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Siemens SIPROTEC, Manual

The Siemens SIPROTEC is a cutting-edge product built to ensure reliable and secure power system protection. Offering unmatched precision and performance, this advanced device comes with a comprehensive user Manual that can be conveniently downloaded for free from our website 88.208.23.73:8080. Explore the product's full potential with our detailed and easily accessible Manual.

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SIPROTEC, 7SD5, Manual

C53000-G1176-C169-5, Release date 02.2011

9

Contents

1

Introduction. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .21

1.1

Overall Operation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .22

1.2

Application Scope  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .25

1.3

Characteristics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .28

2

Functions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .35

2.1

General  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .37

2.1.1

Functional Scope . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .37

2.1.1.1

Configuration of the Scope of Functions  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .37

2.1.1.2

Control of the Main Protection Functions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .38

2.1.1.3

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .38

2.1.1.4

Settings  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .42

2.1.2

General Power System Data (Power System Data 1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .44

2.1.2.1

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .44

2.1.2.2

Settings  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .53

2.1.3

Change Group . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .54

2.1.3.1

Purpose of the Setting Groups . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .54

2.1.3.2

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .54

2.1.3.3

Settings  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .55

2.1.3.4

Information List. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .55

2.1.4

General Protection Data (Power System Data 2)  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .55

2.1.4.1

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .55

2.1.4.2

Settings  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .68

2.1.4.3

Information List. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .72

2.2

Protection Data Interfaces and Protection Data Topology . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .74

2.2.1

Functional Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .74

2.2.1.1

Protection Data Topology / Protection Data Communication . . . . . . . . . . . . . . . . . . . . . . . . . . .74

2.2.2

Operating Modes of the Differential Protection  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .79

2.2.2.1

Mode: Log Out Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .79

2.2.2.2

Differential Protection Test Mode . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .81

2.2.2.3

Differential Protection Commissioning Mode . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .83

2.2.3

Protection Data Interfaces . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .84

2.2.3.1

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .84

2.2.3.2

Settings  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .88

2.2.3.3

Information List. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .89

2.2.4

Differential Protection Topology . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .90

2.2.4.1

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .90

2.2.4.2

Settings  . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .92

2.2.4.3

Information List. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .92

Summary of Contents for SIPROTEC

Page 1: ... Differential Protection with Distance Protection 7SD5 V 4 70 Manual C53000 G1176 C169 5 Preface Contents Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Appendix A Literature Glossary Index ...

Page 2: ...ions We appreciate any suggestions for improvement We reserve the right to make technical improvements without notice Document Version V04 70 01 Release date 02 2011 Copyright Copyright Siemens AG 2011 All rights reserved Dissemination or reproduction of this document or evaluation and communication of its contents is not authorized except where ex pressly permitted Violations are liable for damag...

Page 3: ... 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 with Distance Protection 7SD5 firmware version V 4 70 Indication of Conformity This product complies with the directive of the Council of the European Communities on the approximation of the laws of the Membe...

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

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

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

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

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

Page 9: ...tes 54 2 1 3 3 Settings 55 2 1 3 4 Information List 55 2 1 4 General Protection Data Power System Data 2 55 2 1 4 1 Setting Notes 55 2 1 4 2 Settings 68 2 1 4 3 Information List 72 2 2 Protection Data Interfaces and Protection Data Topology 74 2 2 1 Functional Description 74 2 2 1 1 Protection Data Topology Protection Data Communication 74 2 2 2 Operating Modes of the Differential Protection 79 2 ...

Page 10: ...al 119 2 5 1 3 Calculation of the Impedances 124 2 5 1 4 Setting Notes 132 2 5 1 5 Settings 141 2 5 1 6 Information List 144 2 5 2 Distance Protection with Quadrilateral Characteristic optional 146 2 5 2 1 Method of Operation 146 2 5 2 2 Setting Notes 152 2 5 2 3 Settings 160 2 5 3 Distance Protection with MHO Characteristic optional 163 2 5 3 1 Functional Description 163 2 5 3 2 Setting Notes 170...

Page 11: ...r Zero Infeed 211 2 7 14 Setting Notes 212 2 7 15 Settings 215 2 7 16 Information List 215 2 8 Earth Fault Protection in Earthed Systems optional 217 2 8 1 Functional Description 217 2 8 2 Setting Notes 234 2 8 3 Settings 244 2 8 4 Information List 248 2 9 Teleprotection for Earth Fault Protection optional 249 2 9 1 General 249 2 9 2 Directional Comparison Pickup 250 2 9 3 Directional Unblocking S...

Page 12: ...mmands and Messages 287 2 13 1 Functional Description 287 2 13 2 Information List 288 2 14 Instantaneous High Current Switch onto Fault Protection SOTF 290 2 14 1 Functional Description 290 2 14 2 Setting Notes 292 2 14 3 Settings 294 2 14 4 Information List 294 2 15 Sensitive Earth Flt comp isol starp 295 2 15 1 Method of Operation 295 2 15 2 Setting Notes 298 2 15 3 Settings 301 2 15 4 Informati...

Page 13: ...lure Protection 396 2 22 1 Functional Description 396 2 22 2 Setting Notes 408 2 22 3 Settings 412 2 22 4 Information List 413 2 23 Thermal Overload Protection 414 2 23 1 Method of Operation 414 2 23 2 Setting Notes 415 2 23 3 Settings 417 2 23 4 Information List 417 2 24 Monitoring Functions 418 2 24 1 Measurement Supervision 418 2 24 1 1 Hardware Monitoring 418 2 24 1 2 Software Monitoring 420 2...

Page 14: ... 2 25 1 4 Pickup Logic of the Entire Device 451 2 25 1 5 Tripping Logic of the Entire Device 452 2 25 2 Circuit Breaker Test 457 2 25 2 1 Functional Description 457 2 25 2 2 Information List 458 2 25 3 Device 459 2 25 3 1 Command Dependent Messages 459 2 25 3 2 Switching Statistics 460 2 25 3 3 Setting Notes 460 2 25 3 4 Settings 461 2 25 3 5 Information List 461 2 25 4 EN100 Modul 1 463 2 25 4 1 ...

Page 15: ...ation List 476 2 26 6 Measured Values Constellation 477 2 26 6 1 Functional Description 477 2 26 7 Oscillographic Fault Records 478 2 26 7 1 Functional Description 478 2 26 7 2 Setting Notes 478 2 26 7 3 Settings 479 2 26 7 4 Information List 479 2 26 8 Demand Measurement Setup 480 2 26 8 1 Long Term Average Values 480 2 26 8 2 Setting Notes 480 2 26 8 3 Settings 480 2 26 8 4 Information List 481 ...

Page 16: ...27 4 1 Information List 493 3 Mounting and Commissioning 495 3 1 Mounting and Connections 496 3 1 1 Configuration Information 496 3 1 2 Hardware Modifications 501 3 1 2 1 General 501 3 1 2 2 Disassembly 503 3 1 2 3 Switching Elements on Printed Circuit Boards 506 3 1 2 4 Interface Modules 517 3 1 2 5 Reassembly 521 3 1 3 Mounting 521 3 1 3 1 Panel Flush Mounting 521 3 1 3 2 Rack Mounting and Cubic...

Page 17: ...e Tripping 564 3 3 15 Testing User defined Functions 564 3 3 16 Trip and Close Test with the Circuit Breaker 565 3 3 17 Switching Test of the Configured Operating Equipment 565 3 3 18 Triggering Oscillographic Recording for Test 566 3 4 Final Preparation of the Device 567 4 Technical Data 569 4 1 General 571 4 1 1 Analog Inputs 571 4 1 2 Auxiliary Voltage 572 4 1 3 Binary Inputs and Outputs 573 4 ...

Page 18: ...7 1 Panel Flush Mounting and Cubicle Mounting Size 1 2 637 4 27 2 Panel Flush Mounting and Cubicle Mounting Size 1 1 638 4 27 3 Panel Surface Mounting Housing Size 1 2 639 4 27 4 Panel Surface Mounting Housing Size 1 1 639 A Appendix 641 A 1 Ordering Information and Accessories 642 A 1 1 Ordering Information 642 A 1 1 1 Ordering Code MLFB 642 A 1 2 Accessories 648 A 2 Terminal Assignments 652 A 2 ...

Page 19: ...Contents SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 19 Literature 755 Glossary 757 Index 769 ...

Page 20: ...Contents SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 20 ...

Page 21: ...ne Differential Protection with Distance Protection SIPROTEC 4 7SD5 is introduced in this chapter You are provided with an overview of the field of application characteristics and functional scope of the device 7SD5 1 1 Overall Operation 22 1 2 Application Scope 25 1 3 Characteristics 28 ...

Page 22: ...the device Analog inputs The measuring inputs MI transform the currents and voltages from the instrument transformers and match them to the internal signal levels for processing in the device The device has 4 current and 4 voltage inputs Three current inputs are provided for the input of the phase currents a further input I4 can be used to measure the earth current current transformer starpoint or...

Page 23: ...eceived transmission protocol synchronisation of the differential protection values and summing up of the differential currents and charge currents monitoring of the communication with the other devices of the line protection system Interrogation of threshold values and time sequences Processing of signals for the logic functions Decisions for trip and close commands Recording messages fault data ...

Page 24: ...ect during commissioning checking and also during operation using a standard browser via a communication network This function is supported by a comprehensive WEB Monitor which has been optimised especially for the line protection system Protection data interfaces The protection data interfaces are a particular case Depending on the model there are one or two protection data interfaces available V...

Page 25: ... the protected zone exchange measuring information via protection data in terfaces using dedicated communication links usually fibre optic cables or a communication network provided that they operate with differential protection The distance protection can exchange measuring information via teleprotection functions with conventional connections contacts or transmit it through fast command channels...

Page 26: ...rotection has three definite time overcurrent stages and one inverse time stage a number of characteristics according to various standards is available for the inverse time stage Depending on the order variant the short circuit protection functions can also trip single pole They may co operate with an integrated automatic reclosure function optionally with which single pole three pole or single an...

Page 27: ...ions and measured values issuing control commands To establish an extensive communication with other digital operating control and memory components the device may be provided with further interfaces depending on the order variant The service interface can be operated via the RS232 or RS485 interface and also allows communication via modem For this reason remote operation is possible via PC and th...

Page 28: ... extreme stability against load jumps and power swings Phase selective measurement ensures that the pickup sensitivity is independent of the fault type Suited for transformers in the protected zone order variant Detection of high resistance weak current faults due to high sensitivity of the protection functions Insensitive to inrush and charging currents also for transformers in the protected zone...

Page 29: ...uring systems for each distance zone Six distance zones selectable in forward or reverse direction or non directional one can be graded as an overreach zone Nine time stages for the distance zones Direction determination with polygon or polarization with MHO characteristic is done with unfaulted loop voltages and voltage memory thereby achieving unlimited directional sensitivity not affected by ca...

Page 30: ...he inverse time stage can also be set as fourth definite time stage High sensitivity from 3 mA on depending on the version Phase current restraint against error currents during current transformer saturation Second harmonic inrush restraint Optional earth fault protection with voltage dependent tripping time or with zero sequence power inverse time tripping Each stage can be set to be non directio...

Page 31: ...cted object with the magnitude and phase Transmission of up to 4 fast commands to all remote ends order option Transmission of up to 24 additional binary signals to all remote ends order option Time Overcurrent Protection Selectable as emergency function during a failure of the main protection function s due to a failure of the data communication and or the measuring voltages or as backup function...

Page 32: ... energized state before reclosing Closing at asynchronous system conditions with prediction of the synchronization time Settable minimum and maximum voltage Verification of the synchronous conditions or de energized state also possible before the manual closing of the circuit breaker with separate limit values Also measurement via transformer Measuring voltages optionally phase phase or phase eart...

Page 33: ...ing Start by trip command of every internal protection function Start by external trip functions possible Single stage or two stage Short dropout and overshoot times End fault protection and pole discrepancy monitoring possible Thermal Overload Protection Provides thermal replica of the current heat losses of the protected object R m s measurement of all three phase currents Adjustable thermal and...

Page 34: ...ailure using Fuse Failure Monitor Additional Functions Battery buffered real time clock which may be synchronized via a synchronization signal e g DCF77 IRIG B GPS via satellite receiver binary input or system interface Automatic time synchronization between the devices at the ends of the protected object via the protection data transmission Continuous calculation and display of operational measur...

Page 35: ...for Distance Protection optional 187 2 8 Earth Fault Protection in Earthed Systems optional 217 2 9 Teleprotection for Earth Fault Protection optional 249 2 10 Restricted Earth Fault Protection optional 265 2 11 Measures for Weak and Zero Infeed 273 2 12 Direct Local Trip 285 2 13 Transmission of Binary Commands and Messages 287 2 14 Instantaneous High Current Switch onto Fault Protection SOTF 290...

Page 36: ...Functions 2 SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 36 2 26 Additional Functions 464 2 27 Command Processing 486 ...

Page 37: ...you inform the device Section 2 1 2 of the properties of the main protected object This comprises e g nominal system data nominal data of instrument transformers po larity and connection type of measured values The above information is sufficient to describe the protected object to the device s main protection function i e the differential protection For the other protection functions e g backup d...

Page 38: ... differential protection relay In mode 3 the differential protection is not configured address 112 DIFF PROTECTION Disabled the dis tance protection operates as main protection provided that it is activated 2 1 1 3 Setting Notes Configuring the functional scope The scope of functions with the available options is set in the Functional Scope dialog box to match plant re quirements Most settings are...

Page 39: ...1 Protection Data Topology provides more information The number of devices address 147 NUMBER OF RELAY must match the number of the measuring points at the borders of the object to be protected Please observe that only current transformer sets that limit the pro tected object are counted The line in Figure 2 1 for instance has three measuring points and thus three devices because it is limited by ...

Page 40: ...led the distance protection function and all associated functions will not be available If a pickup of zone Z1 of the distance protection shall be possible only after exceeding an additional current threshold value set the parameter 119 Iph Z1 to Enabled Select the setting Disabled if the additional threshold value is not required Please note that the power swing supplement see also Section 2 6 on...

Page 41: ... remote end The number of cycles must however be configured at least in one of the line ends which must have a reliable infeed The other end or other ends if there are more than two line ends may operate with adaptive dead time Section 2 17 provides detailed information on this topic The AR control mode at address 134 allows a total of four options On the one hand it can be determined whether the ...

Page 42: ...ble and routed for this purpose For double ended fault location address 3807 two ended must be set to ON Please note that address 160 L sections FL is used for the specification of the number of sections into which your line length is divided e g cable over head line For the trip circuit supervision set at address 140 Trip Cir Sup the number of trip circuits to be monitored 1 trip circuit 2 trip c...

Page 43: ... AR cycles 3 AR cycles 4 AR cycles 5 AR cycles 6 AR cycles 7 AR cycles 8 AR cycles ADT Disabled Disabled Auto Reclose Function 134 AR control mode Pickup w Tact Pickup w o Tact Trip w Tact Trip w o Tact Trip w o Tact Auto Reclose control mode 135 Synchro Check Disabled Enabled Disabled Synchronism and Voltage Check 136 FREQUENCY Prot Disabled Enabled Disabled Over Underfrequency Protection 137 U O...

