in the trip log Initialization of fault storage The storage and maintenance of fault values can also be made dependent on the occurrence of a trip comman...

Page 195: ... A further condition for terminating the trip command is that the circuit breaker is recognized to be open The function control of the device checks this condition by means of the circuit breaker position feedback Section Detection of the Circuit Breaker Position and the flow of current In address 1130 the residual current PoleOpenCurrent is set which is certainly undershot when the circuit breake...

Page 196: ...automatic reclosure is applied only the final trip of the protection function should activate reclosing lock out Please bear in mind that the message Definitive TRIP No 536 applies only for 500 ms Then combine the output alarm Definitive TRIP No 536 with the interlocking input Lockout SET so that the interlocking function is not established when an automatic reclosure is still expected to come The...

Page 197: ...e Appendix Prior to the command with the internal automatic reclosure in the ready state the contact opens so that no signal from the circuit breaker is forwarded This is only the case if the device is equipped with internal auto matic reclosure and if the latter was considered when configuring the protection functions address 133 Also when closing the breaker via the binary input Manual Close No ...

Page 198: ... E50417 G1140 C474 A1 Release date 09 2011 198 Figure 2 81 shows time diagrams for manual trip and close as well as for short circuit tripping with a single failed automatic reclosure cycle Figure 2 81 Breaker tripping alarm suppression sequence examples ...

Page 199: ...red differently from the delivery condition The Appendix of this manual deals in detail with the delivery condition and the al location options The output relays and LEDs may be operated in a latched or unlatched mode each may be set individually The latched conditions are protected against loss of the auxiliary voltage They are reset locally by pressing the LED key on the relay remotely using a b...

Page 200: ...he appendix All functions are associated with an information number FNo There is also an indication of where each message can be sent to If functions are not present in a not fully equipped version of the device or are configured to Disabled then the associated indications cannot appear Operational Messages Buffer Event Log The operational messages contain information that the device generates dur...

Page 201: ...dications can be recorded Oldest data are erased for newest data when the buffer is full General Interrogation The general interrogation which can be retrieved via DIGSI enables the current status of the SIPROTEC 4 device to be read out All messages requiring general interrogation are displayed with their present value Spontaneous Messages The spontaneous messages displayed using DIGSI reflect the...

Page 202: ...gisters the value of each current phase that was switched off in each pole This information is then provided in the trip log and summated in a register The maximum current that was switched off is also stored Measured values are indicated in primary values Transmission Statistics In 7SD80 the protection communication is registered in statistics The runtimes of the information between the devices v...

Page 203: ...s calculated from the connected phase to ground voltages 3V0 VA VB VC The two devices connected via the protection interface s form a joint frequency value constellation frequen cy 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 is also used by the d...

Page 204: ... operational voltage 2 VA N VB N VC N Phase to ground voltage kV V Rated operational voltage 3 2 3V0 Displacement voltage kV V Rated operational voltage 3 2 ϕ VA VB ϕ VB VC ϕ VC VA Phase angle of the phase voltages towards each other ϕ VA IA ϕ VB IB ϕ VC IC Phase angle of the phase voltages towards the phase currents V1 V2 Positive and negative sequence com ponent of the voltages kV V Rated operat...

Page 205: ...Vc a 627 VN MV VN 631 3V0 MV 3V0 zero sequence 634 V1 MV V1 positive sequence 635 V2 MV V2 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 684 Vo MV Vo zero sequence 801 Θ Θtrip MV Temperat rise for warning and trip 802 Θ Θtrip A MV Temperature rise for phase A 803 Θ Θtrip B MV Temperature rise for phase B 8...

Page 206: ...computation of this measured values constellation is also executed during an existent system fault in an interval of approx 0 5 s The current voltage measured locally is assumed as reference value for the angle The angle values of the remote ends are referred to the locally measured value Examples for the current in a constellation with 2 ends Current IA at the local end 98 angle 0 Current IA at t...

Page 207: ...a preset point of time 2 17 6 2 Setting Notes Minimum and Maximum Values The minimum and maximum values can be reset automatically at a programmable point in time This feature can be activated by setting address 2811 MinMax cycRESET to YES At address 2812 MiMa RESET TIME you can define the point of time when resetting takes place minute of the day Address 2813 MiMa RESETCYCLE allows you to define ...

Page 208: ...set SP S MIN MAX Buffer Reset 402 Q MiMa Reset SP Q MIN MAX Buffer Reset 403 Idmd MiMaReset SP Idmd MIN MAX Buffer Reset 404 Pdmd MiMaReset SP Pdmd MIN MAX Buffer Reset 405 Qdmd MiMaReset SP Qdmd MIN MAX Buffer Reset 406 Sdmd MiMaReset SP Sdmd MIN MAX Buffer Reset 407 Frq MiMa Reset SP Frq MIN MAX Buffer Reset 408 PF MiMaReset SP Power Factor MIN MAX Buffer Reset 837 IAdmdMin MVT I A Demand Minimu...

Page 209: ...min MVT Apparent Power Minimum 881 Smax MVT Apparent Power Maximum 882 fmin MVT Frequency Minimum 883 fmax MVT Frequency Maximum 1040 Pmin Forw MVT Active Power Minimum Forward 1041 Pmax Forw MVT Active Power Maximum Forward 1042 Pmin Rev MVT Active Power Minimum Reverse 1043 Pmax Rev MVT Active Power Maximum Reverse 1044 Qmin Forw MVT Reactive Power Minimum Forward 1045 Qmax Forw MVT Reactive Pow...

Page 210: ...ber specifies the averaging time window in minutes while the second number gives the frequency of updates within the time window 15 Min 3 Subs for example means Averaging over time for all measured values that arrive within a time window of 15 minutes The output is updated every 15 3 5 minutes Address 2802 DMD Sync Time allows you to specify whether the time period of averaging selected at address...

Page 211: ...I1 positive sequence Demand 834 P dmd MV Active Power Demand 835 Q dmd MV Reactive Power Demand 836 S dmd MV Apparent Power Demand 963 Ia dmd MV I A demand 964 Ib dmd MV I B demand 965 Ic dmd MV I C demand 1052 Pdmd Forw MV Active Power Demand Forward 1053 Pdmd Rev MV Active Power Demand Reverse 1054 Qdmd Forw MV Reactive Power Demand Forward 1055 Qdmd Rev MV Reactive Power Demand Reverse ...

Page 212: ...o change the default settings of the limit values under Properties The settings for limit values must be in percent and usually refer to nominal values of the device For more details see the SIPROTEC 4 System Description and the DIGSI CFC Manual 2 17 8 2 Information List No Information Type of In formation Comments I Admd LV I A dmd I Bdmd LV I B dmd I Cdmd LV I C dmd I1dmd LV I1dmd Pdmd LV Pdmd Q...

Page 213: ...ent transformers normally protection core and the device tolerances The me tering 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 13 Operational metered values 2 17 9 2 Setting Notes Retrieving Parameters The SIPROTEC 4 System Description describes in detail how to read out the statistical counters vi...

Page 214: ...control equipment Prerequisites The number of switchgear devices to be controlled is limited by the existing binary inputs existing binary outputs 2 18 1 1 Description Operation Using the Device s Operator Panel For controlling the device there are two independent colored keys located below the graphic display If you are somewhere in the menu system outside the control submenu you can return to th...

Page 215: ...2 Breaker 52Breaker DP 52 Breaker Disc Swit CF_D2 Disconnect Switch Disc Swit DP Disconnect Switch GndSwit CF_D2 Ground Switch GndSwit DP Ground Switch 52 Open IntSP Interlocking 52 Open 52 Close IntSP Interlocking 52 Close Disc Open IntSP Interlocking Disconnect switch Open Disc Close IntSP Interlocking Disconnect switch Close GndSw Open IntSP Interlocking Ground switch Open GndSw Cl IntSP Interl...

Page 216: ...outputs They serve to initiate internal functions simulate changes of state or to acknowledge changes of state Manual overriding commands to manually update information on process dependent objects such as an nunciations and switching states e g if the communication with the process is interrupted Manually over ridden objects are flagged as such in the information status and can be displayed accor...

Page 217: ...SCADA system or substation controller Double Operation interlocking against parallel switching operation Protection Blocking blocking of switching operations by protective functions Fixed Command Checks Internal Process Time software watch dog which checks the time for processing the control action between initiation of the control and final close of the relay contact Setting Modification in Proce...

Page 218: ...rlocked 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 Deactivated interlock switching means the configured interlocking conditions are not checked in the relay Interlocked switching means that all configured interlocking co...

Page 219: ...d with interlocked switches as soon as one of the protection functions of the unit has opened a fault case The OPEN command by contrast can always be executed Please be aware activation of thermal overload protection elements or sensitive ground fault de tection can create and maintain a fault condition status and can therefore block CLOSE commands If the interlocking is removed consider that on t...

Page 220: ...Functions 2 18 Breaker Control SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 220 Figure 2 84 Standard interlockings ...

Page 221: ...ters explained in the following table Table 2 14 Command types and corresponding messages The following figure shows all interlocking conditions which usually appear in the display of the device for three switchgear items with the relevant abbreviations explained in the previous table All parameterized inter locking conditions are indicated Figure 2 86 Example of configured interlocking conditions...

Page 222: ...ing by protection CLOSE commands are rejected with interlocked switches as soon as one of the pro tection functions of the device has opened a fault case OPEN commands in contrast can always be exe cuted Please be aware that pickup of overload protection elements can also open and maintain a fault and can therefore block CLOSE commands Double Operation Block Parallel switching operations are inter...

Page 223: ...Functions 2 18 Breaker Control SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 223 Figure 2 87 Standard interlockings ...

Page 224: ...y They are marked by letters explained in the following table Table 2 15 Command types and corresponding messages Control Logic using CFC For the bay interlocking a control logic can be structured via the CFC Via specific release conditions the infor mation released or bay interlocked are available e g object 52 Close and 52 Open with the data values ON OFF Interlocking Commands Abbrev Display Swi...

Page 225: ...e current status set in the objects Switching authority and Switching authority DIGSI Configuration Table 2 16 Interlocking logic 1 also Enabled for Switching Authority LOCAL check for LOCAL status n 2 also Enabled for Switching authority REMOTE check for LOCAL REMOTE or DIGSI commands n 3 CS command source CS Auto Commands that are initiated internally command processing in the CFC are not subjec...

Page 226: ...predetermined switchgear posi tion conditions are satisfied to prevent switching errors e g disconnector vs ground switch ground switch only if no voltage applied as well as verification of the state of other mechanical interlocking in the switchgear bay e g High Voltage compartment doors Interlocking conditions can be programmed separately for each switching device for device control CLOSE and or...

Page 227: ...and will be refused with the operating message set condition equals actual condition If the circuit breaker switchgear device is in the intermediate position then this check is not performed Bypassing Interlockings Bypassing configured interlockings at the time of the switching action happens device internal via interlocking recognition in the command job or globally via so called switching modes ...

Page 228: ...indication as it is done with the local command but by ordinary command and feedback information recording Monitoring of Feedback Information The processing of commands monitors the command execution and timing of feedback information for all com mands At the same time the command is sent the monitoring time is started monitoring of the command ex ecution This time controls whether the device achi...

Page 229: ...a size of 30 lines The 7SD80 uses the outputs of the graphical display but with 6 lines Therefore the representation might differ from the representations in the System Description The basic differences of the device with regard to the representation are the following The current selection is indicated by inverse representation not by the prefix Pushbutton Function meaning Confirming entries and n...

Page 230: ... Manual E50417 G1140 C474 A1 Release date 09 2011 230 Figure 2 89 Inverse representation of the current selection In part the sixth line is used for representing e g the active parameter group Figure 2 90 Representation of the active parameter group line 6 ...

Page 231: ... protection and control systems with power systems management and with the relevant safety rules and guidelines Under certain circumstances it may become necessary to adapt parts of the power system hard ware Some of the primary tests require the protected line or equipment to carry load 3 1 Mounting and Connections 232 3 2 Checking Connections 252 3 3 Commissioning 258 3 4 Final Preparation of th...

Page 232: ...n Appendix A 3 It must be checked that the setting of the P System Data 1 Subsection 2 1 3 1 was made in accordance with the device connections Currents In Appendix A 3 examples for the possibilities of the current transformer connections in dependence on network conditions are displayed For normal connection address 220 I4 transformer In prot line must be set and furthermore address 221 I4 Iph CT...

Page 233: ...s 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 following Table shows the relationship between binary inputs and the setting groups A to D Principal con nection diagrams for the two binary inputs are illustrated in the following Figure 3 1 ...

Page 234: ...nected in series with the second circuit breaker auxiliary contact Aux2 to also allow the detection of a trip circuit failure when the circuit breaker auxiliary contact 1 Aux1 is open and the command relay contact has reset The value of this resistor must be such that in the circuit breaker open condition therefore Aux1 is open and Aux2 is closed the circuit breaker trip coil TC is no longer picke...

Page 235: ...result Rmax Rmin the calculation has to be repeated with the next smaller threshold VBI min This threshold is determined via the parameters 260 Threshold BI 1 to 266 Threshold BI 7 The settings Thresh BI 176V Thresh BI 88V Thresh BI 19V are possible For the power consumption of the resistance IBI HIGH Constant current with activated BI 0 25 mA VBI min Minimum control voltage for BI 19 V at deliver...

Page 236: ...e 200 kΩ is selected the following applies for the power IBI HIGH 0 25 mA SIPROTEC 4 7SD80 VBI min 19 V at delivery setting for nominal voltages of 24 V 48 V 88 V at delivery setting for nominal voltages of 60 V 110 V 125 V 220 V 250 V VCTR 110 V from the system trip circuit RCBTC 500 Ω from the system trip circuit VCBTC LOW 2 V from the system trip circuit ...

Page 237: ...wide blade a Philips screwdriver size 1 a 5 mm 0 20 in socket or nut driver In order to disassemble the device first remove it from the substation installation To do so perform the steps stated in Sections Panel Flush Mounting Panel Surface Mounting or Cubicle Mounting in reverse order Note The following must absolutely be observed Disconnect the communication connections at the device bottom port...

Page 238: ...using screw so far that its tip no longer looks out of the thread of the mounting bracket the housing screws are captive they remain in the front cover even when unscrewed Unscrew all screws that fasten any existing communication modules in the module cover on the bottom side of the device Also unscrew the 4 countersunk screws that fasten the module cover on the bottom side of the device Carefully...

Page 239: ...Mounting and Commissioning 3 1 Mounting and Connections SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 239 Figure 3 3 Electronic block without housing ...

Page 240: ...chnical data into the fuse holder 5 mm x 20 mm 0 20 0 79 in safety fuse T characteristic 2 0 A nominal current 250 V nominal voltage Switching capacity 1500 A 300 VDC Only UL approved fuses may be used This data applies to all device types 24 V 48 V and 60 V 250 V Make sure that the defective fuse has not left any obvious damage on the device If the fuse trips again after reconnection of the devic...

Page 241: ...a crosstip screwdriver PZ2 We recommend PZ2 Cable Lugs and Wire Cross sections There are two connection options the connection of single wires and the connection with a ring lug Only copper wires may be used We recommend ring lugs with the following dimensions Figure 3 5 Ring lug For complying with the required insulation clearances insulated ring lugs have to be used Otherwise the crimp zone has ...

Page 242: ...owed When connecting single wires the following cross sections are allowed Mechanical Requirements The fixing elements and the connected components are designed for the following mechanical requirements Cable cross section AWG 14 10 2 0 mm2 to 5 2 mm2 Connector sleeve with plastic collar L 10 mm 0 39 in or L 12 mm 0 47 in Stripping length when used without conductor sleeve 15 mm 0 59 in Use exclus...

Page 243: ...ng twin cable end sleeves when connecting two single cables We recommend the twin cable end sleeves of the series PN 966 144 from Tyco Electronics When connecting single cables the following cross sections are allowed With terminal points lying one below the other you may connect single conductors and jumpers Order No C53207 A406 D194 1 together Please make sure that neighboring jumpers are built ...

Page 244: ...ster on the primary side Therefore checking the insulation at terminals D1 and D2 is not possible at a later time Component testing is performed with AC 70 V For type tests without protective circuit voltage immunity is tested with AC 1 9 kV Installation or Replacement of a SIPROTEC 4 Communication Module The following description assumes the normal case that a SIPROTEC 4 communication module whic...

Page 245: ...g and Commissioning 3 1 Mounting and Connections SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 245 Figure 3 7 Dismounting the FO protection data interface Figure 3 8 7SD80 device with adapter ...

Page 246: ...upporting plate Thus even the longest connection elements of the communication module can be moved in this space between the lower supporting plate reinforcement and the locking latch in the direction of the transformer module The mounting bracket of the module is now drawn up to the stop in the direction of the lower supporting plate rein forcement Thus the 60 pin plug connector on the module and...

Page 247: ...ronics block into the housing until the supporting part rests against the front edge of the hous ing Press the left housing wall slightly out and insert the electronics block carefully further into the housing When the front edge of the housing and the inside of the front plate touch center the front plate by careful lateral movements This makes sure that the front plate encloses surrounds the hou...

Page 248: ...474 A1 Release date 09 2011 248 3 1 3 Installation 3 1 3 1 General The 7SD80 relay has a housing size 1 6 The housing has 2 covers and 4 fixing holes each at the top and bottom see Figure 3 10 and Figure 3 11 Figure 3 10 Housing with covers Figure 3 11 Housing with fixing holes without covers ...

Page 249: ...ational ground to the grounding terminal of the device The cross section of the cable used must correspond to the maximum connected cross section but must be at least 2 5 mm2 Connections are to be established via the screw terminals on the rear panel of the device in accordance with the circuit diagram The details on the connection technique for the communication modules at the bottom of the devic...

Page 250: ... correspond to the maximum connected cross section but must be at least 2 5 mm2 Connections are to be established via the screw terminals at the rear panel of the device in accordance with the circuit diagram The details on the connection technique for the communication modules on the bottom of the device port A and port B in accordance with the SIPROTEC 4 System Description and the details on the...

Page 251: ... operational ground to the grounding terminal of the device The cross section of the cable used must correspond to the maximum connected cross section but must be at least 2 5 mm2 Connections are to be established via the screw terminals at the rear panel of the device in accordance with the circuit diagram The details on the connection technique for the communication modules on the bottom of the ...

Page 252: ...king the Data Connections of the Interfaces Pin Assignment The following tables show the pin assignment of the various interfaces The position of the connections can be seen in the following figures Figure 3 15 USB interface Figure 3 16 Ethernet connections at the device bottom side Figure 3 17 FO protection data interface at the device bottom side port A ...

Page 253: ...icrosoft Windows USB driver is used which is installed together with DIGSI as of version V4 82 The interface is installed as a virtual serial COM port We recommend the use of standard USB cables with a maximum length of 5 m 16 ft Table 3 2 Assignment of the USB socket Connections at Port A Protection data interface optical fiber cable with LC duplex connector The order numbers of the exchange modu...

Page 254: ...O 2110 TxD Data output RxD Data input RTS Request to send CTS Clear to send GND Signal Chassis Ground The cable shield is to be grounded at both ends For extremely EMC prone environments the GND may be connected via a separate individually shielded wire pair to improve immunity to interference Pin No RS232 RS232 time syn chroniza tion 2 RS485 Profibus DP RS485 Modbus RS485 DNP3 0 RS485 Ethernet EN...

Page 255: ...tion data communication usually goes directly from device to device either via electrical connection or optical fiber Optical Fibers Directly WARNING Warning of laser rays Non observance of the following measure can result in death personal injury or substantial property damage Do not look directly into the fiber optic elements not even with optical devices Laser Class 3A according to EN 60825 1 T...

Page 256: ...Are the current transformers grounded properly Are the polarities of the current transformer connections the same Is the phase relationship of the current transformers correct Are the voltage transformers grounded properly Are the polarities of the voltage transformers correct Is the phase relationship of the voltage transformer connections correct Is the polarity for current input I4 correct if u...

Page 257: ...ly Check the trip and close circuits to the power system circuit breakers Verify that the control wiring to and from other devices is correct Check the signaling connections Switch the mcb back on Screw terminals for connection modules The connection module is available in 8 pin design for current connections and in 14 pin design for voltage con nections Figure 3 20 Current and voltage terminals ...