Page 44: ...he wye connected current transformers is specified the fol lowing figure also goes for only two current transformers The setting determines the measuring direction of the device forward line direction A change in this setting also results in a polarity reversal of the earth current inputs IE or IEE 142 Therm Overload Disabled Enabled Disabled Thermal Overload Protection 143 TRANSFORMER NO YES NO T...

Page 45: ...sor system cannot be started Correct entry of the primary data is a prerequisite for the correct computation of operational measured values with primary magnitude If the settings of the device are performed with primary values using DIGSI these primary data are an indispensable requirement for the correct function of the device The differential protection is designed such that it can operate witho...

Page 46: ...additional U4 transformer must be connected to a feeder voltage If the transformation ratio differs this can be adapted with the setting in address 215 Usy1 Usy2 ratio In address 212 Usy2 connection the type of voltage connected to measuring point Usy2 for synchronism check is set The device then automatically selects the voltage at measuring point Usy1 If the two measuring points used for synchro...

Page 47: ...onnected to the set of current trans formers Various possibilities exist for the fourth current input I4 Connection of the I4 input to the earth current in the starpoint of the set of current transformers on the pro tected feeder normal connection Address 220 is then set to I4 transformer In prot line and address 221 I4 Iph CT 1 Connection of the I4 input to a separate earth current transformer on...

Page 48: ...e polarisation of the directional earth fault protection Address 220 is then set to I4 transformer IY starpoint and address 221 I4 Iph CT is accord ing to transformation 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...

Page 49: ...etermines the duration of the trip pulse when a circuit breaker test is initiated via the device This parameter can only be altered using DIGSI under Additional Set tings In address 241 the maximum close command duration TMax CLOSE CMD is set It applies to all close com mands issued by the device It also determines the length of the close command pulse when a circuit breaker test cycle is issued v...

Page 50: ...en of the current transformers VA at rated current P actually connected burden devices secondary lines VA at rated current Usually the internal burden of the current transformers is stated in the test report If it is unknown it can be roughly calculated from the DC resistance Ri of the secondary winding Pi Ri IN 2 The ratio between operational accuracy limit factor and rated accuracy limit factor ...

Page 51: ...se is assumed i e the current as is the case with single phase faults flows back and forth via the secondary lines factor 2 From that the power for nominal current IN 5 A is calculated Pl 0 175 Ω 5 A 2 4 375 VA The entire connected burden consists of the burden of the incoming lines and the burden of the device P 4 375 VA 0 3 VA 4 675 VA Thus the ratio of the accuracy limit factors is as follows C...

Page 52: ...he best way is to treat it like an additional current transformer error Calculate the maximum fault current at the limits of the control range and add it referred to the mean current of the control range to the current transformer errors for the addresses 253 and 254 Perform this correction only at the end facing the regulated winding of the power transformer Calculation example Transformer YNd5 3...

Page 53: ...transf Usy2 transf Ux transformer Not connected U4 voltage transformer is 211 Uph Udelta 0 10 9 99 1 73 Matching ratio Phase VT To Open Delta VT 212 Usy2 connection L1 E L2 E L3 E L1 L2 L2 L3 L3 L1 L1 E VT connection for Usy2 214A ϕ Usy2 Usy1 0 360 0 Angle adjustment Usy2 Usy1 215 Usy1 Usy2 ratio 0 50 2 00 1 00 Matching ratio Usy1 Usy2 220 I4 transformer Not connected In prot line In paral line IY...

Page 54: ...setting groups are stored in the relay Only one setting group may be active at a given time 2 1 3 2 Setting Notes General If multiple setting groups are not required Group A is the default selection Then the rest of this section is not applicable If multiple setting groups are desired the setting group change option must be set to Grp Chge OPTION Enabled in the relay configuration of the functiona...

Page 55: ...the device on the primary rated voltage phase to phase of the equipment to be protected This setting influences the displays of the operational measured values in The primary rated current address 1104 FullScaleCurr is that of the protected object For cables the thermal continuous current loading capacity can be used as a basis For overhead lines the nominal current is usually not defined Here it ...

Page 56: ...transformer winding facing the device However if a winding has a voltage control range do not use the rated voltage of that winding but the voltage that corresponds to the mean value of the currents at the ends of the control range of the tap changer In this way the fault currents caused by voltage control are minimised Calculation example Transformer YNd5 35 MVA 110 kV 25 kV Y winding with tap ch...

Page 57: ...l protection whereas address 1161 VECTOR GROUP U serves as a basis for the calculation of the measured voltages beyond the transformer At address 1163 TRANS STP IS you can enter whether the power transformer starpoint facing the device is earthed or not If the starpoint is earthed the device will eliminate the zero sequence current of the relevant side since this zero sequence current can otherwis...

Page 58: ...e Unit or in Ω miles if mile was selected as distance unit The corresponding line length is entered in address 1113 Line Length in kilometers or in miles If after entry of the reactance per unit of line length in address 1111 or of the line length in address 1113 the distance unit is changed in address 236 the line data must be entered again for the revised distance unit The capacitance per unit l...

Page 59: ...address 1111 the setting x 0 229 Ω km is entered The secondary per distance unit capacitance is therefore In address 1112 the setting c 0 015 µF km is entered Earth impedance ratio Setting of the earth to line impedance ratio is an essential prerequisite for the accurate measurement of the fault distance distance protection fault locator during earth faults This compensation is either achieved by ...

Page 60: ...s are calculated with primary or secondary values Calculation Example 110 kV overhead line 150 mm2 with the data R1 s 0 19 Ω km positive sequence impedance X1 s 0 42 Ω km positive sequence impedance R0 s 0 53 Ω km zero sequence impedance X0 s 1 19 Ω km zero sequence impedance where s line length For earth impedance ratios the following emerge The earth impedance residual compensation factor settin...

Page 61: ...ents from the K0 These earth impedance compensation factors are defined with their magnitude and angle which may be calculated with the line data using the following equation Where Z0 complex zero sequence impedance of the line Z1 complex positive sequence impedance of the line These values can be applied either to the entire line or as per unit of length values since the quotients are in dependen...

Page 62: ...o Z6 as seen from the relay location Note If a combination of values is set which is not recognized by the device it operates with preset values K0 1 e0 The information Dis ErrorK0 Z1 No 3654 or DisErrorK0 Z1 No 3655 appears in the event logs Level Arrangement The location of the centre phase of a level arrangement is determined in address 1124 center phase The compensation factor parameters C0 C1...

Page 63: ...here is in theory no additional distance protection or fault locator mea suring error when the parallel line compensation is used The setting in address 1128 RATIO Par Comp is therefore only relevant for earth faults outside the protected feeder It provides the current ratio IE IEP for the earth current balance of the distance protection in Figure 2 4 for the device at location II above which com ...

Page 64: ...exceeded when the circuit breaker pole is open If parasitic currents e g through induction can be excluded when the circuit breaker is open this setting may be very sensitive Otherwise this setting must be increased Usually the pre setting is sufficient This parameter can only be altered in DIGSI at Display Additional Settings The residual voltage PoleOpenVoltage which will definitely not be excee...

Page 65: ...rgisation SI Time Man Cl address 1150 is the time following manual closure during which a possible influence on the protection functions becomes effective e g the switch on pickup threshold for the differential protection or the increased reach for the distance protection This setting can only be made in DIGSI under Display Additional Settings Note For CB Test and automatic reclosure the CB auxili...

Page 66: ...osures are carried out If not tripping is always three pole The remainder of this margin heading is then irrelevant Address 1155 3pole coupling determines whether each tripping command resulting from pickup in more than phase is 3 pole or whether only each multi pole tripping command results in a three pole trip This setting is only relevant for versions with single pole and three pole tripping an...

Page 67: ... picks up as with L1 L2 E i e as with a multi phase fault Figure 2 6 Multiple fault on a double circuit line next to a generator Address 1156 Trip2phFlt determines that the short circuit protection functions perform only a single pole trip in case of isolated two phase faults clear of ground provided that single pole tripping is possible and per mitted This allows a single pole reclose cycle for t...

Page 68: ... 0 0050 15 0000 Ω mi 0 2420 Ω mi x Line Reactance per length unit 5A 0 0010 3 0000 Ω mi 0 0484 Ω mi 1112 c 1A 0 000 100 000 µF km 0 010 µF km c capacit per unit line len µF km 5A 0 000 500 000 µF km 0 050 µF km 1112 c 1A 0 000 160 000 µF mi 0 016 µF mi c capacit per unit line len µF mile 5A 0 000 800 000 µF mi 0 080 µF mi 1113 Line Length 0 1 1000 0 km 100 0 km Line Length 1113 Line Length 0 1 650...

Page 69: ...ore SOTF 1134 Line Closure only with ManCl I OR U or ManCl CB OR I or M C I or Man Close I or Man Close Recognition of Line Clo sures with 1135 Reset Trip CMD CurrentOpenPole Current AND CB Pickup Reset CurrentOpenPole RESET of Trip Command 1136 OpenPoleDetect OFF Current AND CB w measurement w measurement open pole detector 1140A I CTsat Thres 1A 0 2 50 0 A 20 0 A CT Saturation Threshold 5A 1 0 2...

Page 70: ...les 62 1 Miles S1 Line length in kilome ter 6008 S1 center ph unknown sym Phase 1 Phase 2 Phase 3 unknown sym S1 center phase 6009 S1 XE XL 0 33 10 00 1 00 S1 Zero seq compensat ing factor XE XL 6010 S1 RE RL 0 33 10 00 1 00 S1 Zero seq compensat ing factor RE RL 6011 S1 K0 0 000 4 000 1 000 S1 Zero seq compensat ing factor K0 6012 S1 angle K0 180 00 180 00 0 00 S1 Zero seq compensat ing angle of ...

Page 71: ...eder reactance per mile x 5A 0 0010 3 0000 Ω mi 0 0484 Ω mi 6043 S3 c 1A 0 000 100 000 µF km 0 010 µF km S3 feeder capacitance c in µF km 5A 0 000 500 000 µF km 0 050 µF km 6043 S3 c 1A 0 000 160 000 µF mi 0 016 µF mi S3 feeder capacitance c in µF mile 5A 0 000 800 000 µF mi 0 080 µF mi 6044 S3 Line length 0 1 1000 0 km 100 0 km S3 Line length in kilome ter 6044 S3 line length 0 1 650 0 Miles 62 1...

Page 72: ...82 Only 1ph AR SP External AR programmed for 1phase only 383 Enable ARzones SP Enable all AR Zones Stages 385 Lockout SET SP Lockout SET 386 Lockout RESET SP Lockout RESET 410 CB1 3p Closed SP CB1 aux 3p Closed for AR CB Test 411 CB1 3p Open SP CB1 aux 3p Open for AR CB Test 501 Relay PICKUP OUT Relay PICKUP 502 Relay Drop Out OUT Relay Drop Out 503 Relay PICKUP L1 OUT Relay PICKUP Phase L1 504 Re...

Page 73: ...s coupled 3phase 561 Man Clos Detect OUT Manual close signal detected 562 Man Close Cmd OUT CB CLOSE command for manual closing 563 CB Alarm Supp OUT CB alarm suppressed 590 Line closure OUT Line closure detected 591 1pole open L1 OUT Single pole open detected in L1 592 1pole open L2 OUT Single pole open detected in L2 593 1pole open L3 OUT Single pole open detected in L3 No Information Type of In...

Page 74: ... 2 1 Functional Description 2 2 1 1 Protection Data Topology Protection Data Communication Protection Data Topology For a standard layout of lines with two ends you require one protection data interface for each device The protection data interface is named PI 1 see also Figure 2 7 When configuring the functional scope Section 2 1 1 the corresponding protection data interface must have been config...

Page 75: ...ex 3 at PI 1 The example shows that the indexing of the devices does not neces sarily have to correspond to the sequence of the communication chain Which protection data interface is con nected to which protection data interface is irrelevant One device with one protection data interface at each end of the chain is sufficient Figure 2 9 Differential protection for four ends with chain topology Fig...

Page 76: ...e of the optical fibre refer to Chapter 4 Different types of communication modules can be installed in the devices For ordering information refer to Appendix under Ordering Information and Accesso ries If a communication converter is used the device and the communication converter are linked with an FO5 module via optical fibres The converter itself is available in different versions allowing to c...

Page 77: ...ils Establishing the protection data communication When the devices of a differential protection system are linked to each other and switched on the devices com municate by themselves The successful connection is indicated e g with Rel2 Login when device 1 has detected device 2 Each device of a differential protection system informs each device of the successful pro tection data communication Addi...

Page 78: ...the communication A corresponding alarm is output e g PI1 Datafailure No 3230 for protection data interface 1 Otherwise the same reactions apply as for the disturbance Transmission time jumps that for example can occur in case of switchover in the communication network are recognized e g PI1 jump No 3254 for interface 1 and corrected by the devices The differential protec tion system continues to ...

Page 79: ...ology however only the devices at the ends of the chain can be logged out It is also possible to successively log several devices out of the line protection system It must observed that the logout always has to start from the devices at the end of the remaining chain topology If all devices of a line protection system except one are logged out the remaining device continues to operate in different...

Page 80: ...out ON No 3484 is generated According to the request source either the indication Logout ON off ON No 3459 or Logout ON offBI ON No 3460 is output As soon as a requirement is not met the device is not logged out If the device is to be logged on to the line protection system Logout off or Logout OFF the following is checked Is the local circuit breaker open Is the device not operating in differenti...

Page 81: ...ces are set to zero The local device only evaluates the locally measured currents interprets them as differential current but does not send them to the other devices This enables to measure the thresholds of the differential protection Moreover the test mode prevents the genera tion of an intertrip signal in the local device by tripping of the differential protection If the device is still connect...

Page 82: ...he selected way When deactivating the test mode via the binary inputs a delay time of 500 ms becomes effective The following figures show possible variants for controlling the binary inputs If a switch is used for the control Figure 2 16 it has to be observed that binary input Test Diff ON No 3197 is parameterised as NO contact and that binary input Test Diff OFF No 3198 is parameterised as NC con...

Page 83: ... device on which it was activated The commissioning mode can be activated deactivated as follows Using the integrated keypad Menu Control Taggings Set Commissioning mode Via binary inputs No 3260 Comm Diff ON No 3261 Comm Diff OFF if this was allocated In DIGSI with Control Taggings Diff Commissioning mode Principle of function In the following the logic is shown in a simplified way Figure 2 17 Lo...

Page 84: ...vating deactivating differential protection commissioning mode 1 Binary input as NO contact 2 Binary input as NC contact 2 2 3 Protection Data Interfaces 2 2 3 1 Setting Notes General Information about Interfaces The protection data interfaces connect the devices with the communication media The communication is per manently monitored by the devices Address 4509 T DATA DISTURB defines after which ...

Page 85: ...ault value that does not exceed the usual delay of communication networks This parameter can only be set in DIGSI at Display Additional Settings If it is exceeded during operation for example because of switchover to a dif ferent transmission route the message PI1 TD alarm No 3239 will be issued The protection data in terface and the differential protection continue being in operation Increased tr...

Page 86: ...nchronisation PI1 SYNCMODE TEL or GPS means that the differential protection will be enabled immediately once the connection has been re established data telegrams are received The differential protection works with the value paramterized at address 4506 PROT 1 UNSYM until the synchronisation has been completed As soon as both stations can receive GPS signals and the communication connection has b...

Page 87: ... changed under Additional Settings GPS synchronisation optional For the protection data interface the synchronisation via GPS can be switched ON or OFF at address 4801 GPS SYNC GPS synchronisation means the use of a 1 pulse per second signal 1 PPS This signal is generated by an external GPS receiver The 1 PPS signal is connected to port A of the device see Chapter 3 Table 3 12 The 1 PPS signal has...

Page 88: ... disturbance alarm 4510 T DATAFAIL 0 0 60 0 sec 6 0 sec Time del for transmission failure alarm 4511 PI1 SYNCMODE TEL and GPS TEL or GPS GPS SYNC OFF TEL and GPS PI1 Synchronizationmode 4512 Td ResetRemote 0 00 300 00 sec 0 00 sec Remote signal RESET DELAY for comm fail 4513A PROT1 max ERROR 0 5 20 0 1 0 Prot 1 Maximal permissible error rate 4515A PI1 BLOCK UNSYM YES NO YES Prot 1 Block due to uns...

Page 89: ...s between common parameters 3236 PI1 PI2 error OUT Different PI for transmit and receive 3239 PI1 TD alarm OUT Prot Int 1 Transmission delay too high 3240 PI2 TD alarm OUT Prot Int 2 Transmission delay too high 3243 PI1 with VI Prot Int 1 Connected with relay ID 3244 PI2 with VI Prot Int 2 Connected with relay ID 3245 GPS failure SP GPS failure from external 3247 GPS loss OUT GPS local pulse loss ...

Page 90: ...s thus also for several protected objects can be executed via the same communication system Please make sure that the possible communication connections and the existing interfaces are in accordance with each other If not all devices are equipped with two protection data interfaces those with only one protec tion data interface must be located at the ends of the communication chain A ring topology...

Page 91: ...master The number of configured devices must be identical in all devices During startup of the protection system the above listed conditions are checked If one of these conditions is not yet fulfilled the differential protection does not operate The device then issues one of the following error messages DT inconsistent Device Table contains two or more identical device ident numbers DT unequal Dif...

Page 92: ...ut state ON 3453 Logout OFF SP Logout state OFF 3457 Ringtopology OUT System operates in a closed Ringtopology 3458 Chaintopology OUT System operates in a open Chaintopology 3459 Logout ON off IntSP Logout state ON OFF 3460 Logout ON offBI IntSP Logout state ON OFF via BI 3464 Topol complete OUT Communication topology is complete 3475 Rel1Logout IntSP Relay 1 in Logout state 3476 Rel2Logout IntSP ...

Page 93: ...ion Basic principle with two ends The differential protection is based on current comparison It makes use of the fact that e g a line section L Figure 2 22 always carries the same current i dashed line at its two ends in healthy operation This current flows into one side of the considered zone and leaves it again on the other side A difference in current is a clear indication of a fault within thi...

Page 94: ...ds the infor mation on its intensity and phase relation to the opposite end The interface for this communication between protection devices is called protection data interface As a result the currents can be added up and processed in each device Figure 2 24 Differential protection for a line with two ends In case of more than two ends a communication chain is built up by which each device is infor...

Page 95: ...suring errors caused by the response characteristic of the current transformers and the input circuits of the devices Transmission errors such as signal jitters can also cause deviations of the measured quantities As a result of all these influences the total sum of all currents processed in the devices in healthy operation is not exactly zero Therefore the differential protection is restrained ag...

Page 96: ...ed by estimating the possible local transformer errors from the data of the local current trans formers and the intensity of the locally measured currents see Figure 2 27 The current transformer data have been parameterized in the power system data 1 Section 2 1 2 1 under margin heading Current Transformer Characteristic and apply to each individual device Since each device transmits its estimated...

Page 97: ...um of the restraining quan tities It is due to the self restraint that the differential protection always operates with the maximum possible sensi tivity since the restraining quantities automatically adapt to the maximum possible errors In this way also high resistance faults with high load currents at the same time can be detected effectively Using GPS synchroni sation the self restraint when us...

Page 98: ...on equal to the charging cur rent With active charging current compensation it is very small In addition to the evaluation of the measured values of the phases the differential current for the zero sequence current 3I0 is also calculated I Diff 3I0 is not transmitted but calculated by means of the phase currents Each device calculates its own zero sequence current In addition a zero sequence curre...

Page 99: ... 7SD5 device to period 1 4 The calculated charge Q is a scalar value which is faster to determine and to transmit than a complex phasor The charges of all ends of the protected object are added in the same way as done with the current phasors of the differential protection Thus the total of the charges is available at all ends of the protected zone Immediately after a fault has occurred in the pro...

Page 100: ...to complete the differential protection ensuring a fast tripping for high current short circuits Normally the charge comparison is set higher than the nominal current For charge comparison it is irrelevant whether the charging current compensation is activated or not Blocking interblocking The distance protection provided that it is available and configured automatically takes over as protection f...

Page 101: ...tage picked up Figure 2 31 Pickup logic for the differential protection function As soon as the differential protection function registers a fault within its tripping zone the signal Diff Gen Flt general device pickup of the differential protection is issued For the differential protection function itself this pickup signal is of no concern since the tripping conditions are available at the same t...

Page 102: ...age T DELAY I DIFF Independently of this condition a single phase pickup can be blocked for a short time in order to bridge the transient oscillations on occurrence of a single earth fault in a resonant earthed system The signals thus processed are linked with the output signals Diff Gen TRIP Diff TRIP 1p L1 Diff TRIP 1p L2 Diff TRIP 1p L3 Diff TRIP L123 in the tripping logic of the device The sin...

Page 103: ...operational capacitance IC 3 63 10 6 UN fN CB s with IC Charging current to be calculated in A primary UNom Nominal voltage of the network in kV primary fN Nominal frequency of the network in Hz CB Per unit line length capacitance of the line in nF km or nF mile s Length of the line in km or miles For lines with multiple ends the total sum of all line sections is taken as the length Considering th...

Page 104: ...zed the con nection of a dead line at its end For the duration of the seal in time SI Time all Cl which was set in the general protection data at address 1132 Section 2 1 4 1 all devices are then switched over to this particular pickup sensitivity A setting to three to four times the steady state charging current usually ensures the stability of the protection during switch on of the line For swit...

Page 105: ...ion coil serves to compensate nearly the total earth fault current its nominal current can be approximately used as a basis The pickup thresholds are finally checked during commissioning Further information can be found in chapter Installation and Commissioning Pickup value when switching on the charge comparison If bushing transformers are used for a transformer in the protected line section stra...

Page 106: ...nd on transformers The transformer is located inside the differential protection zone Inrush restraint can be turned ON or OFF at address 2301 INRUSH REST It is based on the evaluation of the second harmonic which exists in the inrush current Ex works a ratio of 15 of the 2nd HARMONIC I2fN IfN is set under address 2302 which can normally be taken over However the com ponent required for restraint ...

Page 107: ...0 00 A 1 50 A 1217A T DELAY I DIFF 0 00 60 00 sec 0 00 sec I DIFF Trip time delay 1218 T3I0 1PHAS 0 00 0 50 sec 0 04 sec Delay 1ph faults comp isol star point 1219A I RELEASE DIFF 1A 0 10 20 00 A 0 0 00 A Min local current to release DIFF Trip 5A 0 50 100 00 A 0 0 00 A 1221 Ic comp OFF ON OFF Charging current compen sation 1224 IcSTAB IcN 2 0 4 0 2 5 Ic Stabilising Ic Nominal 1233 I DIFF 1A 0 8 10...

Page 108: ...ck OUT Diff Differential protection is blocked 3149 Diff OFF OUT Diff Diff protection is switched off 3176 Diff Flt 1p L1 OUT Diff Fault detection L1 only 3177 Diff Flt L1E OUT Diff Fault detection L1E 3178 Diff Flt 1p L2 OUT Diff Fault detection L2 only 3179 Diff Flt L2E OUT Diff Fault detection L2E 3180 Diff Flt L12 OUT Diff Fault detection L12 3181 Diff Flt L12E OUT Diff Fault detection L12E 31...

Page 109: ...3 CommDiffONoffBI IntSP Diff Commissioning state ON OFF via BI 3525 Diff block SP Differential protection blocking signal 3526 Diffblk rec PI1 OUT Differential blocking received at PI1 3527 Diffblk rec PI2 OUT Differential blocking received at PI2 3528 Diffblk sen PI1 OUT Differential blocking sending via PI1 3529 Diffblk sen PI2 OUT Differential blocking sending via PI2 No Information Type of In ...

Page 110: ...o that a simultaneous single pole auto reclosure is always possible provided that devices and circuit breakers are designed for single pole tripping 2 4 1 Functional Description Transmission circuit The transmit signal can originate from two sources Figure 2 33 If the parameter I TRIP SEND is set to YES each trip command of the differential protection is immediately routed to the transmission func...

Page 111: ...ected object whether the received signal is to trip at this particular end or not Figure 2 34 shows the logic diagram If the received signal is to cause the trip it will be forwarded to the tripping logic The tripping logic of the device see also Section 2 25 1 ensures if necessary that the conditions for single pole tripping are met e g single pole tripping permissible auto reclosure function rea...

Page 112: ... only any other desired signals can be transmitted as well After the binary input s have been activated the signals which are set to cause an alarm at the receiving end are transmitted These alarms can in turn execute any desired actions at the receiving end Another 24 transmission channels are available for the transmission of remote alarms and remote commands and 4 ad ditional fast transmission ...

Page 113: ...y stabilizes the transmission signal against dynamic interferences which may occur on the control cabling Address 1304 T ITRIP PROL BI is used to extend a signal after it has been effectively injected from an ex ternal source The reaction of a device when receiving an intertrip remote tripping signal is set at address 1302 I TRIP RECEIVE If it is supposed to cause tripping set the value Trip If th...

Page 114: ...ived at Prot Interface 2 L1 3509 ITrp rec PI2 L2 OUT I Trip Received at Prot Interface 2 L2 3510 ITrp rec PI2 L3 OUT I Trip Received at Prot Interface 2 L3 3511 ITrp sen PI1 L1 OUT I Trip Sending at Prot Interface 1 L1 3512 ITrp sen PI1 L2 OUT I Trip Sending at Prot Interface 1 L2 3513 ITrp sen PI1 L3 OUT I Trip Sending at Prot Interface 1 L3 3514 ITrp sen PI2 L1 OUT I Trip Sending at Prot Interfa...

Page 115: ...zone characteristics substan tially depend on whether the fault at hand is an earth fault or not The 7SD5 has a stabilized earth current mea surement a zero sequence current negative sequence current comparison as well as a displacement voltage measurement Furthermore special measures are taken to avoid a pickup for single earth faults in an isolated or resonant earthed system Earth Current 3I0 Fo...

Page 116: ...hreshold In earthed systems 3U0 Threshold it can be used as an additional criterion for earth faults For earthed systems the U0 criterion may be disabled by applying the setting Logical Combination for Earthed Systems The current and voltage criteria supplement each other as the displacement voltage increases when the zero sequence to positive sequence impedance ratio is large whereas the earth cu...

Page 117: ...nsated or isolated networks an earth pickup is only initiated after a pickup of the zero sequence current criterion It should be considered that the zero sequence voltage criterion with the parameter 1505 3U0 COMP ISOL is used for the confirmation of an earth pickup in case of double earth faults with current transformer saturation The 3I0 threshold is reduced in case of asymmetrical phase to phas...

Page 118: ...up as a result of the earth fault inception transients After a con figurable delay time T3I0 1PHAS the pickup is released again this is necessary to ensure that the distance protection is still able to detect a double earth fault with one base point on a dead end feeder If the phase to phase voltages are asymmetrical this indicates a double earth fault and the pickup is released immediately Figure...

Page 119: ...at address 117 Dis PICKUP Z quadrilat works implicitly i e the above mentioned operations are executed automatically as soon as a fault is detected in one of the distance zones Overcurrent Pickup Overcurrent pickup is a phase selective pickup procedure After numeric filtering the currents are monitored in each phase if a settable value is exceeded A signal is output for the phase s where the set t...

Page 120: ...irst requirement for every phase pickup is that the minimum current Iph is exceeded For the eval uation of phase to phase loops both relevant phase currents have to exceed this value Above this current the current pickup is voltage dependent with the slope being determined by the setting parameters U I and U I For short circuits with large currents the overcurrent pickup Iph is superimposed The bo...

Page 121: ...he phase to phase loops the sensitivity is particularly high for phase to phase faults In ex tensive compensated networks this selection is advantageous because it excludes pickup as a result of single earth faults on principle With two and three phase faults it automatically adapts to the prevailing infeed con ditions i e in weak infeed operation mode it becomes more current sensitive with strong...

Page 122: ...ate infeed Then the local measured voltage will only drop to a small extent in the event of a short circuit at the line end or in the back up range of the distance protection so that the phase angle between current and voltage is required as an additional criterion for fault detection The U I ϕ pickup is a per phase and per loop pickup mode It is crucial for the phase currents to exceed the pickup...

Page 123: ...s effect it is cut off by the overcurrent stage Iϕ The bold dots in Figure 2 42 mark the settings which determine the geometry of the current voltage characteristic The angle dependent area i e the area within the short circuit angle of the characteristic in Figure 2 42 can either be set to affect in forward direction in direction of line or in both directions Figure 2 42 U I ϕ characteristic Loop...

Page 124: ...mediately used for the calculation The fault evaluation is therefore always done with the measured values of the current fault condition Phase to Phase Loops To calculate the phase to phase loop for instance during a two phase short circuit L1 L2 Figure 2 43 the loop equation is IL1 ZL IL2 ZL UL1 E UL2 E with U I the complex measured quantities and Z R jX the complex line impedance The line impeda...

Page 125: ...ase measuring unit shown by the example of the L1 L2 loop Phase to Earth Loops For the calculation of the phase to earth loop for example during an L3 E short circuit Figure 2 45 it must be noted that the impedance of the earth return path does not correspond to the impedance of the phase Figure 2 45 Single phase earth fault fault loop ...

Page 126: ...rcuit voltage ϕL phase angle of the phase short circuit current ϕE phase angle of the earth short circuit current The factors RE RL and XE XL are dependent only on the line constants and no longer on the distance to fault The calculation of the phase to earth loops does not take place as long as the concerned phase is switched off during single pole dead time to avoid an incorrect measurement with...

Page 127: ...ine image the corresponding loop pick up is desig nated as a definitely valid loop If the impedances of more than one loop are now located within the range of the zone the smallest is still de clared to be a valid loop Furthermore all loops with an impedance that does not exceed the smallest loop im pedance by more than 50 are declared as being valid Loops with larger impedance are eliminated Thos...

Page 128: ... occurrence of earth faults especially in large resonant earthed systems large fault inception tran sient currents can appear that may evoke the earth current pickup In case of an overcurrent pick up there may also be a phase current pickup The 7SD5 features special measures against such spurious pickups With the occurrence of a double earth fault in isolated or resonant earthed systems it is suff...