Page 258: ...s given in Technical Data Chapter 4 must not be exceeded neither during testing nor during commissioning When testing the device with secondary test equipment make sure that no other measurement quantities are connected and that the trip and close circuits to the circuit breakers and other primary switches are disconnect ed from the device DANGER Hazardous voltages during interruptions in secondar...

Page 259: ... in detail how to activate and deactivate the test mode and blocked data transmission Please note that when DIGSI is being used for device editing the program must be in the online operating mode for the test features to be used 3 3 2 Checking Time Synchronization If external time synchronization sources are used the data of the time source antenna system time generator are checked see Subsection ...

Page 260: ...during real operation by transmitting or receiving messages via the system interface Note After termination of the system interface 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 DIGSI in the Online operating mode Open the Online directory by double clicking t...

Page 261: ... system As long as the window is open further tests can be performed Test in Message Direction For all information that is transmitted to the central station test the options in the list which appears in SET POINT Status Make sure that each checking process is carried out carefully without causing any danger see above and refer to DANGER Click on Send in the function to be tested and check whether...

Page 262: ...e protection device to be able to access the new communication module a change has to be made in the parameter set in DIGSI Manager In DIGSI 4 Manager select the SIPROTEC device in your project and select the menu item Edit Object properties to open the Properties SIPROTEC 4 Device dialog box see following Figure In the Communication Modules tab select an interface for the 11 Port B bottom side of...

Page 263: ...ssignment for a SIPROTEC device has been changed this is usually connected with a change of the allocations of the SIPROTEC objects to the system interface After having selected a new mapping file please check the allocations to Target system interface or Source system interface in the DIGSI allocation matrix Edit Field Module Specific Settings In the edit field Module specific settings only chang...

Page 264: ...g 3 3 Commissioning SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 264 Figure 3 24 Module specific settings Then transfer the data to the protection device see the following figure Figure 3 25 Transmitting data ...

Page 265: ...ntrolled in DIGSI This feature is used to verify control wiring from the device to plant equipment operational checks during commissioning This test option should however definitely not be used while the device is in real oper ation DANGER Danger evolving from operating the equipment e g circuit breakers disconnectors by means of the test function Non observance of the following measure will resul...

Page 266: ...of the binary inputs and outputs are indicated by an open or closed switch symbol the LEDs by a dark or illuminated LED symbol The opposite state of each element is displayed in the column Scheduled The display is made in plain text The right most column indicates the commands or messages that are configured masked to the hardware components Figure 3 26 Test of the binary inputs outputs example Ch...

Page 267: ...t required Proceed as follows in order to check the binary inputs Activate each of function in the system which causes a binary input to pick up Check the reaction in the Status column of the dialog box To do so the dialog box must be updated The options may be found below under the margin heading Updating the Display Finish the testing see margin heading below Exiting the Test Mode If however the...

Page 268: ...d by the plant settings 3 3 6 Checking the Protection Data Communication General You can check the device communication from the PC using DIGSI You can either connect the PC directly to the device on site using the front operator interface or the service interface port B of the PC Figure 3 27 Or you can log into the device using a modem via the service interface example in Figure 3 29 Figure 3 27 ...

Page 269: ...In case of an incorrect communication link the indication PDI FO faulty no 3230 or PDI Cu faulty no 3232 is displayed In this case check the connection again Are the connections correct and not swapped Are the cables free from mechanical damage intact and the connectors locked Otherwise repeat the verification Continue with the margin heading Consistency of Connection and Parameterization Consiste...

Page 270: ...make a detailed description of the necessary tests It is important to observe local conditions and protection and system drawings Before starting the circuit breaker tests it is recommended to isolate the circuit breaker of the tested feeder at both ends i e line isolators and busbar isolators should be open so that the breaker can be operated without risk Caution Also for tests on the local circu...

Page 271: ...e of breaker failures it is important to check that the trip commands to the adjacent circuit breakers are correct The adjacent circuit breakers are those of all feeders which must be tripped in order to ensure interruption of the fault current should the local breaker fail These are therefore the circuit breakers of all feeders which feed the busbar or busbar section to which the feeder with the ...

Page 272: ...under margin heading Symmetry Monitoring The voltages can be read as primary and secondary values on the display at the front or called up in the PC via the operator or service interface and compared with the actual measured quantities Besides the magnitudes of the phase to ground and the phase to phase voltages the phase differences of the voltages are also displayed so that the correct phase seq...

Page 273: ...ching factors see Section 2 1 3 at margin heading Con nection of the Currents At the indication of balance monitoring there might actually be asymmetries of the primary system If they are part of normal operation the corresponding monitoring function is set less sensitive see Section 2 14 1 under margin heading Symmetry Monitoring The currents can be read as primary and secondary values on the dis...

Page 274: ...e if active power flows into the protected object P negative if active power flows towards the busbar Q positive if inductive reactive power flows into the protected object Q negative if reactive power flows toward the busbar Therefore the power results and their components must have opposite signs at both ends It must be taken into consideration that high charging currents which might occur with ...

Page 275: ...rmed 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 have opposite signs at both ends i e they are turned by 180 The protected object is now switched off i e the circuit breakers are opene...

Page 276: ... measured quantities as primary or secondary values The absolute values as well as the phase differences of the voltages are indicated so that the correct phase sequence and polarity of individual transformers can also be seen The same manipulation is carried out with the current and voltage transformers at the other end Figure 3 31 Polarity check for I4 Example for a current transformer set in Ho...

Page 277: ...nitiation 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 does not need to be checked again here Otherwise the initiating event is simulated and the response of the circuit breaker at the opposite line end is verified For remote transmission the external command input is employed on the receiving line e...

Page 278: ...also Section 2 12 Furthermore the ready state of the circuit breaker for the CB test must be indicated to the binary input with FNo 371 3 3 13 Switching Check for the Configured Equipment Switching via Command Input If the configured equipment was not switched sufficiently in the hardware test already described configured equipment must be switched on and off from the device via the integrated con...

Page 279: ...e e g via the binary input on switch on of the protection object An oscillographic recording that is externally triggered that is without a protective element pickup or device trip is processed by the device as a normal oscillographic recording and has a number for establishing a se quence However these recordings are not displayed in the fault indication buffer as they are not fault events Start ...

Page 280: ...rmation on this 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 counters in the switching statistics should be reset to the values that were existing prior to the testing see also SIPROTEC 4 System Description The counters of the operational measured values e g operation counter if availab...

Page 281: ... 4 4 Ground Fault Differential Protection in Grounded Systems 299 4 5 Ground Fault Differential Protection in Resonant grounded Isolated Systems 300 4 6 Breaker Intertrip and Remote Tripping Direct Local Trip 301 4 7 Time Overcurrent Protection 302 4 8 Inrush Current Restraint Breaker Intertrip and Remote Tripping 309 4 9 Circuit Breaker Failure Protection Optional 310 4 10 Thermal Overload Protec...

Page 282: ...ar range 1 Burden per phase and ground path at INom 1 A at INom 5 A for sensitive ground fault detection at 1 A 0 05 VA 0 3 VA 0 05 VA Load capacity current path thermal rms dynamic peak value 500 A for 1 s 150 A for 10 s 20 A continuous 1250 A half cycle Load capacity input for sensitive ground fault detection INs 1 thermal rms dynamic peak value 300 A for 1 s 100 A for 10 s 15 A continuous 750 A...

Page 283: ... category IEC 60255 27 III AC ripple voltage peak to peak IEC 60255 11 15 of auxiliary voltage Power input Quiescent Energized 7SD80 approx 5 W approx 12 W Bridging time for failure short circuit IEC 60255 11 50 ms at V 110 V 10 ms at V 110 V Voltage supply via an integrated converter Nominal auxiliary AC voltage VH AC 115 V AC 230 V Permissible voltage ranges AC 92 V to 132 V AC 184 V to 265 V Ov...

Page 284: ...ated voltages DC 110 V to 250 V V high DC 88 V V low DC 44 V For rated voltages DC 220 V and 250 V V high DC 176 V V low DC 88 V Maximum admissible voltage 300 V DC Input interference suppression 220 V induced above 220nF at a recovery time between two switching operations 60 ms Signal command relay alarm relay Quantity and data depending on the order variant configurable Order variant NO contact ...

Page 285: ...nization Connection Back case bottom mounting location B 9 pin DSUB socket Test voltage 500 V 50 Hz Transmission speed min 1 200 Bd max 115 000 Bd factory setting 9 600 Bd Bridgeable distance 16 40 yd RS485 Connection Back case bottom mounting location B 9 pin DSUB socket Test voltage 500 V 50 Hz Transmission speed min 1 200 Bd max 115 000 Bd factory setting 9 600 Bd Bridgeable distance Max 0 62 m...

Page 286: ...nection Back case bottom mounting location B Transmission speed Up to 1 5 MBd Recommended 500 kBd with normal casing Optical wavelength λ 820 nm Laser Class 1 according to EN 60825 1 2 When using glass fiber 50 125 μm or glass fiber 62 5 125 µm Permissible optical signal at tenuation max 8 dB with glass fiber 62 5 125 µm Bridgeable distance Max 0 93 miles DNP3 0 MODBUS RS485 Connection Back case b...

Page 287: ...ation B 2 x RJ45 socket 100BaseT in acc with IEEE802 3 Test voltage with regard to the socket 500 V 50 Hz Transmission speed 100 Mbit s Bridgeable distance 21 87 yd Ethernet electrical EN 100 for IEC61850 and DIGSI Connection Back case bottom mounting location B LC connector 100BaseF in acc with IEEE802 3 Transmission speed 100 Mbit s Optical wavelength 1300 nm Bridgeable distance Max 1 24 miles ...

Page 288: ...tage test routine test isolated communi cation interfaces A and B 500 V 50 Hz Voltage test routine test CU protection data inter face 1 DC 70 V Impulse voltage test type test all processor cir cuits against each other and against the grounding terminal except communication interface and CU protection data interface category III 5 kV peak value 1 2 µs 50 µs 0 5 J 3 positive and 3 negative impulses ...

Page 289: ...s installation class III IEC 60255 22 5 IEC 61000 4 5 Impulse 1 2 µs 50 µs Auxiliary voltage Common mode 4 kV 12 Ω 9 µF Diff mode 1 kV 2 Ω 18 µF Measuring inputs and relay outputs Common mode 4 kV 42 Ω 0 5 µF Diff mode 1 kV 42 Ω 0 5 µF Binary inputs Common mode 4 kV 42 Ω 0 5 µF Diff mode 1 kV 42 Ω gas filled tube CU protection interface unscreened a and b Common mode 4 kV 42 Ω gas filled tube CU p...