Page 129: ... L1 L2 L3 ACYCLIC Cyclic L3 before L1 before L2 before L3 L3 L1 CYCLIC Cyclic L1 before L3 before L2 before L1 L1 L3 CYCLIC All loops are measured All loops Loop pickup Evaluated loop s Setting of parameter 1520 L1 E L2 E L1 L2 L2 E L3 E L2 L3 L1 E L3 E L3 L1 L1 E L3 E L3 E PHASE PREF 2phe L3 L1 ACYCLIC L1 E L2 E L1 L2 L2 E L3 E L2 L3 L1 E L3 E L3 L1 L1 E L3 E L1 E PHASE PREF 2phe L1 L3 ACYCLIC L1...

Page 130: ...t In some cases for example when the two feeders are terminated to different busbars and the location of the earth fault is on one of the remote busbars at B in Figure 2 48 an overreach may occur The parallel line compensation only applies to faults on the protected feeder For faults on the parallel line the compensation may not be carried out as this would cause severe overreach The relay located...

Page 131: ...fter the trip command If the fault type has not been recog nized completely during the valid measuring cycle and the other loops are only picked up during the next cycle an immediate blocking would lead to incomplete types of fault Figure 2 49 Logic diagram for the blocking of the distance protection Switching onto a fault If the circuit breaker is manually closed onto a short circuit the distance...

Page 132: ... the other pickup modes it is set at address 1911 Earth fault detection In systems with earthed starpoint the setting 3I0 Threshold address 1503 is set somewhat below the minimum expected earth fault current 3I0 is defined as the sum of the phase currents IL1 IL2 IL3 which equals the starpoint current of the set of current transformers In non earthed systems the setting value is rec ommended to be...

Page 133: ...he setting that you make here affects the differential protection function as well see also Section 2 3 2 under margin heading Delay Times Application with series compensated lines In applications for or in the proximity of series compensated lines lines with series capacitors address 1508 SER COMP is set to YES to ensure that the direction determination operates correctly in all cases The influ e...

Page 134: ...s also possible to evaluate Ø Ø loops only This ensures the highest accuracy for 2 phase to earth faults Finally it is possible to declare only the phase to earth loops as valid set ting Ø E loops only Double earth faults in non earthed systems In isolated or resonant earthed systems it must be guaranteed that the preference for double earth faults in whole galvanically connected systems is consis...

Page 135: ...also be blocked by the binary input 3610 BLOCK Z1 Trip This binary input allows for in stance to specify further blocking conditions relating to the interaction with the differential protection using CFC The effect of the binary input does not depend on the status of the differential protection Load range only for impedance pickup When using the impedance pickup function on long heavily loaded lin...

Page 136: ...ad Ø Ø 97 98 Ω primary 10 69 Ω secondary R load Ø E 97 98 Ω primary 10 69 Ω secondary The spread angle of the load trapezoid characteristic ϕ load Ø E address 1542 and ϕ load Ø Ø address 1544 must be greater approx 5 than the maximum arising load angle corresponding to the minimum power factor cosϕ Minimum power factor example cos ϕmin 0 63 ϕmax 51 Setting value ϕ load Ø Ø ϕmax 5 56 Calculation Ex...

Page 137: ...st be set For the calculation it is given as a ratio relative to the load current Imax calculated above Ratio between IE on healthy line and Imax when parallel line has a single pole open condition This ratio depends on the line length as well as on the source and line impedances If it is not possible to de termine this value from power system simulations a value between 0 4 for long double lines ...

Page 138: ...he unambiguous detection of earth faults via the earth fault detection function also see Section 2 5 1 Otherwise a mode using UPh E for all fault types may be useful address 1901 PROGAM U I LE Uphe LL Uphe accepting lesser sensitivity for earth free faults since the overcurrent stage Iph usually picks up there In networks with low resistance earthed starpoint the U I ϕ pickup should only come into...

Page 139: ...ctor of 1 2 the condition for maximum load current in respect to Iph still has to be observed Then the minimum current limit Iph address 1911 is set to below the minimum short circuit current approx 10 This also applies to the phase currents during earth faults or double earth faults At address 1930 1ph FAULTS you can select whether a phase to earth loop is selected in an earthed network for singl...

Page 140: ...ngle range ϕSC are set in address 1920 ϕ and 1921 ϕ The short circuit angle range ϕSC is located between these two angles Here too the required voltage settings according to the pickup mode see above are relevant The characteristic for the load angle range has to be set in a way that is just below the minimum expected op erating voltage at the maximum expected load current In the range of the shor...

Page 141: ... Threshold 1 100 V 5 V 3U0 threshold zero seq voltage pickup 1505 3U0 COMP ISOL 10 200 V V 3U0 pickup comp isol star point 1507A 3I0 Iphmax 0 05 0 30 0 10 3I0 pickup stabilisation 3I0 Iphmax 1508 SER COMP NO YES NO Series compensated line 1509A E F recognition 3I0 OR 3U0 3I0 AND 3U0 3I0 OR 3U0 criterion of earth fault rec ognition 1510 Start Timers on Dis Pickup on Zone Pickup on Dis Pickup Condit...

Page 142: ... 00 sec 0 00 sec T1 1phase delay for single phase faults 1606 T1 multi phase 0 00 30 00 sec 0 00 sec T1multi ph delay for multi phase faults 1615 T2 1phase 0 00 30 00 sec 0 30 sec T2 1phase delay for single phase faults 1616 T2 multi phase 0 00 30 00 sec 0 30 sec T2multi ph delay for multi phase faults 1617A Trip 1pole Z2 NO YES NO Single pole trip for faults in Z2 1625 T3 DELAY 0 00 30 00 sec 0 6...

Page 143: ... 20 70 V 48 V Undervoltage ph e at Iph 1914 Uph ph I 40 130 V 80 V Undervoltage ph ph at Iph 1915 Uph ph I 40 130 V 80 V Undervoltage ph ph at Iph 1916 Iphi 1A 0 10 8 00 A 0 50 A Iphi Pickup minimum current at phi 5A 0 50 40 00 A 2 50 A 1917 Uph e Iphi 20 70 V 48 V Undervoltage ph e at Iphi 1918 Uph ph Iphi 40 130 V 80 V Undervoltage ph ph at Iphi 1919A EFFECT ϕ forward reverse Forward forward rev...

Page 144: ... L1 3673 Dis Pickup L2 OUT Distance PICKUP L2 3674 Dis Pickup L3 OUT Distance PICKUP L3 3675 Dis Pickup E OUT Distance PICKUP Earth 3681 Dis Pickup 1pL1 OUT Distance Pickup Phase L1 only 3682 Dis Pickup L1E OUT Distance Pickup L1E 3683 Dis Pickup 1pL2 OUT Distance Pickup Phase L2 only 3684 Dis Pickup L2E OUT Distance Pickup L2E 3685 Dis Pickup L12 OUT Distance Pickup L12 3686 Dis Pickup L12E OUT D...

Page 145: ...is Z1 L23 OUT Distance Pickup Z1 Loop L23 3746 Dis Z1 L31 OUT Distance Pickup Z1 Loop L31 3747 Dis Z1B L1E OUT Distance Pickup Z1B Loop L1E 3748 Dis Z1B L2E OUT Distance Pickup Z1B Loop L2E 3749 Dis Z1B L3E OUT Distance Pickup Z1B Loop L3E 3750 Dis Z1B L12 OUT Distance Pickup Z1B Loop L12 3751 Dis Z1B L23 OUT Distance Pickup Z1B Loop L23 3752 Dis Z1B L31 OUT Distance Pickup Z1B Loop L31 3755 Dis P...

Page 146: ...he R X coordi nate system the directional characteristic however limits the tripping range to the desired quadrants refer to Direction determination below The R reach may be set separately for the phase to phase faults and the phase to earth faults to achieve a larger fault resistance coverage for earth faults if this is desired 3811 Dis TripZ1 1p OUT Distance TRIP single phase Z1 3813 Dis TripZ1B...

Page 147: ...ZL is used However depending on the quality of the measured values different computation techniques are used Immediately after fault inception the short circuit voltage is disturbed by transients The voltage memorised prior to fault inception is therefore used in this situation If even the steady state short circuit voltage during a close up fault is too small for direction determination an unfaul...

Page 148: ...this line e g closing onto an earthed line Figure 2 54 shows the theoretical steady state characteristic In practice the limits of the directional character istic when using memorized voltages is dependent on both the source impedance and the load transferred across the line prior to fault inception Accordingly the directional characteristic includes a safety margin with respect to the borders of ...

Page 149: ...e 2 55 shows the directional characteristic using quadrature or memorized voltage as well as taking the source impedance into account no load transfer As these voltages are equal to the corresponding generator voltage E and they do not change after fault inception the directional characteristic is shifted in the impedance diagram by the source impedance ZS1 E1 I1 For the fault location F1 Figure 2...

Page 150: ...see Figure 2 56 Figure 2 56 Voltage characteristic while a fault occurs after a series capacitor a without pickup of the protective spark gap b with pickup of the protective spark gap The distance protection function would thus detect a wrong fault direction The use of memorized voltages however ensures that the direction is correctly detected see Figure 2 57a Since the voltage prior to the fault ...

Page 151: ...oop information is also converted to phase segregated information Using the impedance pickup the calculated loop impedances are also assigned to the zone characteristics set for the distance protection but without consideration of an explicit fault detection scheme The pickup range of the distance protection is determined from the thresholds of the largest set polygon taking into consideration the...

Page 152: ...y T1B 1phase or T1B multi phase 2 5 2 2 Setting Notes Grading coordination chart It is recommended to initially create a grading coordination chart for the entire galvanically interconnected system This diagram should reflect the line lengths with their primary reactances X in Ω km For the reach of the distance zones the reactances X are the deciding quantity The first zone Z1 is usually set to co...

Page 153: ...ondary side of the current and voltage transformers In general Accordingly the reach for any distance zone can be specified as follows where NCT Current transformer ratio NVT Transformation ratio of voltage transformer Calculation Example 110 kV overhead line 150 mm2 with the following data s length 35 km R1 s 0 19 Ω km X1 s 0 42 Ω km R0 s 0 53 Ω km X0 s 1 19 Ω km Current Transformer 600 A 5 A Vol...

Page 154: ...nside the set resistance of the first zone The standard value for the arc voltage UArc is approx 2 5 kV per meter of arc length Example A maximum arc voltage of 8 kV is assumed for phase to phase faults line data as above If the minimum primary short circuit current is assumed to be 1000 A this corresponds to 8 Ω primary The resistance setting for the first zone including a safety margin of 20 wou...

Page 155: ...e no information is available on the current ratio a value of approx 3 can be assumed On radial feeders with negligible infeed from the opposite end this ratio is 0 RTF Effective tower footing resistance of the overhead line system Where no information is avail able on the amount of tower footing resistance a value of 3 Ω can be assumed for overhead lines with earth wire see also 5 The following r...

Page 156: ...sed up to R X 1 loop reach For larger R X settings a reduced grading factor for zone 1 can be calculated with the following formula see also 5 The reduced grading factor is calculated from GF Grading factor reach of zone Z1 in relation to the line length R Loop reach in R direction for zone Z1 R1 1 RE RL X Loop reach in X direction for zone Z1 X1 1 XE XL δU Voltage transformer angle error typical ...

Page 157: ...he X in tersection reach RE Z1 Ø E address 1604 for the R intersection applicable to phase to earth faults and delay time settings If a fault resistance at the fault location arc tower footing etc causes a voltage drop in the measured imped ance loop the phase angle difference between this voltage and the measured loop current may shift the deter mined fault location in X direction Parameter 1607 ...

Page 158: ...multiple phase faults in the first zone T1 1phase Address 1605 and T1 multi phase address 1606 The first zone is normally set to operate without additional time delay For the remaining zones the following correspondingly applies X Z2 address 1613 R Z2 Ø Ø address 1612 RE Z2 Ø E address 1614 X Z3 address 1623 R Z3 Ø Ø address 1622 RE Z3 Ø E address 1624 X Z4 address 1633 R Z4 Ø Ø address 1632 RE Z4...

Page 159: ...he above aspects Setting T5 to infinite prevents that this stage causes a trip Blocking of Zone Z1 If the main protection functions differential protection and distance protection operate in parallel the distance protection of Zone Z1 may pick up before the differential protection e g in the case of close up faults If this is desired the distance protection works as a booster stage for fast trippi...

Page 160: ...enable tripping of Z1 only above an increased phase current threshold value For this purpose you can define a separate minimum current for the zone Z1 under address 1608 Iph Z1 The pickup of zone Z1 is in this case only possible if the phase currents exceed this threshold value and are also above the threshold for enabling the distance measurement 1502 Minimum Iph 1910 Iph 1911 Iph 1916 Iphi Param...

Page 161: ...Z2 NO YES NO Single pole trip for faults in Z2 1621 Op mode Z3 Forward Reverse Non Directional Inactive Reverse Operating mode Z3 1622 R Z3 Ø Ø 1A 0 050 600 000 Ω 5 000 Ω R Z3 Resistance for ph ph faults 5A 0 010 120 000 Ω 1 000 Ω 1623 X Z3 1A 0 050 600 000 Ω 10 000 Ω X Z3 Reactance 5A 0 010 120 000 Ω 2 000 Ω 1624 RE Z3 Ø E 1A 0 050 600 000 Ω 10 000 Ω RE Z3 Resistance for ph e faults 5A 0 010 120 ...

Page 162: ... 120 000 Ω 0 300 Ω 1653 X Z1B 1A 0 050 600 000 Ω 3 000 Ω X Z1B Reactance 5A 0 010 120 000 Ω 0 600 Ω 1654 RE Z1B Ø E 1A 0 050 600 000 Ω 3 000 Ω RE Z1B Resistance for ph e faults 5A 0 010 120 000 Ω 0 600 Ω 1655 T1B 1phase 0 00 30 00 sec 0 00 sec T1B 1phase delay for single ph faults 1656 T1B multi phase 0 00 30 00 sec 0 00 sec T1B multi ph delay for multi ph faults 1657 1st AR Z1B NO YES NO Z1B enab...

Page 163: ...x independent and one additional controlled zone for each fault imped ance loop The basic shape of an MHO characteristic is shown in Figure 2 63 as an example of a zone The MHO characteristic is defined by the line of its diameter which intersects the origin of the coordinate system and the magnitude of the diameter which corresponds to the impedance Zr which determines the reach and by the angle ...

Page 164: ...ith the circumference The upper zenith which is determined by the reach setting Zr remains unchanged Immediately after fault inception the short circuit voltage is disturbed by transients the voltage memorized prior to fault inception is therefore used for po larization This causes a displacement of the lower zenith by an impedance corresponding to the memorized voltage refer to Figure 2 64 When t...

Page 165: ...alue Zr For the fault location F1 Figure 2 65a the short circuit is in the forward direction and the source impedance is in the reverse direction All fault locations right up to the device mounting location current transformers are clearly inside the MHO characteristic Figure 2 65b If the current is reversed the zenith of the circle diameter changes abruptly Figure 2 65c A reversed current I2 whic...

Page 166: ... for Ph E loops is greater than a 40 of the nominal voltage UN address 204 and greater than a 70 of UN for Ph Ph loops If there is no prefault voltage due to a sequential fault or energization onto a fault the memorized voltage can only be used for a limited time for reasons of accuracy For single pole faults and two pole faults without earth path component a voltage which is not involved in the f...

Page 167: ...ation voltage of the MHO characteristic consists of the currently measured voltage and the voltage measured before the occurrence of the fault it is possible that the distance protection function would detect a wrong fault direction To prevent spurious trippings or erroneous pickups a memory voltage proportion of up to 80 could be necessary This however would lead to a considerable increase of the...

Page 168: ...s the inversion of the direction result Assignment to tripping zones and zone pickup The assignment of measured values to the tripping zones of the MHO characteristic is done for each zone by determining the angles between two difference phasors ΔZ1 and ΔZ2 Figure 2 68 These phasors result from the difference between the two zeniths of the circle diameter and the fault impedance The zenith Zr corr...

Page 169: ... fault impedance of any loop is confidently measured inside the MHO characteristic of a distance zone the affected loop is designated as picked up The loop information is also converted to phase segregated information Another condition for pickup is that the dis tance protection may not be blocked or switched off completely Figure 2 69 shows these conditions The zones and phases of such a valid pi...

Page 170: ...o earth measurement address 116 Grading coordination chart It is recommended to initially create a grading coordination chart for the entire galvanically interconnected system This diagram should reflect the line lengths with their primary impedances Z in Ω km For the reach of the distance zones the impedances Z are the deciding quantities The first zone Z1 is usually set to cover 85 of the protec...

Page 171: ...atio NVT Transformation ratio of voltage transformers On long heavily loaded lines the MHO characteristic may extend into the load impedance range This is of no consequence as the pickup by overload is prevented by the load trapezoid Refer to margin heading Load Area in Section 2 5 1 Calculation Example 110 kV overhead line 150 mm2 with the following data s length 35 km R1 s 0 19 Ω km X1 s 0 42 Ω ...

Page 172: ...ss 1616 while tolerating a longer delay time for single phase faults with T2 1phase address 1615 The zone timers for the remaining zones are set with the parameters T3 DELAY address 1625 T4 DELAY address 1635 T5 DELAY address 1645 and T6 DELAY address 1665 If the device is provided with the capability to trip single pole single pole tripping is then possible in the zones Z1 and Z2 While single pol...

Page 173: ...rdance with the type of application usually to zero or a very small delay When used in conjunction with teleprotection comparison schemes the dependence on the fault detection must be considered refer to margin heading Distance Pro tection Prerequisites in Section 2 7 14 If the distance protection is used in conjunction with the internal or an automatic recloser it may be determined in address 165...

Page 174: ...sec 0 30 sec T2multi ph delay for multi phase faults 1617A Trip 1pole Z2 NO YES NO Single pole trip for faults in Z2 1625 T3 DELAY 0 00 30 00 sec 0 60 sec T3 delay 1635 T4 DELAY 0 00 30 00 sec 0 90 sec T4 delay 1645 T5 DELAY 0 00 30 00 sec 0 90 sec T5 delay 1655 T1B 1phase 0 00 30 00 sec 0 00 sec T1B 1phase delay for single ph faults 1656 T1B multi phase 0 00 30 00 sec 0 00 sec T1B multi ph delay ...

Page 175: ...everse Inactive Forward Operating mode Z1B ex tended zone 1752 ZR Z1B 1A 0 050 200 000 Ω 3 000 Ω ZR Z1B Impedance Reach 5A 0 010 40 000 Ω 0 600 Ω 1761 Op mode Z6 Forward Reverse Inactive Inactive Operating mode Z6 1762 ZR Z6 1A 0 050 200 000 Ω 15 000 Ω ZR Z6 Impedance Reach 5A 0 010 40 000 Ω 3 000 Ω 1771A Mem Polariz PhE 0 0 100 0 15 0 Voltage Memory polariza tion phase e 1772A CrossPolarizPhE 0 0...

Page 176: ...d measuring loop changes e g because an intermediate infeed is switched off It is also the preferred setting if other distance protection relays in the power system are working with this start timing Where grading of the delay times is especially important for instance if the fault location shifts from zone Z3 to zone Z2 the setting on Zone Pickup should be chosen The simplified zone logic is show...

Page 177: ...Functions 2 5 Distance Protection SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 177 Figure 2 71 Tripping logic for the 1st zone Figure 2 72 Tripping logic for the 2nd zone ...

Page 178: ... 7SD5 to trip single pole during two phase faults without earth connection in the overreach ing zone when single pole automatic reclosure is used As the device features an integrated teleprotection function release signals from this function may activate zone Z1B provided that the internal teleprotection signal transmission function has been configured to one of the available schemes with paramete...

Page 179: ...Functions 2 5 Distance Protection SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 179 Figure 2 75 Tripping logic for the controlled zone Z1B ...

Page 180: ...one that initiated the tripping is identified if single pole tripping is possible this is also signalled as shown in the zone logic diagrams Figures 2 71 to 2 75 The actual generation of the commands for the trip ping output relay is executed within the tripping logic of the entire device 2 5 4 2 Setting Notes The trip delay times of the distance stages and intervention options which are also proc...

Page 181: ...er with the new load balance of the system The distance protection registers large transient currents during the power swing and especially at the electrical centre small voltages Figure 2 76 Small voltages with simultaneous large currents apparently imply small impedances which again could lead to tripping by the distance protection In expansive networks with large transferred power even the stab...

Page 182: ...between two subsequent impedance values features a clear change in ΔR or ΔX In case of a fault the impedance vector jumps to the fault impedance without moving afterwards Trajectory uniformity During a power swing the ratio between two subsequent changes of ΔR or ΔX will not exceed a threshold A fault usually causes an abrupt jump of the impedance vector from the load impedance to the fault imped ...

Page 183: ...ied logic diagram for the power swing function is given This measurement is executed per phase A power swing signal will be generated if the measured impedance is inside the power swing polygon PPOL The power swing signal remains active until a fault occurs or until the power swing has de cayed The power swing detection can be blocked via the binary input No 4160 Pow Swing BLK Figure 2 79 Logic di...

Page 184: ... condition is desired the parameter PowerSwing trip address 2006 YES is set If the criteria for power swing detection are met the distance protection is initially blocked according to the configured program for power swing blocking to avoid tripping by the distance protection When the impedance vectors identified by the power swing detection exit the pickup characteristic APOL the sign of the R co...

Page 185: ...dress 120 during the configuration The 4 possible programs may be set in address 2002 P S Op mode as described in Section 2 6 All zones block Z1 Z1B block Z2 block or Z1 Z1B Z2 block Additionally the tripping function for unstable power swings asynchronism can be set with parameter PowerSwing trip address 2006 which should be set to YES if required presetting is NO In the event of power swing trip...

Page 186: ...er Swing Operating mode 2006 PowerSwing trip NO YES NO Power swing trip No Information Type of In formation Comments 4160 Pow Swing BLK SP BLOCK Power Swing detection 4163 P Swing unstab OUT Power Swing unstable 4164 Power Swing OUT Power Swing detected 4166 Pow Swing TRIP OUT Power Swing TRIP command 4167 Pow Swing L1 OUT Power Swing detected in L1 4168 Pow Swing L2 OUT Power Swing detected in L2...

Page 187: ...on is set with a normal grading characteristic If a trip command occurs in the first zone the other line end receives this information via a transmission channel There the received signal initates a trip either by activation of overreach zone Z1B or via a direct trip command 7SD5 allows PUTT Pickup Permissive Underreach Transfer Trip with Zone Acceleration Z1B PUTT Direct Underreach Transfer Trip ...

Page 188: ...e 1 pole automatic reclosure can be carried out reliably even if two 1 phase faults occur on different lines in the system The signal transmission schemes are also suited for three terminal lines teed feeders In this case a signal is transmitted from each of the three ends to each of the others in both directions If disturbances occur in the transmission path the teleprotection supplement may be b...

Page 189: ...r the teleprotection scheme in this operating mode It may however be controlled by the automatic reclosing function see also section 2 17 Figure 2 83 Operation scheme of the permissive underreach transfer trip PUTT method Sequence The permissive transfer trip signal is only sent for faults in forward direction Accordingly the first zone Z1 of the distance protection must definitely be set to Forwa...

Page 190: ...7 Teleprotection for Distance Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 190 Figure 2 84 Logic diagram of the permissive underreach transfer trip PUTT with pickup one line end ...

Page 191: ...ess 2103 Send Prolong to compensate for possible differences in the pickup times at the two line ends The distance protection is set in such a way that the first zone reaches up to approximately 85 of the line length the overreaching zone however is set to reach beyond the next station approximately 120 of the line length On three terminal lines Z1 is also set to approximately 85 of the shorter li...

Page 192: ...ure 2 86 Logic diagram of the permissive underreach transfer trip PUTT using Z1B one line end The permissive transfer trip should only send for faults in the Forward direction Therefore the first zone Z1 of the distance protection must be set to at address 1601 Op mode Z1 see also Section 2 5 1 under side title Independent zones Z1 up to Z6 ...

Page 193: ... 87 The transmit signal can be prolonged by TS settable in address 2103 Send Prolong to compensate for pos sible differences in the pickup time at the two line ends The distance protection is set such that the first zone reaches up to approximately 85 of the line length On three terminal lines Z1 is also set to approximately 85 of the shorter line section but at least beyond the tee off point Care...

Page 194: ...rded to the command relay A prerequisite for fast tripping is therefore that the fault is recognised inside Z1B in forward direction at both line ends The distance protection is set in such a way that overreaching zone Z1B reaches beyond the next station approximately 120 of the line length On three terminal lines Z1B must be set to reliably reach beyond the longer line section even if there is an...

Page 195: ...an auto matic reclosure by setting parameter 1st AR Z1B and by an external recloser device via the binary input Enable ARzones The occurrence of erroneous signals resulting from transients during clearance of external faults or from direc tion reversal resulting during the clearance of faults on parallel lines is neutralized by the Transient Blocking On feeders with single end infeed the line end ...

Page 196: ... 2 7 Teleprotection for Distance Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 196 Figure 2 89 Logic diagram of the permissive overreach transfer trip POTT scheme one line end ...

Page 197: ...ogic diagram of the directional comparison scheme for one line end On two terminal lines the signal transmission may be phase segregated In this case send and receive circuits operate separately for each phase On three terminal lines the transmit signals are sent to both opposite line ends The receive signals are then combined with a logical AND gate as all three line ends must transmit a send sig...

Page 198: ...unctions 2 7 Teleprotection for Distance Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 198 Figure 2 91 Logic diagram of the directional comparison scheme one line end ...

Page 199: ...r during a fault outside Z1B or in the reverse direction the monitoring frequency f0 is transmitted If a release signal is also received from the opposite end the trip signal is forwarded to the command relay Accordingly it is a prerequisite for fast tripping that the fault is recognised inside Z1B in forward direction at both line ends The distance protection is set in such a way that overreachin...

Page 200: ...the release Unblock 1 is issued after a security delay time of 20 ms and passed onto the receive logic This release is however removed after a further 100 ms via the timer stage 100 100 ms When the transmission is functional again one of the two receive signals must appear again either Dis T UB ub 1 or Dis T UB bl 1 after a further 100 ms drop off delay of the timer stage 100 100 ms the quiescent ...

Page 201: ...Functions 2 7 Teleprotection for Distance Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 201 Figure 2 93 Send and enabling logic of the unblocking scheme ...

Page 202: ...Functions 2 7 Teleprotection for Distance Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 202 Figure 2 94 Unblock logic ...

Page 203: ... the protected line by means of power line carrier PLC and the attenuation of the transmitted signal at the fault location may be so severe that reception at the other line end cannot necessarily be guaran teed The function scheme is shown in Figure 2 95 Faults inside the overreaching zone Z1B which is set to approximately 120 of the line length will initiate trip ping unless a blocking signal is ...

Page 204: ...2 5 1 at margin heading Controlled Zone Z1B On two terminal lines the signal transmission may be phase segregated In this case send and receive circuits operate separately for each phase On three terminal lines the transmit signals are sent to both opposite line ends The receive signals are then combined with a logical OR gate as no blocking signal must be received from any line end during an inte...

Page 205: ...Functions 2 7 Teleprotection for Distance Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 205 Figure 2 96 Logic diagram of the blocking scheme one line end ...

Page 206: ... Z1B functions as instantaneous zone at both ends of the protected line Zone Z1B is set to reach beyond the next station The pilot wire comparison avoids non selective tripping The information exchange between both line ends is carried out via a closed quiescent current loop Figure 2 97 fed by a substation battery One NC contact must be allocated for each signal output the receiving input must be ...

Page 207: ...t wire failure is delayed by 10 s The pilot wire comparison supplement is then blocked It does not need to be blocked from external as the pilot wire failure is recognized internally The other stages of the distance protection continue operating according to the normal grading co ordination chart Due to the low current consumption of the binary inputs it may be necessary to additionally burden the...

Page 208: ... wire comparison logic The isolation voltage of the pilot wires and the binary inputs and outputs must also be taken into account In the event of an earth fault the induced longitudinal voltage must neither exceed 60 of the isolation voltage of the pilot wires nor 60 of the isolation of the device The pilot wire comparison is therefore only suited for short lines ...

Page 209: ...se delay time T1B must be set longer than the pickup time Ta of the protection devices of the outgoing lines is blocked after the pickup of an inferior protection The pickup signal is sent ac cording to Figure 2 100 via the receive input 4006 DisTel Rec Ch1 of the distance protection If no signal is received this zone guarantees fast tripping of the busbar for faults on the busbar such as for exam...

Page 210: ... circuit Figure 2 101 shows the principle of the transient blocking for a permissive scheme If following fault detection a non directional fault or a fault in the reverse direction is determined within the waiting time TrBlk Wait Time address 2109 the transmit circuit and the release of the overreaching zone Z1B are prevented This blocking is maintained for the duration of the transient blocking t...

Page 211: ...on Figure 2 102 shows the generation of the echo release by the distance protection The detection of the weak infeed condition and accordingly the requirement for an echo are combined in a central AND gate The distance protection must neither be switched off nor blocked as it would otherwise always produce an echo due to the missing fault detection If however the time delayed overcurrent protectio...

Page 212: ...ess 121 Depending on this configuration only those parameters which are applicable to the selected mode appear here If the teleprotection supplement is not required the address 121 is set to Teleprot Dist Disabled The following modes are possible with conventional transmission links as described in Section 2 7 Direct underreach transfer trip Remote trip without any pickup PUTT Pickup Permissive Un...

Page 213: ...ayed setting to this end Figure 2 103 Distance protection setting with permissive overreach schemes Time Settings The send signal prolongation Send Prolong address 2103 must ensure that the send signal reliably reaches the opposite line end even if there is very fast tripping at the sending line end and or the signal trans mission time is relatively long In the case of the permissive overreaching ...