Page 290: ...xis Frequency sweep 1 octave min 1 cycle in 3 orthogonal axes Standards IEC 60255 21 and IEC 60068 Oscillation IEC 60255 21 1 Class 2 IEC 60068 2 6 Sinusoidal 5 Hz to 8 Hz 7 5 mm amplitude 8 Hz to 150 Hz 2 g acceleration Frequency sweep 1 octave min 20 cycles in 3 orthogonal axes Shock IEC 60255 21 2 Class 1 IEC 60068 2 27 Semi sinusoidal 15 g acceleration duration 11 ms each 3 shocks in both dire...

Page 291: ...as a rule be equipped with suitable surge suppression components For substations with operating voltages of 100 kV and above all external cables should be shielded with a conductive shield grounded at both ends For substations with lower operating voltages no special mea sures are normally required Do not withdraw or insert individual modules or boards while the protective device is energized In w...

Page 292: ...ned technician Replace Battery with VARTA or Panasonic Cat Nos CR 1 2 AA or BR 1 2 AA only Use of another Battery may present a risk of fire or explosion See manual for safety instructions Caution The battery used in this device may present a fire or chemical burn hazard if mistreated Do not recharge disassemble heat above 100 C 212 F or inciner ate Dispose of used battery promptly Keep away from ...

Page 293: ...minal D1 and D2 Connection modules for protection data interface depending on the order variant Optical protection data interface Maximum distance monomode fiber 14 91 miles Maximum distance multimode fiber1 2 49 miles Protocol Full duplex Connector type Duplex LC connector SFF IEC 61754 20 standard Maximum baudrate 512 kbit s Transmission rate min 15 dBmavg max 8 dBmavg Receiver sensitivity maxim...

Page 294: ...ere are examples The actually possible range depends on the properties of the cable the number of joints and splices Electrical protection data interface Maximum distance 16 km 9 94 miles for AWG 19 0 65 mm2 Maximum transmission rate 128 kbit s Telecommunication cable or communication cable twin wire e g A 2Y L 2Y cable Cable attenuation 40 dB for 80 kHz Ranges determined during tests 1 Mode Trans...

Page 295: ...igher this value the better Attenuation D the smaller this value the better 01 and 02 12 db 40 dB 03 and 04 6 db 40 dB 05 and 06 6 db 30 dB the signal noise ratio and the attenuation are operational measured values It can be possible to select several modes for a cable Due the smaller disturbance sensitivity modes 01 and 03 are rec ommended We recommend the following for the lines listed here as e...

Page 296: ... 00 A Increments 0 01 A INom 5 A 2 50 A to 20 00 A The operating times depend on the communication speed The following data require a transmission rate of 512 kbit s Pickup time with infeed at both ends approx 15 ms to 40 ms Pickup times with infeed at both ends approx 35 ms to 40 ms Command time approx 15 ms to 90 ms Start time at 50 Hz approx 51 ms Frequency range 45 Hz to 55 Hz at 50 Hz 55 Hz t...

Page 297: ...echnical Data 4 3 87 Differential Protection Phase Comparison Protection SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 297 Pickup Characteristic Figure 4 1 Dynamic pickup characteristic ...

Page 298: ...Technical Data 4 3 87 Differential Protection Phase Comparison Protection SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 298 Figure 4 2 Static pickup characteristic ...

Page 299: ...35 ms typical 37 ms maximum 40 ms Dropout times of the I87N L I DIFF element approx minimum 30 ms typical 32 ms maximum 34 ms Differential current 5 of setting value or 1 INom Delay of the 87N L I DIFF element approx 1 of setting value or 10 ms Frequency range 45 Hz to 55 Hz at 50 Hz 55 Hz to 65 Hz at 60 Hz 25 Hz to 45 Hz at 50 Hz 30 Hz to 55 Hz at 60 Hz Increased tolerances Tripping delay 87L Tri...

Page 300: ...mission rate of 512 kbit s Pickup trip times of the 87N L IN s element at 50 Hz or 60 Hz approx minimum 24 ms to 29 ms Dropout times of the I87N L I DIFF element approx minimum 35 ms to 50 ms Minimum current for direction determination 5 of setting value or 1 INom Delay of the 87N L I DIFF element approx 1 of setting value or 10 ms Frequency range 45 Hz to 55 Hz at 50 Hz 55 Hz to 65 Hz at 60 Hz 25...

Page 301: ... 25 ms typical 27 ms maximum 29 ms Expiry tolerances 1 of setting value or 10 ms The set times are pure time delays Tripping of the remote ends by a command injected via binary inputs The command times depend on the communication speed The following data require a transmission rate of 512 kbit s for the optical fiber protection interface Operating times total approx minimum 10 ms typical 13 ms max...

Page 302: ...A to 25 00 A or ineffective Increments 0 01 A for INom 5 A 0 50 A to 125 00 A or ineffective Pickup value 50N B1 PICKUP ground for INom 1 A 0 05 A to 25 00 A or ineffective Increments 0 01 A for INom 5 A 0 25 A to 125 00 A or ineffective Pickup value directional phases for INom 1 A 0 10 A to 25 00 A or ineffective Increments 0 01 A for INom 5 A 0 50 A to 125 00 A or ineffective Delays directional ...

Page 303: ...alue 50N STUB PICKUP ground for INom 1 A 0 05 A to 25 00 A or ineffective Increments 0 01 A for INom 5 A 0 25 A to 125 00 A or ineffective Delays 50 STUB DELAY 0 00 s to 30 00 s or ineffective Increments 0 01 s 50N STUB DELAY 0 00 s to 30 00 s or ineffective Increments 0 01 s Pickup value directional phases for INom 1 A 0 10 A to 25 00 A or ineffective Increments 0 01 A for INom 5 A 0 50 A to 125 ...

Page 304: ...ting value 15 ms 5 of setting value 15 ms defined times 1 of setting value or 10 ms Pickup value 67 TOC PICKUP directional phases for INom 1 A 0 10 A to 4 00 A or ineffective Increments 0 01 A for INom 5 A 0 50 A to 20 00 A or ineffective Pickup value 67N TOC PICKUP Earth directional for INom 1 A 0 05 A to 4 00 A or ineffective Increments 0 01 A for INom 5 A 0 25 A to 20 00 A or ineffective Time m...

Page 305: ...P 1 s 5 of setting value 15 ms 5 of setting value 15 ms defined times 1 of setting value or 10 ms Pickup value 67 TOC PICKUP directional phases for INom 1 A 0 10 A to 4 00 A or ineffective Increments 0 01 A for INom 5 A 0 50 A to 20 00 A or ineffective Pickup value 67N TOC PICKUP Earth directional for INom 1 A 0 05 A to 4 00 A or ineffective Increments 0 01 A for INom 5 A 0 25 A to 20 00 A or inef...

Page 306: ...cal Data 4 7 Time Overcurrent Protection SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 306 Figure 4 3 Trip time characteristics of inverse time overcurrent elements acc IEC phases and ground ...

Page 307: ... Data 4 7 Time Overcurrent Protection SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 307 Figure 4 4 Trip time characteristics of inverse time overcurrent element acc ANSI IEEE phases and ground ...

Page 308: ... Data 4 7 Time Overcurrent Protection SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 308 Figure 4 5 Trip time characteristics of inverse time overcurrent element acc ANSI IEEE phases and ground ...

Page 309: ...INom 1 A 1 1 A to 25 0 A Increments 0 1 A INom 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 deactivated or active until dropout Increments 0 01 s Restraint ratio 2 Inrush stabilization I2fN IfN 0 to 45 Increments 1 Max current for restraint INom 1 A 1 1 A to 25 0 A Increments 0 1 A INom 5 A 5 5 A to 125 ...

Page 310: ...iliary 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 or external 1 pole trip 1 Internal or external 3 pole trip 1 Int...

Page 311: ... Thermal Alarm ΘAlarm ΘTrip 50 to 100 of the trip overtemperature Increments 1 Current alarm element IAlarm for INom 1 A 0 10 A to 4 00 A Increments 0 01 A for INom 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 Ap...

Page 312: ...Technical Data 4 10 Thermal Overload Protection 49 SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 312 Figure 4 6 Trip time characteristics of the overload protection ...

Page 313: ...ting value or 10 ms Overvoltage VPhPh 2 0 V to 220 0 V Increments 0 1 V Delay TVPhPh 0 00 s to 100 00 s Increments 0 01 s Overvoltage VPhPh 2 0 V to 220 0 V Increments 0 1 V Delay TVPhPh 0 00 s to 100 00 s Increments 0 01 s Dropout ratio 0 30 to 0 99 Increments 0 01 Pickup time approx 40 ms Dropout time approx 35 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of setting value or 10 ms Ov...

Page 314: ...0 s to 100 00 s Increments 0 01 s Overvoltage 3V0 1 0 V to 220 0 V Increments 0 1 V Delay T3V0 0 00 s to 100 00 s Increments 0 01 s Dropout ratio 0 30 to 0 99 Increments 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 Voltages 3 of setting value...

Page 315: ... 01 to 1 20 Increments 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 setting value or 10 ms Undervoltage V1 1 0 V to 100 0 V Increments 0 1 V Delay TV1 0 00 s to 100 00 s Increments 0 01 s Undervoltage V1 1 0 V to 100 0 V Increments 0 1 V Delay TV1 0 00 s to 100 00 s Increments 0 01 s Dropou...

Page 316: ...Hz Increments 0 01 Hz Pickup times f f approx 85 ms Dropout times f f approx 30 ms Time delays T 0 00 s to 600 00 s Increments 0 01 s The set times are pure time delays Note on drop off times Drop off was enforced by current 0 A and voltage 0 V Enforcing the drop off by means of a frequency change below the drop off threshold extends the drop off times Δf I pickup value dropout value I 0 02 Hz to ...

Page 317: ...1 s to 300 00 s Increments 0 01 s Dead times prior to reclosure separately for all types and all cycles 0 01 s to 1800 00 s Increments 0 01 s Dead times after evolving fault recognition 0 01 s to 1800 00 s Increments 0 01 s Blocking 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...

Page 318: ...umber of possible remote indications 16 The operating times depend on the communication speed The following data require a transmission rate of 512 kbit s for the optical fiber protection interface The operating times refer to the entire signal path from entry via binary inputs until output of commands via output relays Operating times total approx typical 20 ms 5 ms Dropout times total approx typ...

Page 319: ...e Vmin Vmax BAL FACTOR V as long as Vmax BAL VLIMIT BAL FACTOR V 0 58 to 0 95 Increments 0 01 BAL VLIMIT 10 V to 100 V Increments 1 V T BAL VLIMIT 5 s to 100 s Increments 1 s Voltage phase sequence VA leads VB leads VC as long as VA VB VC 40 V v3 non symmetrical voltages Fuse failure monitoring 3 V0 FFM V OR 3 V2 FFM V AND at the same time 3 I0 FFM I AND 3 I2 FFM I FFM V 10 V to 100 V Increments 1...

Page 320: ...elease date 09 2011 320 Trip Circuit Supervision Number of supervised trip circuits 1 to 3 Operation of each trip circuit With 1 binary input or with 2 binary inputs Pickup and dropout time approx 1 to 2 s Settable time delay for operation with 1 binary input 1 s to 30 s Increments 1 s ...

Page 321: ...t voltage VN 2 0 V to 200 0 V Increments 0 1 V Power P Q for IN 1 A 2 0 W to 10000 W Increment 0 1 W for IN 5 A 10 W to 50000 W Power factor cosϕ 0 99 to 0 99 Increments 0 01 Frequency for fNom 50 Hz for fNom 60 Hz 40 0 Hz to 60 0 Hz 50 0 Hz to 70 0 Hz Increments 0 01 Hz Increments 0 01 Hz Frequency change df dt 0 10 Hz s to 20 00 Hz s Increments 0 01 Hz s Dropout ratio element 1 01 to 3 00 Increm...

Page 322: ...s Binary input approx 20 ms Dropout times Current voltage phase quantities 20 ms Current voltage symmetrical components 30 ms Power typical maximum 50 ms 350 ms Power factor 300 ms Frequency 100 ms Frequency change 200 ms Binary input 10 ms Pickup thresholds Current for INom 1 A 3 of setting value or 15 mA for INom 5 A 3 of setting value or 75 mA Current symmetrical components for INom 1 A 4 of se...

Page 323: ... Pickup Values Auxiliary DC voltage in range 0 8 VAux VAuxNom 1 15 1 Temperature in range 5 C 41 F Θamb 55 C 131 F 0 5 10 K Frequency in range of 25 Hz to 70 Hz Frequency in the range of 0 95 f fNom 1 05 fNom 50 Hz or 60 Hz 1 Frequency outside range 0 95 f fNom 1 05 Increased tolerances Harmonics up to 10 3rd harmonic up to 10 5th harmonic 1 1 ...

Page 324: ...ue 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 X X X DI...

Page 325: ...ession 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 starts monitoring The red ERROR LED lights up Maximum number of all CFC charts considering one task level 16 Only Error Message evolving fault in processing procedure Maximum number of all CFC inputs conside...

Page 326: ...ime res olution of the device of 5 ms as the blocks will not then start with the starting pulse Maximum Number of TICKS in the Task Levels 1 When the sum of TICKS of all blocks exceeds the limits before mentioned an error message is output by CFC Description Limit Comments Maximum number of simultaneous changes of the chart inputs per task level 50 When the limit is exceeded an error message is ou...

Page 327: ...nection 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 Adapter REA...

Page 328: ...urrent Operational Measured Values for Powers S P Q apparent active and reactive power in MVA MW Mvar primary and SN operational nominal power 3 VN IN Tolerance for S 1 5 of SN at I IN and V VN in range 50 to 120 Tolerance for P 2 of PN at I IN and V VN in range 50 to 120 and ABS cos ϕ in range 0 7 Tolerance for Q 2 of QN at I IN and V VN in range 50 to 120 and ABS cos ϕ in range 0 7 Operating Mea...

Page 329: ...ion Resolution 0 01 ms Number of automatic reclosures initiated by the device Separately for 1st AR cycle and for all further cycles Total of interrupted currents separately for each breaker pole Maximum interrupted current separately for each breaker pole Resolution for operational events 1 ms Resolution for fault events 1 ms Buffer battery Type 3 V 1 Ah Type CR 1 2 AA self discharging time appro...

Page 330: ... 6 Figure 4 7 Dimensional drawing of a 7SD80 for panel flush mounting and cabinet flush mounting housing size 1 6 Note A set of mounting brackets consisting of upper and lower mounting rail order no C73165 A63 D200 1 is required for cabinet flush mounting Provide for sufficient space at the device bottom side or below the device to accommodate the cables of the communication modules ...

Page 331: ...4 19 Dimensions SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 331 4 19 2 Panel Surface Mounting Housing Size 1 6 Figure 4 8 Dimensional drawing of a 7SD80 for panel surface mounting housing size 1 6 ...

Page 332: ...Technical Data 4 19 Dimensions SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 332 4 19 3 Bottom View Figure 4 9 Bottom view of a 7SD80 housing size 1 6 ...

Page 333: ...how the proper connections of the devices to primary equipment in many typical power system configurations Tables with all settings and all information available in this device equipped with all options are provided Default settings are also given A 1 Ordering Information and Accessories 334 A 2 Terminal Assignments 339 A 3 Connection Examples 345 A 4 Current Transformer Requirements 348 A 5 Defau...

Page 334: ...er contacts 1 life status contact Protection interface optical fiber for monomode 24 km multimode fiber 4 km LC duplex connector 5 1 6 19 housing 4 x I 3 x V 7 BI 8 BO 2 changeover contacts 1 life status contact Protection interface optical fiber for monomode 24 km multimode fiber 4 km LC duplex connector 6 1 6 19 housing 4 x I 3 x V 5 BI 8 BO 2 changeover contacts 1 life status contact Protection...

Page 335: ...al ports bottom side of device front port B Supple ment Profibus DP Slave electrical RS485 L 0 A Profibus DP Slave optical double ring ST connector L 0 B Modbus electrical RS485 L 0 D Modbus 820 nm optical ST connector L 0 E DNP3 0 electrical RS485 L 0 G DNP3 0 optical 820 nm ST connector L 0 H IEC 60870 5 103 redundant electrical RS485 RJ45 connector L 0 P IEC61850 100Mbit Ethernet 2 electrical p...

Page 336: ...ntrol Flexible protection functions from current voltage 2 power 2 27 59 Undervoltage overvoltage 27 59 2 81 U O Underfrequency overfrequency 2 Basic design directional overcurrent protection phase and directional ground fault protection 1 3 B 67 Overcurrent protection directional phase V I 67 1 67 2 67 TOC 67N Ground fault protection directional V I 67N 1 67N 2 67N TOC Basic design ground fault d...

Page 337: ...195 1 PCM transformer 20 kV screwed connections for ring type lug 7XR9516 Replacement Modules for Interfaces RS232 C53207 A351 D641 1 RS485 C53207 A351 D642 1 optical fiber 820 nm C53207 A351 D643 1 Profibus DP RS485 C53207 A351 D611 1 Profibus DP double ring C53207 A351 D613 1 Profibus FMS RS485 C53207 A351 D603 1 Profibus FMS double ring C53207 A351 D606 1 DNP 3 0 RS485 C53207 A351 D631 1 DNP 3 ...

Page 338: ...101 301 Panasonic BR 1 2AA Terminals Voltage terminal block C or block E C53207 A406 D181 1 Voltage terminal block D inverse print C53207 A406 D182 1 Current terminal block 4xI C53207 A406 D185 1 Current terminal block 3xI 1xINs sensitive C53207 A406 D186 1 Current terminal short circuit links 3 pieces C53207 A406 D193 1 Voltage terminal short circuit links 6 pieces C53207 A406 D194 1 ...

Page 339: ...ts SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 339 A 2 Terminal Assignments A 2 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounting 7SD801 Figure A 1 Overview diagram 7SD801 ...

Page 340: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 340 7SD802 Figure A 2 Overview diagram 7SD802 ...

Page 341: ...rminal Assignments SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 341 7SD803 Figure A 3 Connection diagram 7SD803 The optical fiber interface at port A can only be delivered if the 12th digit equals 7 ...

Page 342: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 342 7SD805 Figure A 4 Overview diagram 7SD805 ...

Page 343: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 343 7SD806 Figure A 5 Overview diagram 7SD806 ...

Page 344: ...rminal Assignments SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 344 7SD807 Figure A 6 Connection diagram 7SD807 The optical fiber interface at port A can only be delivered if the 12th digit equals 7 ...

Page 345: ...rent transformers and neutral point current ground current Holmgreen connection standard connection suitable for all power systems neutral point in line direction Figure A 8 Current transformer connections to three current transformers and neutral point current ground current Holmgreen connection standard connection suitable for all power systems neutral point in busbar direction ...

Page 346: ... from additional summation current transformer preferably for effectively or low resistance grounded networks Important Grounding of the cable shield must be effected at the cable side Note The switchover of the current polarity address 201 also reverses the polarity of the current input IN Figure A 10 Example for the connection type VAN VBN VCN with voltage connection on the feeder side ...

Page 347: ...Appendix A 3 Connection Examples SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 347 Figure A 11 V0 connection ...

Page 348: ...of the remote device Required minimum effective accuracy limiting factor and K SSC min 30 K SSC Effective symmetrical short circuit current factor KSSC Specified symmetrical short circuit current factor example Current transformer 5P20 KSSC 20 ISSC max ext fault maximum through flowing short circuit current Ipn Primary transformer rated current RCT Secondary direct current winding resistance of th...

Page 349: ...ltage RCt Internal burden RB Rated burden Isn Secondary rated transformer current KSSC Rated overcurrent factor Vs t max sec terminal voltage at 20 Ipn Maximum difference of the primary rated currents of the core balance current transformer 0 33 Ipn local Ipn remote 3 Select the primary rated current of the core balance current transformer so that ground current flowing in the ground fault of the ...

Page 350: ... required class accuracy depending on the neutral point grounding and the operation of the function An angle correction may have to be parameterized at the device for particularly small ground fault currents see Description of the sensitive ground fault detection Neutral point Isolated Resonant grounded system Function directional Class 1 Class 1 ...