Page 214: ...ckTime when the direction measurement is delayed compared to the function pickup signal transients A setting of 10 ms to 40 ms is generally applicable depending on the operating tripping time of the relevant circuit breaker on the parallel line It is absolutely necessary that the transient blocking time TrBlk BlockTime address 2110 is longer than the duration of transients resulting from the incep...

Page 215: ...Type of In formation Comments 4001 Dis Telep ON SP Distance Teleprotection ON 4002 Dis Telep OFF SP Distance Teleprotection OFF 4003 Dis Telep Blk SP Distance Teleprotection BLOCK 4005 Dis RecFail SP Dist teleprotection Carrier faulty 4006 DisTel Rec Ch1 SP Dis Tele Carrier RECEPTION Channel 1 4007 Dis T RecCh1L1 SP Dis Tele Carrier RECEPTION Channel 1 L1 4008 Dis T RecCh1L2 SP Dis Tele Carrier RE...

Page 216: ...Dis Telep Carrier SEND signal L3 4060 DisJumpBlocking OUT Dis Tele Blocking Send signal with jump 4068 Dis T Trans Blk OUT Dis Telep Transient Blocking 4070 Dis T BL STOP OUT Dis Tele Blocking carrier STOP signal 4080 Dis T UB Fail1 OUT Dis Tele Unblocking FAILURE Channel 1 4081 Dis T UB Fail2 OUT Dis Tele Unblocking FAILURE Channel 2 4082 Dis T BL STOPL1 OUT DisTel Blocking carrier STOP signal L1...

Page 217: ...se the measured impedance is outside the fault detection char acteristic of the distance protection High fault resistances can be found for instance in overhead lines without earth wire or in sandy soil 2 8 1 Functional Description Measured Quantities The zero sequence current is used as measured variable According to its definition equation it is obtained from the sum of the three phase currents ...

Page 218: ...le zero sequence current 3 I0 is passed through a numerical filter and then compared with the set value 3I0 If this value is exceeded an alarm is issued After the corresponding delay time T 3I0 has ex pired a trip command is issued which is also alarmed The reset threshold is approximately 95 of the pickup threshold Figure 2 104 shows the logic diagram of the 3I0 stage The function blocks directio...

Page 219: ...04 applies Definite time overcurrent stage 3I0 The logic of the overcurrent stage 3I0 too is the same as that of the 3I0 stage In all references 3I0 must merely be replaced with 3I0 In all other respects Figure 2 104 applies This stage operates with a spe cially optimized digital filter that completely suppresses all harmonic components beginning with the 2nd har monic Therefore it is particularly...

Page 220: ...current and a time multiplier 3I0p Time Dial IEC characteristic Figure 2 105 or a time multiplier TimeDial TD3I0p ANSI characteristic A pre selection of the available characteristics was already carried out during the configuration of the protection functions Furthermore an additional fixed delay Add T DELAY may be se lected The characteristics are shown in the Technical Data Fig 2 105 shows the l...

Page 221: ...a number of parameters The slope and a time shift 3I0p MaxT DELAY which directly affect the curve can be changed The characteristics are shown in the Technical Data Figure 2 106 shows the logic diagram In addition to the curve parameters a minimum time 3I0p MinT DELAY can be determined below this time no tripping can occur Below a current factor of 3I0p Startpoint which is set as a multiple of the...

Page 222: ...ge time protection U0 inverse The zero sequence voltage time protection operates according to a voltage dependent trip time characteristic It can be used instead of the time overcurrent stage with inverse time delay The voltage time characteristic can be displaced in voltage direction by a constant voltage U0inv minimum valid for t and in time direction by a constant time T forw U0inv The characte...

Page 223: ...ng time depends on the level of the zero sequence voltage U0 For meshed earthed systems the zero sequence voltage increases towards the earth fault location The inverse characteristic results in the shortest command time for the relay closest to the fault The other relays then reset Figure 2 107 Directional zero sequence voltage time protection with non directional backup stage ...

Page 224: ...erates according to a power dependent trip time characteristic It can be used instead of an inverse time overcurrent stage The power is calculated from the zero sequence voltage and the zero sequence current The component Sr is decisive in direction of a configurable compensation angle ϕcomp which is also referred to as compensated zero sequence power i e Sr 3I0 3U0 cos ϕ ϕComp where ϕ U0 I0 ϕComp...

Page 225: ...cteristic results in the shortest command time for the relay closest to the fault The other relays then reset Phase current stabilization Asymmetrical load conditions in multiple earthed systems or different current transformer errors can result in a zero sequence current This zero sequence current could cause faulty pickup of the earth current stages if low pickup thresholds are set To avoid this...

Page 226: ...ot effective below a certain current threshold For devices with normal earth current trans former and for devices without separate earth current transformer inrush blocking is only effective if the earth current is higher than 0 41 IN or if the current of the 2nd harmonic is higher than 0 041 IN For devices with sensitive current transformer inrush blocking becomes effective as soon as the earth c...

Page 227: ... miniature circuit breaker trips for the Uen transformer no 362 FAIL U4 VT the system switches automatically to the zero sequence voltage calculated from the normal voltage transformers Directional determination with 3 U0 is possible as long as the calculated zero sequence voltage is not disturbed as well The calculated zero sequence voltage is deemed to be disturbed if the VT miniature circuit br...

Page 228: ...th zero sequence system The voltage drop on the series capacitor UC0 3 I0 XserCap address 3187 is subtracted from the measured zero sequence voltage 3U0meas The resulting voltage3U0Dir is then assigned to the directional characteristic of the earth fault protection as shown on Figure 2 111 Determination of direction with negative phase sequence system It is advantageous to use negative sequence sy...

Page 229: ...tage transformer mcb Fuse Failure Monitor measured voltage failure monitoring or a single pole dead time Figure 2 112 shows an example of the direc tional characteristic Figure 2 112 Directional characteristic with zero sequence power example Sr setting value S FORWARD Selection of the earth faulted phase Since the earth fault protection uses the quantities of the zero sequence system and the nega...

Page 230: ...a single phase fault The phase selector has an action time of approximately 40 ms If the phase selector has not made a decision during this time three pole tripping is initiated Three pole tripping is initiated anyway as soon as a multi pole fault has been detected as described above Therefore the phase selective transmit signals in teleprotection schemes can have a delay of up to 40 ms as compare...

Page 231: ...Functions 2 8 Earth Fault Protection in Earthed Systems optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 231 Figure 2 113 Logic diagram of single pole tripping with phase selector ...

Page 232: ...e a fault is detected by the distance protection the earth fault protection will not trip This gives the selective fault clearance by the distance protection preference over tripping by the earth fault protection The blocking can be restricted by configuration to single phase or multi phase faults and to faults in distance zone Z1 or Z1 Z1B The blocking only affects the time sequence and tripping ...

Page 233: ...hing onto an earth fault The line energisation detection can be used to achieve fast tripping when energising the circuit breaker in case of an earth fault The earth fault protection can then trip three pole without delay Parameters can be set to de termine to which stage s the non delayed tripping following energisation applies see also logic diagrams from Figure 2 104 to Figure 2 108 The non del...

Page 234: ... address 3174 BLK for DisZone to in each zone Address 3102 thus refers to the fault type and address 3174 to the fault location The two blocking options create an AND condition To block the earth fault protection only for single phase faults occurring in zone Z1 set address 3102 BLOCK for Dist 1phase PICKUP and 3174 BLK for DisZone in zone Z1 To block the earth fault protection for any fault type ...

Page 235: ... NO When setting stages separat the parameters for the phase selective setting are visible 3117 Trip 1p 3I0 3127 Trip 1p 3I0 3137 Trip 1p 3I0 and 3158 Trip 1p 3I0p parameter 3109 Trip 1pole E F is hidden The parameters 3117 3127 3137 and 3158 can be used to determine which stage is to trip 1 pole provided that the faulted phase can be determined with certainty If the corresponding stage is to trip...

Page 236: ...iguration Section 2 1 1 3 address 131 With IEC characteristics address 131 Earth Fault O C TOC IEC the following options are available in address 3151 IEC Curve Normal Inverse inverse type A according to IEC 60255 3 Very Inverse very inverse type B according to IEC 60255 3 Extremely Inv extremely inverse type C according to IEC 60255 3 and LongTimeInverse long inverse type B according to IEC 60255...

Page 237: ...f this is required The setting Add T DELAY address 3147 is added to the time of the set curve During the selection of the current and time settings regard must be taken as to whether a stage should be direction dependent and whether it uses teleprotection Refer also to the margin headings Determination of Direction and Teleprotection with Earth Fault Protection Inverse time stage with logarithmic ...

Page 238: ... which this stage is required to oper ate The value must be exceeded by the minimum earth fault current value The voltage controlled characteristic is based on the following formula U0 is the actual zero sequence voltage U0 min is the setting value U0inv minimum address 3183 Please take into consideration that the formula is based on the zero sequence voltage U0 not on 3U0 The function is illustra...

Page 239: ...ate The value must be exceeded by the minimum earth fault current value The zero sequence power Sr is calculated according to the formula Sr 3I0 3U0 cos ϕ ϕComp The angle ϕComp is set as maximum sensitivity angle at address 3168 PHI comp It refers to the zero sequence voltage in relation to the zero sequence current The default setting 255 thus corresponds to a zero sequence impedance angle of 75 ...

Page 240: ... in the secondary circuit of the voltage trans formers This presupposes that the device is equipped with a current input I4 of normal sensitivity and that the current from the transformer starpoint infeed is connected to I4 If direction determination is to be carried out using exclusively the negative sequence system signals 3I2 and 3U2 the setting with U2 and I2 is applied In this case only the n...

Page 241: ...g angles Dir ALPHA and Dir BETA addresses 3162 and 3163 This parameter can only be changed in DIGSI at Display Additional Settings As these set values are not critical the presettings may be left unchanged If you want to change these values refer to margin heading Direction Determination with Zero Sequence System for the angle determination The direction determination POLARIZATION with zero seq po...

Page 242: ...B Z0A in Figure 2 117 the following setting is recommended for parameter 3186 3U0 forward 3U0 forward 0 8 3I0 lowest directional stage Z0L Additional safety can be obtained through the zero sequence impedance of the infeed at the opposite line end which is not taken into account in the formula Z0B in Figure 2 117 In lines with series compensation it is possible to compensate the negative influence...

Page 243: ...argin heading Earth Fault Protection Prerequisites Switching onto an earth fault It is possible to determine with a setting which stage trips without delay following closure onto a dead fault The parameters 3I0 SOTF Trip address 3114 3I0 SOTF Trip address 3124 3I0 SOTF Trip address 3134 and if necessary 3I0p SOTF Trip address 3149 are available for the stages and can be set to YES or NO for each s...

Page 244: ... it may be assumed that if very large currents occur a short circuit has occurred before the transformer In the event of such large cur rents the inrush restraint is inhibited This threshold value which is set in the address 3171 Imax InrushRest should be larger than the maximum expected inrush current RMS value 2 8 3 Settings Addresses which have an appended A can only be changed with DIGSI under...

Page 245: ...ES NO Instantaneous trip via Tele prot BI 3124 3I0 SOTF Trip NO YES NO Instantaneous trip after SwitchOnToFault 3125 3I0 InrushBlk NO YES NO Inrush Blocking 3126 BLK 1p 3I0 YES No non dir YES Block 3I0 during 1pole dead time 3127 Trip 1p 3I0 YES NO YES Single pole trip with 3I0 3130 Op mode 3I0 Forward Reverse Non Directional Inactive Inactive Operating mode 3131 3I0 1A 0 05 25 00 A 1 00 A 3I0 Pic...

Page 246: ...e Delay 3147 Add T DELAY 0 00 30 00 sec 1 20 sec Additional Time Delay 3148 3I0p Telep BI NO YES NO Instantaneous trip via Tele prot BI 3149 3I0p SOTF Trip NO YES NO Instantaneous trip after SwitchOnToFault 3150 3I0p InrushBlk NO YES NO Inrush Blocking 3151 IEC Curve Normal Inverse Very Inverse Extremely Inv LongTimeInverse Normal Inverse IEC Curve 3152 ANSI Curve Inverse Short Inverse Long Invers...

Page 247: ...VA 1 5 VA 3170 2nd InrushRest 10 45 15 2nd harmonic ratio for inrush restraint 3171 Imax InrushRest 1A 0 50 25 00 A 7 50 A Max Current overriding inrush restraint 5A 2 50 125 00 A 37 50 A 3172 SOTF Op Mode PICKUP PICKUP DIRECT PICKUP DIRECT Instantaneous mode after SwitchOnToFault 3173 SOTF Time DELAY 0 00 30 00 sec 0 00 sec Trip time delay after SOTF 3174 BLK for DisZone in zone Z1 in zone Z1 Z1B...

Page 248: ...1338 E F L3 selec OUT E F phase selector L3 selected 1345 EF Pickup OUT Earth fault protection PICKED UP 1354 EF 3I0 Pickup OUT E F 3I0 PICKED UP 1355 EF 3I0 Pickup OUT E F 3I0 PICKED UP 1356 EF 3I0 Pickup OUT E F 3I0 PICKED UP 1357 EF 3I0p Pickup OUT E F 3I0p PICKED UP 1358 EF forward OUT E F picked up FORWARD 1359 EF reverse OUT E F picked up REVERSE 1361 EF Trip OUT E F General TRIP command 136...

Page 249: ...ata interfaces can be used for signal transmission For example Fibre optic cables communication networks or dedicated cables control cable or twisted phone wire In this case send and receive signals must be linked to the remote commands via CFC Directional comparison pickup is suitable for these kinds of transmission 7SD5 also allows the transmission of phase selective signals This has the advanta...

Page 250: ...n the forward direction it initially sends a permissive signal to the opposite line end If a permissive signal is also received from the opposite end a trip signal is routed to the trip logic Accordingly it is a prerequisite for fast tripping that the fault is recognized in the forward direction at both line ends The send signal can be prolonged by TS settable The prolongation of the send signal o...

Page 251: ...Line Config address 3202 the device is informed as to whether it has one or two opposite line ends The occurrence of erroneous signals resulting from transients during clearance of external faults or from direc tion reversal resulting during the clearance of faults on parallel lines is neutralized by the Transient Blocking see margin heading Transient Blocking On lines where there is only a single...

Page 252: ...ctions 2 9 Teleprotection for Earth Fault Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 252 Figure 2 120 Logic diagram of the directional comparison scheme one line end ...

Page 253: ...re required for the transmission If the transmission device has a channel monitoring then the monitoring frequency f0 is keyed over to the working frequency fU unblocking frequency When the protection recognizes an earth fault in the forward di rection it initiates the transmission of the unblock frequency fU During the quiescent state or during an earth fault in the reverse direction the monitori...

Page 254: ...d signal the unblock logic takes effect neither the unblocking signal EF UB ub 1 nor the monitoring signal EF UB bl 1 are received In this case the release Unblock 1 is issued after a security delay time of 20 ms and passed onto the receive logic This release is however removed after a further 100 ms via the timer stage 100 100 ms When the transmission is functional again one of the two receive si...

Page 255: ...Functions 2 9 Teleprotection for Earth Fault Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 255 Figure 2 122 Logic diagram of the unblocking scheme one line end ...

Page 256: ...Functions 2 9 Teleprotection for Earth Fault Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 256 Figure 2 123 Unblock logic ...

Page 257: ...nctionality is shown in Figure 2 124 Earth faults in the forward direction cause tripping if a blocking signal is not received from the opposite line end Due to possible differences in the pickup times of the devices at both line ends and due to the signal transmis sion time delay the tripping must be somewhat delayed by TV in this case To avoid signal race conditions a transmit signal can be prol...

Page 258: ...Functions 2 9 Teleprotection for Earth Fault Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 258 Figure 2 125 Logic diagram of the blocking scheme one line end ...

Page 259: ...6 After expiration of TrBlk BlockTime address 3210 the delay time Release Delay address 3208 is restarted It lies in the nature of the blocking scheme that single end fed short circuits can also be tripped rapidly without any special measures as the non feeding end cannot generate a blocking signal 2 9 5 Transient Blocking Transient blocking provides additional security against erroneous signals d...

Page 260: ...cho signal at the other line end enables the release of the trip command The common echo signal see Figure Section 2 11 1 is triggered by both the earth fault protection and the distance protection Figure 2 127 shows the generation of the echo release by the earth fault protection The detection of the weak infeed condition and accordingly the requirement for an echo are combined in a central AND g...

Page 261: ...tion at B does not recognize the fault this would be interpreted as a fault with single sided infeed from A echo from B or no blocking signal from B which would lead to unwanted tripping by the protection at A Therefore the earth fault protection features an earth fault stage 3IoMin Teleprot address 3105 This stage must be set more sensitive than the earth current stage used for the teleprotection...

Page 262: ...gs The release of the directional tripping can be delayed by means of the permissive signal delay Release Delay address 3208 In general this is only required for the blocking scheme BLOCKING to allow sufficient transmission time for the blocking signal during external faults This delay only has an effect on the receive circuit of the teleprotection Conversely tripping by the comparison protection ...

Page 263: ... DIS address 3212 should be set to YES This blocks also the distance protection if an external fault was previously detected by the earth fault protection only Echo function The echo function settings are common to all weak infeed measures and summarized in tabular form in Section 2 11 2 2 Note The ECHO SIGNAL No 4246 must be separately allocated to the output relay for the transmitter actuation a...

Page 264: ...N Channel 1 Ph L3 1328 EF UB ub 1 L1 SP E F Unblocking UNBLOCK Chan 1 Ph L1 1329 EF UB ub 1 L2 SP E F Unblocking UNBLOCK Chan 1 Ph L2 1330 EF UB ub 1 L3 SP E F Unblocking UNBLOCK Chan 1 Ph L3 1371 EF Tele SEND L1 OUT E F Telep Carrier SEND signal Phase L1 1372 EF Tele SEND L2 OUT E F Telep Carrier SEND signal Phase L2 1373 EF Tele SEND L3 OUT E F Telep Carrier SEND signal Phase L3 1374 EF Tele STO...

Page 265: ... current transformer is installed in the starpoint connection i e between the starpoint and the earthing electrode The starpoint CT and the phase CTs define the limits of the protected zone exactly 2 10 1 Application Examples Figures 2 130 and 2 131 show two application examples A prerequisite is that the I4 transformer detects the starpoint current of the transformer side to be protected Figure 2...

Page 266: ...ccurs outside the protected zone Figure 2 133 a starpoint current ISP will also flow But an equally large current 3 I0 must then flow through the phase current transformers Since the current direction into the protected object is defined as positive this current is in phase opposition with ISP Figure 2 133 Example for an earth fault outside a transformer with current distribution When an external ...

Page 267: ...s present Figure 2 134 Principle of restricted earth fault protection When an earth fault occurs outside the protected zone a zero sequence current also flows though the phase current transformers This is on the primary side in counter phase with the starpoint current and has equal magnitude Therefore both the magnitude of the currents and their phase relationship are evaluated for re straint purp...

Page 268: ...t to zero i e full sensitivity during internal earth fault This result shows that for an internal fault no restraint is effective since the restraining quantity is either zero or negative Thus even small earth currents can cause tripping In contrast strong restraint becomes effective for external earth faults Figure 2 135 shows that the higher the zero sequence current transmitted by the phase cur...

Page 269: ...summation and and difference comparison Figure 2 136 Phasor diagram of the restraint quantity during external fault The restraint quantity can be influenced by a factor k This factor has a certain relationship to the limit angle ϕlimit This limit angle determines for which phase displacement between 3I0 and 3I0 the pickup value for 3I0 3I0 grows to i e no pickup occurs In 7SD5 k 4 In the aforement...

Page 270: ... IrestREF Σ I IL1 IL2 IL3 I4 The slope of the characteristic curve can be adjusted Pickup Normally a differential protection does not need a pickup since the fault detection and the trip condition are identical But the earth fault differential protection like all protection functions has a pickup function which is required for tripping and serves as the starting point for a number of further activ...

Page 271: ...e Without proper settings the device may show unexpected reactions incl tripping The sensitivity of the protection is determined by the I REF address 4111 This is the earth fault current that flows through the starpoint lead of the transformer Any other earth current which may be supplied from the network does not influence the sensitivity The set pickup value can be additionally increased in the ...

Page 272: ...s Column C configuration indicates the corresponding second ary nominal current of the current transformer 2 10 5 Information List Addr Parameter C Setting Options Default Setting Comments 4101 REF PROT OFF ON OFF Restricted Earth Fault Pro tection 4111 I REF 1A 0 05 2 00 A 0 15 A Pick up value I REF 5A 0 25 10 00 A 0 75 A 4112A T I REF 0 00 60 00 sec 0 00 sec T I REF Time Delay 4113A SLOPE 0 00 0...

Page 273: ...ious trippings may occur if distance protection and earth fault protection create an echo independently from each other In this case parameter Echo 1channel has to be set to YES If the conditions for an echo signal are met by the distance protection or the earth fault protection see also Sections 2 7 and 2 9 under Echo Function a short delay Trip Echo DELAY is initially activated This delay is nec...

Page 274: ...Functions 2 11 Measures for Weak and Zero Infeed SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 274 Figure 2 140 Logic diagram of the echo function with teleprotection ...

Page 275: ... infeed condition is built up per phase in conjunction with the distance pro tection and additionally once for the earth fault protection Since the undervoltage check is performed for each phase single pole tripping is also possible provided the device version has the single pole tripping option In the event of a short circuit it may be assumed that only a small voltage appears at the line end wit...

Page 276: ...Figure 2 141 Logic diagram of the weak infeed tripping Where the distance protection and the earth fault protection function share the same transmission channel address 2509 YES and neither the distance protection nor the earth fault protection are blocked the output of this gate is an AND combination of the inputs ...

Page 277: ...eding line end is released as well The parameters for weak infeed are listed in Section 2 11 3 2 The echo function can be enabled ECHO only or disabled OFF under address 2501 FCT Weak Infeed By means of this switch the weak infeed tripping function can also be activated ECHO and TRIPand Echo Trip I 0 If no circuit breaker auxiliary contacts are routed and if no current flows over the line a trippi...

Page 278: ...ous trippings may occur if distance protection and earth fault protection create an echo independently of each other In this case the parameter Echo 1channel address 2509 has to be set to YES The presetting is NO Note The ECHO SIGNAL No 4246 must be separately allocated to the output relay for the transmitter actuation as it is not included in the transmit signals of the transmission functions 2 1...

Page 279: ...Functions 2 11 Measures for Weak and Zero Infeed SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 279 Non delayed Tripping Figure 2 142 Logic diagram for non delayed tripping ...

Page 280: ...Functions 2 11 Measures for Weak and Zero Infeed SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 280 Trip with Delay Figure 2 143 Logic for delayed tripping ...

Page 281: ...ent voltage exceeds the dropout threshold a new pickup is possible after a maximum of 1 s Figure 2 144 Undervoltage detection for UL1 E Instantaneous tripping An undelayed TRIP command is issued if a receive signal WI reception is present and if an undervolt age is detected simultaneously The receive signal is prolonged at address 2512 Rec Ext so that a trip command is still possible in the event ...

Page 282: ...ued only reporting A 1 pole or 3 pole trip command for 1 pole pickup can still be issued A delayed tripping stage is implemented to allow tripping of the dedicated line end in case the transmission channel is faulted When undervoltage conditions have been detected this stage picks up in one or more phases and trips with delay after a configured time address 2515 TM and address 2516 TT depending on...

Page 283: ... time 2504A Echo BLOCK Time 0 00 30 00 sec 0 05 sec Echo Block Time 2505 UNDERVOLTAGE 2 70 V 25 V Undervoltage ph e 2509 Echo 1channel NO YES NO Echo logic Dis and EF on common channel 2510 Uphe Factor 0 10 1 00 0 70 Factor for undervoltage Uphe 2511 Time const τ 1 60 sec 5 sec Time constant Tau 2512A Rec Ext 0 00 30 00 sec 0 65 sec Reception extension 2513A T 3I0 Ext 0 00 30 00 sec 0 60 sec 3I0 e...

Page 284: ...detected OUT Weak Infeed Zero seq current detected 4226 WI U L1 OUT Weak Infeed Undervoltg L1 4227 WI U L2 OUT Weak Infeed Undervoltg L2 4228 WI U L3 OUT Weak Infeed Undervoltg L3 4229 WI TRIP 3I0 OUT WI TRIP with zero sequence current 4231 WeakInf PICKUP OUT Weak Infeed PICKED UP 4232 W I Pickup L1 OUT Weak Infeed PICKUP L1 4233 W I Pickup L2 OUT Weak Infeed PICKUP L2 4234 W I Pickup L3 OUT Weak ...

Page 285: ...te trip of the circuit breaker at the opposite line end On conventional transmission paths one transmission channel per desired transmission direction is required for remote tripping at the remote end For example fibre optic connections or voice frequency modulated high frequency channels via pilot cables power line carrier or microwave radio links can be used for this purpose in the following way...

Page 286: ...he circuit breaker is therefore ensured even if the initiating signal pulse is very short 2 12 3 Settings 2 12 4 Information List Addr Parameter Setting Options Default Setting Comments 2201 FCT Direct Trip ON OFF OFF Direct Transfer Trip DTT 2202 Trip Time DELAY 0 00 30 00 sec 0 01 sec Trip Time Delay No Information Type of In formation Comments 4403 BLOCK DTT SP BLOCK Direct Transfer Trip functi...

Page 287: ...emote CMD1 rec to Remote CMD4 rec The remaining 24 items of information reach the device via the binary inputs Rem Signal 1 to Rem Signal24 and are correspondingly available under Rem Sig 1recv etc at the receiving side When assigning the binary inputs and outputs using DIGSI you can provide the information to be transmitted with your own designation If for example a line has a unit connected powe...

Page 288: ...mote Signal 10 input 3559 Rem Signal11 SP Remote Signal 11 input 3560 Rem Signal12 SP Remote Signal 12 input 3561 Rem Signal13 SP Remote Signal 13 input 3562 Rem Signal14 SP Remote Signal 14 input 3563 Rem Signal15 SP Remote Signal 15 input 3564 Rem Signal16 SP Remote Signal 16 input 3565 Rem Signal17 SP Remote Signal 17 input 3566 Rem Signal18 SP Remote Signal 18 input 3567 Rem Signal19 SP Remote...

Page 289: ...Rem Sig16recv OUT Remote signal 16 received 3589 Rem Sig17recv OUT Remote signal 17 received 3590 Rem Sig18recv OUT Remote signal 18 received 3591 Rem Sig19recv OUT Remote signal 19 received 3592 Rem Sig20recv OUT Remote signal 20 received 3593 Rem Sig21recv OUT Remote signal 21 received 3594 Rem Sig22recv OUT Remote signal 22 received 3595 Rem Sig23recv OUT Remote signal 23 received 3596 Rem Sig2...

Page 290: ... local only for the first mode only the position of the local circuit breaker is considered If the circuit breaker is open at least for the time set in parameter SI Time all Cl address 1132 and an energization takes place the I stage is activated for the time set in pa rameter SI Time all Cl The I stage trips unselectively in case that the threshold is exceeded If the parameter CBaux for I is set ...

Page 291: ...lue of the currents is measured from the double setting value onwards Figure 2 147 shows the logic diagram in the upper part Therefore this stage is used when current grading is possible This is possible with a small source impedance and at the same time a high impedance of the protected object an example can be found in the advice on setting notes Section 2 14 2 The I stage is enabled automatical...

Page 292: ...not to pick up on the RMS value of the inrush current produced during the connection of the protected object On the other hand fault currents flowing through the protected object do not need to be considered When using a PC and DIGSI for the parameterization the values can be optionally entered as primary or sec ondary quantities For settings with secondary values the currents will be converted fo...

Page 293: ... of the current transformers Exemplary calculation 110 kV overhead line 150 mm2 with the data s length 60km R1 s 0 19 Ω km X1 s 0 42 Ω km Short circuit power at the feeding end Sk 3 5 GVA subtransient since the I stage can respond to the first peak value Current transformer 600 A 5 A From that the line impedance ZL and the source impedance ZS are calculated Z1 s 0 192 0 422 Ω km 0 46 Ω km ZL 0 46 ...

Page 294: ...mation Type of In formation Comments 4253 BLOCK SOTF O C SP BLOCK Instantaneous SOTF Overcurrent 4271 SOTF O C OFF OUT SOTF O C is switched OFF 4272 SOTF O C BLOCK OUT SOTF O C is BLOCKED 4273 SOTF O C ACTIVE OUT SOTF O C is ACTIVE 4281 SOTF O C PICKUP OUT SOTF O C PICKED UP 4282 SOF O CpickupL1 OUT SOTF O C Pickup L1 4283 SOF O CpickupL2 OUT SOTF O C Pickup L2 4284 SOF O CpickupL3 OUT SOTF O C Pi...

Page 295: ...the following functions Detection of an earth fault pick up by monitoring the displacement voltage Determination of the faulted phase by measuring the phase to earth voltages Determination of the direction of the earth fault residual current by high accuracy real and reactive compo nent measurement Pickup Pickup occurs when the settable threshold for the displacement voltage 3 U0 is exceeded To en...

Page 296: ...le for direction determination of the earth current In this case only the ohmic active residual current which results from the losses of the arc sup pression coil can be used for directional determination This earth fault residual current is only about some per cent of the capacitive earth fault current Following the phase determination the earth fault direction is determined from a highly accurat...

Page 297: ...esonant earthed systems Furthermore the angle error of the toroidal current transformer can be compen sated in the 7SD5 Since the angle error is non linear this is done by entering two operating points of the angle error curve of the transformer The device then calculates the error curve with the accuracy needed Earth Fault Location In radial systems locating earth faults is relatively simple Sinc...

Page 298: ...entifies the faulty phase and the earth fault direction according to the other settings If the earth fault detection is switched ON with Trip it also issues a trip command In this case no earth fault protocol is generated but a trip log that registers all information about the earth fault and the earth fault tripping The tripping can be delayed via address 3007 T 3U0 Voltage Stages The displacemen...