Page 351: ...eral TRIP 85 DT Gen TRIP 3517 85 DT General TRIP LED7 Emer mode 2054 Emergency mode LED8 Alarm Sum Event 160 Alarm Summary Event Failure Σi 289 Alarm Current summation supervision Binary Input Default function Function No Description BI1 85 DT 3pol 3504 86 DT Intertrip 3 pole signal input BI2 87L block 32100 87L Protection blocking signal 87N L block 32120 87N L Protection blocking signal BI3 BLOC...

Page 352: ...ion BO1 Emer mode 2054 Emergency mode BO2 Alarm Sum Event 160 Alarm Summary Event BO3 Relay PICKUP 501 Relay PICKUP BO4 Relay TRIP 511 Relay GENERAL TRIP command BO5 Relay TRIP 511 Relay GENERAL TRIP command BO6 Rem Sig 1 Rx 3573 Remote signal 1 received BO7 PDI FO faulty 3230 PDI FO failure PDI Cu faulty 3232 PDI Cu failure BO8 Function Keys Default function F1 Display of operational indications ...

Page 353: ...device type The start page of the default display appearing after startup of the device can be selected in the device data via parameter 640 Start image DD for the 6 line display of the 7SD80 Figure A 12 Default display of the 7SD80 for models with V without extended measured values For V0 I0 ϕ measurement the measured ground current INB is shown under N and the ground current IN or INs under Ns ...

Page 354: ... 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 354 Figure A 13 Default display of the 7SD80 for models with V with extended measured values Figure A 14 Default display of the 7SD80 for models without V and extended measured values ...

Page 355: ...e A 16 Default display of the device with Cu protection interface Figure A 17 Default display of the device with fiber optic protection interface Spontaneous Fault Display After a fault has occurred the most important fault data are automatically displayed after general device pickup in the order shown in the picture below Figure A 18 Representation of spontaneous messages on the device display ...

Page 356: ...C474 A1 Release date 09 2011 356 A 5 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 UnlockDT Figure A 19 Connection of input and output ...

Page 357: ...User defined indications and switch ing objects Yes Yes Yes Yes Yes Time synchronization Yes Yes Yes Yes Yes Messages with time stamp Yes Yes Yes Yes Yes Commissioning aids Data transmission stop Yes Yes Yes No No Creating test messag es Yes Yes Yes No No Physical mode Asynchronous Asynchronous Synchronous Asynchronous Asynchronous Transmission mode cyclic event cyclic event cyclic event cyclic cy...

Page 358: ... N ANSI 50 N 51 N IEC Backup overcurrent 133 79 Auto Recl Disabled 1 AR cycle 2 AR cycles Disabled 79 Auto Reclose Function 134 AR control mode PU w ActionTime PU w o ActionT Trip w ActionT Trip w oActionT Trip w ActionT Auto Reclose control mode 136 81 O U Disabled Enabled Disabled 81 Over Underfrequency Protec tion 137 27 59 Disabled Enabled Disabled 27 59 Under Overvoltage Protec tion 139 50BF ...

Page 359: ... Flexible Function 04 Flexible Function 05 Flexible Function 06 Flexible Function 07 Flexible Function 08 Flexible Function 09 Flexible Function 10 Flexible Function 11 Flexible Function 12 Flexible Function 13 Flexible Function 14 Flexible Function 15 Flexible Function 16 Flexible Function 17 Flexible Function 18 Flexible Function 19 Flexible Function 20 Please select Flexible Functions Addr Para...

Page 360: ...xceeding Dropping below Exceeding Pickup with 0 CURRENT Flx Ia Ib Ic In In sensitive Ia Current 0 VOLTAGE Flx Please select Va n Vb n Vc n Va b Vb c Vc a Please select Voltage 0 POWER Flx Ia Va n Ib Vb n Ic Vc n Ia Va n Power 0 VOLTAGE SYSTEM Flx Phase Phase Phase Ground Phase Phase Voltage System 0 P U THRESHOLD Flx 0 03 40 00 A 2 00 A Pickup Threshold 0 P U THRESHOLD Flx 1A 0 03 40 00 A 2 00 A P...

Page 361: ... CBtest dead P System Data 1 0 00 30 00 sec 0 10 sec Dead Time for CB test autoreclo sure 260 Threshold BI 1 P System Data 1 Thresh BI 176V Thresh BI 88V Thresh BI 19V Thresh BI 176V Threshold for Binary Input 1 261 Threshold BI 2 P System Data 1 Thresh BI 176V Thresh BI 88V Thresh BI 19V Thresh BI 176V Threshold for Binary Input 2 262 Threshold BI 3 P System Data 1 Thresh BI 176V Thresh BI 88V Th...

Page 362: ... 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 Line Closure P System Data 2 only with ManCl I OR V or ManCl 52a OR I or M C I or Man Close only with ManCl Recognition of Line Closures with 1135 Reset Trip CMD P System Data 2 CurrentOpenPole Current AND 52a Pickup Reset CurrentOpenPole RESET of Trip Command...

Page 363: ...lay for intertrip via bin input 1304 85 DT T PROL BI 85 DT Intertrip 0 00 30 00 sec 0 00 sec 85 DT Prol for intertrip via bin in put 1305 85 DT Iph rel 85 DT Intertrip 1A 0 0 25 0 A 0 0 A 85 DT minimal Phase Current to rel trip 5A 0 0 125 0 A 0 0 A 1306 85 DT 3I0 rel 85 DT Intertrip 1A 0 0 25 0 A 0 0 A 85 DT minimal 3I0 Current to rel trip 5A 0 0 125 0 A 0 0 A 2201 Direct Trip DT DTT Direct Trip O...

Page 364: ...CKED BLOCKED 67 N B2 Direct stage on Fuse Failure 2623 50 B2 PICKUP Back Up O C 1A 0 10 25 00 A 1 50 A 50 B2 Pickup 5A 0 50 125 00 A 7 50 A 2623 67 B2 PICKUP Back Up O C 0 05 50 00 A 1 50 A 67 B2 Pickup threshold 2624 50 B2 DELAY Back Up O C 0 00 30 00 sec 0 50 sec 50 B2 Delay 2624 67 B2 DELAY Back Up O C 0 00 30 00 sec 0 50 sec 67 B2 set time delay 2625 50 B2 Inrush Back Up O C NO YES NO 50 B2 In...

Page 365: ...r 2641 51N B AddTdelay Back Up O C 0 00 30 00 sec 0 00 sec 51N B Additional Time Delay 2641 67N TOC AddTDel Back Up O C 0 00 30 00 sec 0 00 sec 67N TOC Additional Time Delay 2642 IEC Curve Back Up O C Normal Inverse Very Inverse Extremely Inv LongTimeInverse Normal Inverse IEC Curve 2642 IEC Curve Back Up O C Normal Inverse Very Inverse Extremely Inv LongTimeInverse Normal Inverse IEC Curve 2643 A...

Page 366: ...rem Superv 5 100 sec 5 sec T Balance Factor for Voltage Monitor 2909A T BAL I LIMIT Measurem Superv 5 100 sec 5 sec T Current Balance Monitor 2910 FUSE FAIL MON Measurem Superv ON OFF ON Fuse Failure Monitor 2911A FFM V min Measurem Superv 10 100 V 30 V Minimum Voltage Threshold V 2912A FFM I max Measurem Superv 1A 0 10 1 00 A 0 10 A Maximum Current Threshold I 5A 0 50 5 00 A 0 50 A 2913A FFM V ma...

Page 367: ...64 2 AR DeadT 1Flt 79 Auto Recl 0 01 1800 00 sec 1 20 sec Dead time after 1phase faults 3465 2 AR DeadT 2Flt 79 Auto Recl 0 01 1800 00 sec 1 20 sec Dead time after 2phase faults 3466 2 AR DeadT 3Flt 79 Auto Recl 0 01 1800 00 sec 0 50 sec Dead time after 3phase faults 3468 2 AR Dead 3Trip 79 Auto Recl 0 01 1800 00 sec 0 50 sec Dead time after 3pole trip 3469 2 AR DeadT EV 79 Auto Recl 0 01 1800 00 ...

Page 368: ...ero seq 3725 59G 2 3V0 DELAY 27 59 O U Volt 0 00 100 00 sec 1 00 sec 59G 2 Time Delay 3728A 59G 3Vo Stabil 27 59 O U Volt ON OFF ON 59G Stabilization 3Vo Measure ment 3729A 59G RESET 27 59 O U Volt 0 30 0 99 0 95 Reset ratio 3731 59 V1 Mode 27 59 O U Volt OFF Alarm Only ON V Alarm V Trip OFF Operating mode V1 overvoltage prot 3732 59 1 V1 PICKUP 27 59 O U Volt 2 0 220 0 V 150 0 V 59 1 Pickup Overv...

Page 369: ... 20 1 05 Reset ratio 3901 FCT 50BF Break 50BF BkrFailure ON OFF ON 50BF Breaker Failure Protection 3902 50BF PICKUP 50BF BkrFailure 1A 0 05 20 00 A 0 10 A 50BF Pickup current threshold 5A 0 25 100 00 A 0 50 A 3905 50BF 1 Delay 3p 50BF BkrFailure 0 00 30 00 sec 0 00 sec Delay after 3pole start for local trip 3906 50BF 2 Delay 50BF BkrFailure 0 00 30 00 sec 0 15 sec Delay of 2nd element for busbar t...

Page 370: ... Time delay for data disturbance alarm 4512 Td ResetRemote Prot Interface 0 00 300 00 sec 0 00 sec Remote signal RESET DELAY for comm fail 4601 PDI Cu Prot Interface ON OFF ON Protection Data Interface copper 4602 PDI Cu TER Prot Interface 0 5 20 0 1 0 PDI Cu max telegram error rate 4603 PDI Cu mode Prot Interface 01 02 03 04 05 06 01 PDI Cu operation mode 4604 PDI Cu MAX ATT Prot Interface 0 46 d...

Page 371: ...set 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 Key Relay Chatter Suppression Type Information Number Data Unit General Interrogation Test mode Test mode Device General IntSP On Off LED BO 192 21 1 Yes Stop data trans...

Page 372: ...ing 52 Open 52 Open Control Device IntSP Interlocking 52 Close 52 Close Control Device IntSP Interlocking Disconnect switch Open Disc Open Control Device IntSP Interlocking Disconnect switch Close Disc Close Control Device IntSP Interlocking Ground switch Open GndSw Open Control Device IntSP Interlocking Ground switch Close GndSw Cl Control Device IntSP Q2 Open Close Q2 Op Cl Control Device CF_D 2...

Page 373: ...0 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 General SP LED BI BO 192 27 1 Yes 12 User defined annunciation 2 Annunc 2 Device General SP LED BI BO 192 28 1 Yes 13 User defined annunciation 3 Annunc ...

Page 374: ...ce Fail I balance Measurem Superv OUT On Off LED BO 135 183 1 Yes 164 Failure General Voltage Supervi sion Fail V Superv Measurem Superv OUT LED BO 192 33 1 Yes 167 Failure Voltage Balance Fail V balance Measurem Superv OUT On Off LED BO 135 186 1 Yes 168 Failure Voltage absent Fail V absent Measurem Superv OUT On Off LED BO 135 187 1 Yes 169 VT Fuse Failure alarm 10s VT FuseFail 10s Measurem Supe...

Page 375: ... 2115 Function 00 BLOCK TRIP Phase A 00 BL TripA Flx SP On Off On Off LED BI FC TN BO 235 2116 Function 00 BLOCK TRIP Phase B 00 BL TripB Flx SP On Off On Off LED BI FC TN BO 235 2117 Function 00 BLOCK TRIP Phase C 00 BL TripC Flx SP On Off On Off LED BI FC TN BO 235 2118 Function 00 is BLOCKED 00 BLOCKED Flx OUT On Off On Off LED BO 235 2119 Function 00 is switched OFF 00 OFF Flx OUT On Off LED B...

Page 376: ... Broken current wire at other end ØC ext Brk Wire ØC Measurem Superv OUT On Off LED BO 301 Power System fault Pow Sys Flt P System Data 2 OUT On Off ON 135 231 2 Yes 302 Fault Event Fault Event P System Data 2 OUT ON 135 232 2 No 320 Warn Limit of Memory Data ex ceeded Warn Mem Data Device General OUT On Off LED BO 321 Warn Limit of Memory Parameter exceeded Warn Mem Para Device General OUT On Off...

Page 377: ...LED BI BO 407 Frq MIN MAX Buffer Reset Frq MiMa Reset Min Max meter SP ON LED BI BO 408 Power Factor MIN MAX Buffer Reset PF MiMaReset Min Max meter SP ON LED BI BO 410 52a Bkr1 aux 3pClosed for AR CB Test 52a Bkr1 3p Cl P System Data 2 SP LED BI BO 150 80 1 Yes 411 52b Bkr1 aux 3p Open for AR CB Test 52b Bkr1 3p Op P System Data 2 SP LED BI BO 150 81 1 Yes 501 Relay PICKUP Relay PICKUP P System D...

Page 378: ...C Σ Ic Statistics VI 1030 max fault current Phase A Ia max Statistics VI 1031 max fault current Phase B Ib max Statistics VI 1032 max fault current Phase C Ic max Statistics VI 1401 50BF Switch on breaker fail prot 50BF on 50BF BkrFailure SP LED BI BO 1402 50BF Switch off breaker fail prot 50BF off 50BF BkrFailure SP LED BI BO 1403 BLOCK 50BF BLOCK 50BF 50BF BkrFailure SP On Off LED BI BO 166 103 ...

Page 379: ...1521 49 Thermal Overload TRIP 49 Th O L TRIP 49 Th Overload OUT ON LED BO 167 21 2 Yes 2054 Emergency mode Emer mode Device General OUT On Off On Off LED BO 192 37 1 Yes 2701 79 ON 79 ON 79 Auto Recl SP LED BI BO 40 1 1 Yes 2702 79 OFF 79 OFF 79 Auto Recl SP LED BI BO 40 2 1 Yes 2703 BLOCK 79 BLOCK 79 79 Auto Recl SP On Off LED BI BO 40 3 1 Yes 2711 79 External start of internal A R 79 Start 79 Au...

Page 380: ... dead time after 3phase fault running 79 Tdead 3pFlt 79 Auto Recl OUT ON LED BO 40 154 2 Yes 2844 79 1st cycle running 79 1stCyc run 79 Auto Recl OUT ON LED BO 40 155 2 Yes 2845 79 2nd cycle running 79 2ndCyc run 79 Auto Recl OUT ON LED BO 40 157 2 Yes 2851 79 Close command 79 Close 79 Auto Recl OUT ON m LED BO 192 128 2 No 2853 79 Close command after 3pole 1st cycle 79 Close1 Cyc3p 79 Auto Recl O...

Page 381: ...f LED BI BO 3230 PDI FO failure PDI FO faulty Prot Interface OUT On Off LED BO 93 136 1 Yes 3232 PDI Cu failure PDI Cu faulty Prot Interface OUT On Off LED BO 93 138 1 Yes 3243 PDI FO connected to relay ID PDI FO con to Prot Interface VI On Off 3244 PDI Cu connected to relay ID PDI Cu con to Prot Interface VI On Off 3258 PDI FO telegram error rate ex ceeded PDI FO TER Prot Interface OUT On Off LED...

Page 382: ...te Signals SP On Off LED BI BO 3560 Remote Signal 12 input Rem Signal12 Remote Signals SP On Off LED BI BO 3561 Remote Signal 13 input Rem Signal13 Remote Signals SP On Off LED BI BO 3562 Remote Signal 14 input Rem Signal14 Remote Signals SP On Off LED BI BO 3563 Remote Signal 15 input Rem Signal15 Remote Signals SP On Off LED BI BO 3564 Remote Signal 16 input Rem Signal16 Remote Signals SP On Off...

Page 383: ...1 35 2 No 5203 BLOCK 81O U BLOCK 81O U 81 O U Freq SP On Off LED BI BO 70 176 1 Yes 5206 BLOCK 81 1 BLOCK 81 1 81 O U Freq SP On Off LED BI BO 70 177 1 Yes 5207 BLOCK 81 2 BLOCK 81 2 81 O U Freq SP On Off LED BI BO 70 178 1 Yes 5208 BLOCK 81 3 BLOCK 81 3 81 O U Freq SP On Off LED BI BO 70 179 1 Yes 5209 BLOCK 81 4 BLOCK 81 4 81 O U Freq SP On Off LED BI BO 70 180 1 Yes 5211 81 OFF 81 OFF 81 O U Fr...

Page 384: ...blocked Binary input is not set 74TC 3 ProgFAIL 74TC TripCirc OUT On Off LED BO 7104 BLOCK 50 B1 Backup Over Current BLOCK 50 B1 Back Up O C SP On Off LED BI BO 64 4 1 Yes 7105 BLOCK 50 B2 Backup Over Current BLOCK 50 B2 Back Up O C SP On Off LED BI BO 64 5 1 Yes 7106 BLOCK 51 B Backup OverCur rent BLOCK 51 B Back Up O C SP On Off LED BI BO 64 6 1 Yes 7107 BLOCK 50N B1 Backup Over Current BLOCK 50...

Page 385: ...64 65 2 Yes 7191 50 N B1 Pickup 50 N B1 PICKUP Back Up O C OUT ON m LED BO 64 91 2 Yes 7192 50 N B2 Pickup 50 N B2 PICKUP Back Up O C OUT ON m LED BO 64 92 2 Yes 7193 51 N B Pickup 51 N B PICKUP Back Up O C OUT ON m LED BO 64 93 2 Yes 7201 50 STUB Pickup 50 STUB PICKUP Back Up O C OUT On Off m LED BO 64 101 2 Yes 7211 50 N 51 N B General TRIP command 5X B TRIP Back Up O C OUT LED BO 64 111 2 No 72...

Page 386: ...Yes 7346 CB TEST canceled due to Power Sys Fault CB TSTstop FLT Testing OUT_ Ev ON 7347 CB TEST canceled due to CB already OPEN CB TSTstop OPEN Testing OUT_ Ev ON 7348 CB TEST canceled due to CB was NOT READY CB TSTstop NOTr Testing OUT_ Ev ON 7349 CB TEST canceled due to CB stayed CLOSED CB TSTstop CLOS Testing OUT_ Ev ON 7350 CB TEST was successful CB TST OK Testing OUT_ Ev ON 10201 BLOCK 59 Vph...

Page 387: ...Undervolt is switched OFF 27 Vphph OFF 27 59 O U Volt OUT On Off LED BO 73 27 1 Yes 10228 27 Vphph Undervolt is BLOCKED 27 Vphph BLK 27 59 O U Volt OUT On Off On Off LED BO 73 28 1 Yes 10229 27 V1 Undervolt is switched OFF 27 V1 OFF 27 59 O U Volt OUT On Off LED BO 73 29 1 Yes 10230 27 V1 Undervolt is BLOCKED 27 V1 BLK 27 59 O U Volt OUT On Off On Off LED BO 73 30 1 Yes 10231 27 59 Voltage protect...

Page 388: ... Volt OUT LED BO 73 140 2 Yes 10265 59 1 Vphph Pickup C A 59 1 Vpp PU CA 27 59 O U Volt OUT LED BO 73 141 2 Yes 10266 59 2 Vphph Pickup A B 59 2 Vpp PU AB 27 59 O U Volt OUT LED BO 73 142 2 Yes 10267 59 2 Vphph Pickup B C 59 2 Vpp PU BC 27 59 O U Volt OUT LED BO 73 143 2 Yes 10268 59 2 Vphph Pickup C A 59 2 Vpp PU CA 27 59 O U Volt OUT LED BO 73 144 2 Yes 10270 59 1 3V0 Pickup 59 1 3V0 Pickup 27 5...

Page 389: ... C 27 Vpg PU C 27 59 O U Volt OUT On Off LED BO 73 114 2 Yes 10315 27 1 Vphg TimeOut 27 1 Vpg TimeOut 27 59 O U Volt OUT LED BO 10316 27 2 Vphg TimeOut 27 2 Vpg TimeOut 27 59 O U Volt OUT LED BO 10317 27 Vphg TRIP command 27 Vpg TRIP 27 59 O U Volt OUT ON LED BO 73 117 2 Yes 10318 27 1 Vphg Pickup A 27 1 Vpg PU A 27 59 O U Volt OUT LED BO 73 145 2 Yes 10319 27 1 Vphg Pickup B 27 1 Vpg PU B 27 59 O...

Page 390: ... No 17531 67 N Backup O C is ACTIVE 67 N ACTIVE Back Up O C OUT ON LED BO 64 149 2 No 17532 Backup O C stage 67 N B2 is sw OFF 67 N B2 OFF Back Up O C OUT ON LED BO 17533 Backup O C stage 67 N B1 is sw OFF 67 N B1 OFF Back Up O C OUT ON LED BO 17534 Backup O C stage 67 N TOC is sw OFF 67 N TOC OFF Back Up O C OUT ON LED BO 17535 67 N Backup O C PICKED UP 67 N PICKUP Back Up O C OUT on LED BO 17536...

Page 391: ...117 87L IDYN C 87L IDYN C 87 Diff Prot OUT On Off m LED BO 32118 87L ISTAT A 87L ISTAT A 87 Diff Prot OUT On Off m LED BO 32119 87L ISTAT B 87L ISTAT B 87 Diff Prot OUT On Off m LED BO 32120 87N L Protection blocking signal 87N L block 87 Diff Prot SP On Off LED BI BO 32121 87N L Protection is active 87N L active 87 Diff Prot OUT on LED BO 32122 87 N L Fault detection 87 N L Gen Flt 87 Diff Prot O...

Page 392: ...32203 PDI Test Mode remote PDI Test remote Device General OUT On Off LED BO 32224 PDI FO aging distance damping high PDI FO AGING Device General OUT LED BO 32225 PDI Cu aging distance damping high PDI Cu AGING Device General OUT LED BO 32227 PDI FO receive level to low PDI FO RQ LOW Prot Interface OUT On Off LED BO 32228 PDI FO attenuation to high PDI Cu ATT HIGH Prot Interface OUT On Off LED BO 3...

Page 393: ...m Sum Event 289 163 167 168 169 170 171 177 190 191 193 183 184 185 186 187 Failure Σi Fail I balance Fail V balance Fail V 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 5 161 Fail I Superv 289 163 Failure Σi Fail I balance 164 Fail V Superv 167 168 Fail V balance Fail V absen...

Page 394: ...nt 134 129 No 9 4 CFC CD DD 622 Vb Vb Measurement 134 129 No 9 5 CFC CD DD 623 Vc Vc Measurement 134 129 No 9 6 CFC CD DD 624 Va b Va b Measurement 134 129 No 9 10 CFC CD DD 625 Vb c Vb c Measurement 134 129 No 9 11 CFC CD DD 626 Vc a Vc a Measurement 134 129 No 9 12 CFC CD DD 627 VN VN Measurement CFC CD DD 631 3V0 zero sequence 3V0 Measurement CFC CD DD 634 V1 positive sequence V1 Measurement CF...

Page 395: ...ve sequence Maximum I1 Max Min Max meter CFC CD DD 859 Va n Min Va nMin Min Max meter CFC CD DD 860 Va n Max Va nMax Min Max meter CFC CD DD 861 Vb n Min Vb nMin Min Max meter CFC CD DD 862 Vb n Max Vb nMax Min Max meter CFC CD DD 863 Vc n Min Vc nMin Min Max meter CFC CD DD 864 Vc n Max Vc nMax Min Max meter CFC CD DD 865 Va b Min Va bMin Min Max meter CFC CD DD 867 Va b Max Va bMax Min Max meter...

Page 396: ...verse Pdmd Rev Demand meter CFC CD DD 1054 Reactive Power Demand Forward Qdmd Forw Demand meter CFC CD DD 1055 Reactive Power Demand Reverse Qdmd Rev Demand meter CFC CD DD 7731 PHI I AB local Φ I AB Measurement CFC CD DD 7732 PHI I BC local Φ I BC Measurement CFC CD DD 7733 PHI I CA local Φ I CA Measurement CFC CD DD 7734 PHI V AB local Φ V AB Measurement CFC CD DD 7735 PHI V BC local Φ V BC Meas...

Page 397: ...Slave CFC CD DD 7785 Angle I B_remote I B_local ΦI B Measure Slave CFC CD DD 7786 I C of Operational nominal current I C_opN Measure Slave CFC CD DD 7787 Angle I C_remote I C_local ΦI C Measure Slave CFC CD DD 7789 V A of Operational nominal voltage V A_opN Measure Slave CFC CD DD 7790 Angle V A_remote V A_local ΦV A Measure Slave CFC CD DD 7791 V B of Operational nominal voltage V B_opN Measure S...

Page 398: ...CD DD 32222 PDI FO temperatur PDI FO TEMP Measure PDI CFC CD DD 32223 PDI FO BIAS current PDI FO BIAS Measure PDI CFC CD DD 32226 Rest3I0 Operational nominal current Rest3I0 IDiff IRest CFC CD DD 32230 Send telegrams in the last second Send Tel sec Measure PDI CFC CD DD 32231 Good received telegrams in the last sec Good Rec sec Measure PDI CFC CD DD 32232 Bad received telegrams in the last sec Bad...

Page 399: ...40 C474 A1 Release date 09 2011 399 Literature 1 SIPROTEC 4 System Description E50417 H1176 C151 A1 2 SIPROTEC DIGSI Start UP E50417 G1176 C152 A2 3 DIGSI CFC Manual E50417 H1176 C098 A5 4 SIPROTEC SIGRA 4 Manual E50417 H1176 C070 A1 ...

Page 400: ...Literature SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 400 ...

Page 401: ... 4 bytes BP_xx Bit pattern indication Bitstring Of x Bit x designates the length in bits 8 16 24 or 32 bits C_xx Command without feedback CF_xx Command with feedback CFC Continuous Function Chart CFC is a graphics editor with which a program can be created and configured by using ready made blocks CFC blocks Blocks are parts of the user program delimited by their function their structure or their ...

Page 402: ...uch a con tainer Control display The image which is displayed on devices with a large graphic display after pressing the control key is called control display It contains the switchgear that can be controlled in the feeder with status display It is used to perform switching operations Defining this diagram is part of the configuration Data pane The right hand area of the project window displays th...

Page 403: ...and moved from one data area to another Electromagnetic compatibility Electromagnetic compatibility EMC is the ability of an electrical apparatus to function fault free in a specified environment without influencing the environment unduly EMC Electromagnetic compatibility ESD protection ESD protection is the total of all the means and measures used to protect electrostatic sensitive devices ExBPxx...

Page 404: ... is sampled This information is used to update the system end process image The current process state can also be sampled after a data loss by means of a GI GOOSE message GOOSE messages Generic Object Oriented Substation Event in accordance with IEC 61850 are data pack ages that are transmitted cyclically and event controlled via the Ethernet communication system They serve for direct information ...

Page 405: ...nd sub modules using ModPara has been completed This data is split up into several files One file contains details about the fundamental project structure This also includes for example information detailing which fields exist in this project This file is called a HV project description file ID Internal double point indication Double point indication ID_S Internal double point indication intermedi...

Page 406: ...bject The type and scope of the information exchanged among the users is also stored in this object IRIG B Time signal code of the Inter Range Instrumentation Group IS Internal single point indication Single point indication IS_F Internal indication fleeting Fleeting indication Single point indication ISO 9001 The ISO 9000 ff range of standards defines measures used to ensure the quality of a prod...

Page 407: ... 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 a user address You can create several modem profiles for one physical modem To do so you need to link various initialization commands o...

Page 408: ...EC 4 device Phone book User addresses for a modem connection are saved in this object type PMV Pulse metered value Process bus Devices featuring a process bus interface can communicate directly with the SICAM HV modules The process bus interface is equipped with an Ethernet module PROFIBUS PROcess FIeld BUS the German process and field bus standard as specified in the standard EN 50170 Volume 2 PR...

Page 409: ...dem Setting parameters General term for all adjustments made to the device Parameterization jobs are executed by means of DIGSI or in some cases directly on the device SI Single point indication SI_F Single point indication fleeting Transient information Single point indication SICAM PAS Power Automation System Substation control system The range of possible configurations spans from integrated st...

Page 410: ...t may well differ from the device data of the source object However all variants derived from the source object have the same VD address as the source object For this reason they always correspond to the same real SIPROTEC 4 device as the source object Objects of type SIPROTEC 4 variant have a variety of uses such as documenting different operating states when entering parameter settings of a SIPR...

Page 411: ...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 by DIGSI Manager It exists only once in the entire project and thus serves to ide...

Page 412: ...Glossary SIPROTEC 7SD80 Manual E50417 G1140 C474 A1 Release date 09 2011 412 ...

Page 413: ...ctions 256 Checking Time Synchronization 259 Checking User defined Functions 277 Circuit Breaker External tripping 139 Malfunction 106 Position logic 158 Test 39 Trip close test 278 Circuit Breaker Position Detection 158 Circuit Breaker Failure Protection 101 310 Circuit breaker monitoring 310 End fault protection 310 Initiation conditions 310 Pole discrepancy supervision 310 Times 310 Climatic st...

Page 414: ...failure monitor 169 176 G Ground current differential protection Pickup value 62 Pickup values 62 Ground fault 63 Ground fault differential protection 23 23 Ground fault direction determination 64 H Humidity 291 I Initiation breaker failure protection 104 Inrush current restraint 309 Inrush Restraint 309 Insulation Test 288 Interlocked Switching 218 Intertrip 76 301 Inverse time current element ov...

Page 415: ... 161 318 Remote Tripping 301 Remote tripping 76 Restraint current values 206 Retrieving parameters 213 S Selection of Default Display Start page 34 Service Conditions 291 Setting Groups Changing Changing Setting Groups 233 Single element breaker failure protection 109 Software Monitoring 165 Standard Interlocking 219 222 Standards 288 Start Triggering Oscillographic Recording 279 Statistics 329 Su...

Page 416: ...o phase 123 127 315 Positive sequence system V1 123 127 315 User defined functions 324 V Vibration and Shock Stress during Stationary Operation 290 Vibration and Shock Stress during Transport 290 Voltage balance 166 Voltage inputs 282 Voltage phase rotation 169 Voltage Protection 25 116 Voltage supply 283 W Warning Temperature Level 114 Watchdog 165 Wire break monitoring 167 ...

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