Page 299: ...finite detection of the faulted phase is a further prerequisite for alarming an earth fault Determination of Direction The following is valid for determination of direction during earth faults Pickup current 3I0 address 3005 must be set as high as possible to avoid a false pickup of the device provoked by asymmetrical currents in the system and by current transformers especially in a Holmgreen con...

Page 300: ...l The coil is matched to the total network The compensation current is thus 62 5 A The losses should be 4 For earth fault directional determination core balance current transformers 60 A 1 A are fitted Since the residual wattmetric current is derived principally from the coil losses it is independent of earth fault location approximately the same 4 of 62 5 A 2 5 A or secondary 2 5 A 60 A 0 042 A A...

Page 301: ...1 3012 CT Err I2 0 003 1 600 A 1 000 A Current I2 for CT Angle Error 3013 CT Err F2 0 0 5 0 0 0 CT Angle Error at I2 No Information Type of In formation Comments 1219 3I0senA VI Active 3I0sen sensitive Ie 1220 3I0senR VI Reactive 3I0sen sensitive Ie 1251 SensEF on SP Switch on sensitive E F detection 1252 SensEF off SP Switch off sensitive E F detection 1253 SensEF block SP Block sensitive E F det...

Page 302: ...tection and distance protection are then blocked This means that emergency operation replaces the differential protection and or the distance protection as short circuit protection if protection data communication fails and the distance protection working in parallel detects a failure of the measuring voltages from one of the following conditions The Voltage transformer mcb tripped signal is recei...

Page 303: ...nd con nected Definite Time High set Current Stage I Each phase current is compared with the setting value Iph after numerical filtering the earth current is com pared with 3I0 PICKUP After pickup of a stage and expiry of the associated delay times T Iph or T 3I0 a trip command is issued The dropout value is approximately 7 below the pickup value but at least 1 8 of the nominal current Figure 2 15...

Page 304: ... references Iph must merely be replaced by Iph or 3I0 PICKUP by 3I0 The parameter 2624 I Telep BI is set to NO by default In all other respects figure 2 153 applies Inverse time overcurrent stage IP The logic of the inverse overcurrent stage also operates chiefly in the same way as the remaining stages How ever the time delay is calculated here based on the type of the set characteristic the inten...

Page 305: ...hows the logic diagram The setting parameter addresses of the IEC characteristics are shown by way of an example In the setting information Section 2 16 3 the different setting addresses are elaborated upon Figure 2 154 Logic diagram of the IP stage inverse time overcurrent protection example of IEC curve 1 Output indications associated with the pickup signals are listed in Table 2 12 2 Output ind...

Page 306: ...is then automatically active as soon as the differential protection is not effective due to a communication disturbance and the distance protection is not effective due to a failure of the measuring voltage The I stage can however also be used as a standard additional and independent overcurrent stage since it works independent of the other stages In this case the enable input I STUB ENABLE must b...

Page 307: ...hout delay or with a reduced delay It can be determined via parameter setting for which stage s the instantaneous tripping following energization applies refer also to the logic diagrams Figure 2 153 2 154 and 2 155 This function is independent of the high current instantaneous tripping described in Section 2 14 Pickup logic and tripping logic The pickup signals of the single phases or earth and o...

Page 308: ...g unit but not by a phase measuring unit O C TRIP L123 is signalled I PU L1 I PU L2 I PU L3 I PU E 2 155 2 155 2 155 2 155 I STUB PICKUP 7201 All pickups O C PICKUP 7161 Internal indication Display Output indication No I PU L1 I PU L1 Ip PU L1 I PU L1 1 2 153 2 154 2 155 O C TRIP 1p L1 or O C TRIP L123 7212 or 7215 I PU L2 I PU L2 Ip PU L2 I PU L2 1 2 153 2 154 2 155 O C TRIP 1p L2 or O C TRIP L12...

Page 309: ...stages can be set as instantaneous tripping stages when switching onto a fault This is chosen during the setting of the individual stages see below To avoid a spurious pick up due to transient overcur rents the delay SOTF Time DELAY address 2602 can be set Typically the presetting of 0 s is correct A short delay can be useful in case of long cables for which high inrush currents can be expected or...

Page 310: ...ent occurring at the line end during a short circuit being decisive The set time delays are pure additional delays which do not include the operating time measuring time The parameter I Telep BI address 2614 defines whether the time delays T Iph address 2611 and T 3I0 address 2613 can be bypassed via the binary input O C InstTRIP No 7110 or by the op erational automatic reclosure function The bina...

Page 311: ...e ex pected The time delay T Iph address 2621 results from the time grading schedule designed for the network When using the function as emergency overcurrent protection shorter delay times make sense one grading time step above instantaneous tripping since in this case the function is to work only if the main protection func tions i e differential and or distance protection fail The time T 3I0 ad...

Page 312: ...directly be applied as setting here Primary Set value IP 630 A Secondary Set value IP 5 25 A i e 630 A 600 A X 5 A The time multiplier T Ip Time Dial address 2642 derives from the time grading schedule set for the net work For use as emergency overcurrent protection shorter delay times make sense one grading time step above instantaneous tripping since this function is to work only if the main pro...

Page 313: ...ondary Setting value IP 5 25 A i e 630 A 600 A X 5 A The time multiplier Time Dial TD Ip address 2643 derives from the time grading schedule set for the network For use as emergency overcurrent protection shorter delay times make sense one grading time step above instantaneous tripping since this function is to work only if the main protection functions i e differential and or distance protection ...

Page 314: ...ckup without fault The delay T Iph STUB address 2631 however can be shorter than defined in the time grading schedule since this stage works only in emergency operation i e in case of a communication failure of the differential protection or a local measurement voltage failure of the dis tance protection One grading time above the base time of the differential protection is usually sufficient Acco...

Page 315: ... via Tele prot BI 2615 I SOTF NO YES NO Instantaneous trip after SwitchOnToFault 2620 Iph 1A 0 05 50 00 A 1 50 A Iph Pickup 5A 0 25 250 00 A 7 50 A 2621 T Iph 0 00 30 00 sec 0 50 sec T Iph Time delay 2622 3I0 1A 0 05 25 00 A 0 20 A 3I0 Pickup 5A 0 25 125 00 A 1 00 A 2623 T 3I0 0 00 30 00 sec 2 00 sec T 3I0 Time delay 2624 I Telep BI NO YES NO Instantaneous trip via Tele prot BI 2625 I SOTF NO YES ...

Page 316: ... 2671 I 3I0 p SOTF NO YES NO Instantaneous trip after SwitchOnToFault No Information Type of In formation Comments 7104 BLOCK O C I SP BLOCK Backup OverCurrent I 7105 BLOCK O C I SP BLOCK Backup OverCurrent I 7106 BLOCK O C Ip SP BLOCK Backup OverCurrent Ip 7107 BLOCK O C Ie SP BLOCK Backup OverCurrent Ie 7108 BLOCK O C Ie SP BLOCK Backup OverCurrent Ie 7109 BLOCK O C Iep SP BLOCK Backup OverCurre...

Page 317: ...up O C Pickup L31E 7182 O C Pickup L23 OUT Backup O C Pickup L23 7183 O C Pickup L23E OUT Backup O C Pickup L23E 7184 O C Pickup L123 OUT Backup O C Pickup L123 7185 O C PickupL123E OUT Backup O C Pickup L123E 7191 O C PICKUP I OUT Backup O C Pickup I 7192 O C PICKUP I OUT Backup O C Pickup I 7193 O C PICKUP Ip OUT Backup O C Pickup Ip 7201 I STUB PICKUP OUT O C I STUB Pickup 7211 O C TRIP OUT Bac...

Page 318: ...metallic short circuit the protection issues a final trip In some systems several reclosing attempts are performed In the model with 1 pole tripping the 7SD5 allows phase selective 1 pole tripping A 1 and 3 pole one and multi shot automatic reclosure is integrated depending on the order variant The 7SD5 can also operate in conjunction with an external automatic reclosure device In this case the si...

Page 319: ...ctivity before reclosure In order for the automatic reclosure to be successful all faults on the entire overhead line must be cleared at all line ends simultaneously as fast as possible This is the usual case in differential protection schemes because the strict selective zone definition of the pro tected object by the current transformer sets always allows non delayed tripping In the distance pro...

Page 320: ...e g 2nd reclosure ready AR 2 CycZoneRel and the inputs for enabling releasing non delayed tripping of the protection functions can be established via the binary inputs and outputs or the integrated user definable logic functions CFC Mixed Lines Overhead Line Cable In the distance protection it is possible to use the distance zone signals to distinguish between cable and over head line faults to a ...

Page 321: ...s the first trip of a time overcurrent protection following a fault is fast i e before the end of any action time This starts the automatic reclose function After unsuccessful reclo sure the 2nd cycle would then become active but the time overcurrent protection does not trip in this example until after 1s according to its grading time Since the action time for the second cycle was exceeded here th...

Page 322: ...e after a final trip or other events which block the auto reclose function after it has been started Re starting is blocked during this time When this time expires the automatic reclosure 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 funct...

Page 323: ...owed the reclosure is blocked dynamically The trip command is final The latter also applies if the CB trips two poles following a 1 pole trip command The device can only detect this if the auxiliary contacts of each pole are connected individually The device immediately initiates 3 pole cou pling which results in a 3 pole trip command If the CB auxiliary contacts indicate that at least one further...

Page 324: ...to a final 3 pole trip After unsuccessful reclosure final tripping the automatic reclosure function is blocked dynamically see also margin heading Reclose Block above The sequence above applies for single reclosure cycles In 7SD5 multiple reclosure up to 8 shots is also pos sible see below Sequence of a 1 pole and 3 pole Reclose Cycle This operating mode is only possible with the appropriate devic...

Page 325: ...ole trip after the last permissible reclosure following a protection stage that is valid without auto reclosure The automatic reclosure function is blocked dynamically see also margin heading Blocking reclosure above Handling Evolving Faults When 1 pole or 1 and 3 pole reclose cycles are executed in the network particular attention must be paid to sequential faults Sequential faults are faults whi...

Page 326: ...ltage of a disconnected phase does not disappear following a trip reclosure can be prevented A pre requisite for this function is that the voltage transformers are connected on the line side of the circuit breaker To select this function the dead line check must be activated The automatic reclosure function then checks the disconnected line for no voltage the line must have been without voltage fo...

Page 327: ...ssarily stressed as a result With non selective tripping outside the protected zone by an overreaching time graded protection no further reclosure cycles can be generated there because the fault current path via busbar B and position II remains interrupted even after several reclosures At position I overreach is allowed in the case of multiple reclosures and even in the event of final tripping bec...

Page 328: ... Reclosure 382 Only 1ph AR The external reclosure device is only programmed for 1 pole the stages of the individual protection functions that are activated before reclosure via No 383 only do so in the case of 1 phase faults in the event of multiple phase faults these stages of the individual short circuit protection functions do not operate This input is not required if no overreaching stage is u...

Page 329: ...e indications No 512 513 514 can be combined to one 1 pole tripping output No 515 sends the 3 pole tripping signal to the external device In case of exclusively 3 pole reclose cycles the general pickup signal No 501 if required by the external re closure device and trip signal No 511 of 7SD5 see Figure 2 162 are usually sufficient Figure 2 161 Connection example with external auto reclosure device...

Page 330: ...ure 2 163 shows the interconnection between the internal automatic reclosure function of the 7SD5 and an external protection device as a connection example for 1 pole cylces To achieve 3 pole coupling of the external protection and to release if necessary its accelerated stages before reclosure the following output functions are suitable 2864 AR 1p Trip Perm Internal automatic reclosure function r...

Page 331: ...ample with external protection device for 3 pole reclosure AR control mode with TRIP But if the internal automatic reclose function is controlled by the pickup only possible for 3 pole tripping 110 Trip mode 3pole only the phase selective pickup signals of the external protection must be connected if distinction shall be made between different types of fault The general trip command then suffices ...

Page 332: ...ernal automatic 3 pole coupling is therefore unnecessary if the above conditions are met This prevents 2 pole tripping under all circumstances For the connection according to Figure 2 166 it must be considered that the cross connections to the second protection must be interrupted during the check of one of the two protection systems with protection monitoring equipment This is done for example by...

Page 333: ...al SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 333 Figure 2 166 Connection example for 2 protection devices with 2 automatic reclosure functions BI Binary inputs M Signal output K Command for all protection functions operating with AR ...

Page 334: ...ional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 334 Figure 2 167 Connection example for 2 protection devices with internal automatic reclosure function and minimum cross connection Figure 2 168 Setting of the software filter time ...

Page 335: ...nterrogated prior to every reclosure This is set when setting the individual reclose cycles see below To check that the ready status of the circuit breaker is regained during the dead times you can set a circuit breaker ready monitoring time under address 3409 CB TIME OUT The time is set slightly longer than the re covery time of the circuit breaker after an OPEN CLOSE OPEN cycle If the circuit br...

Page 336: ...time If a 3 pole reclose cycle is to be initiated by tripping of the sequential fault set EV FLT MODE starts 3p AR In this case a separately adjustable 3 pole dead time is started with the 3 pole trip command due to the sequential fault This is only useful if 3 pole reclosure is also permitted Address 3408 T Start MONITOR monitors the reaction of the circuit breaker after a trip command If the CB ...

Page 337: ...ommon 3 pole control of the CB is possible Dead line check Under address 3431 the dead line check can be switched active It presupposes that voltage transformers are installed on the line side of the feeder and connected to the device If this is not the case or the function is not used set DLC RDT WITHOUT DLC RDT DLC means that the dead line check of the line voltage is used It only allows reclosi...

Page 338: ... of all dead times and all pro tection operating times plus one reclaim time Under address 3435 ADT 1p allowed it can be determined whether 1 pole tripping is allowed provided that 1 pole tripping is possible If NO the protection trips 3 pole for all fault types If YES the actual trip signal of the starting protection functions is decisive If the reclaim time is unequal to 0 s and 1 pole tripping ...

Page 339: ...function has no fault detection signal Depending on the configured operating mode of the automatic reclosure address 134 AR control mode only address 3456 and 3457 if AR control mode with TRIP are available or address 3453 to 3455 if AR control mode with PICKUP In AR control mode with TRIP you can set different dead times for 1 pole and 3 pole reclose cycles Whether 1 pole or 3 pole tripping is tr...

Page 340: ...roblems in the network during a 3 pole reclosure cycle you should set address 3460 1 AR SynRequest to YES In this case it is verified before each reclosure following a 3 pole trip whether the voltages of feeder and busbar are sufficiently synchronous This is only done on condition that either the internal synchronism and voltage check functions are available or that an external device is available...

Page 341: ...3 AR Tdead 3Flt Dead time after 3 phase pickup 3478 3 AR Tdead1Trip Dead time after 1 pole tripping 3479 3 AR Tdead3Trip Dead time after 3 pole tripping 3480 3 AR Tdead EV Dead time after evolving fault 3481 3 AR CB CLOSE CB ready interrogation before reclosing 3482 3 AR SynRequest Sync check after 3 pole tripping 3483 4 AR START Start in 4th cycle generally allowed 3484 4 AR T ACTION Action time ...

Page 342: ...e operational information system that in the event of an upcoming system fault there will be a final trip i e without reclosure If the automatic reclosure has been started this information does not appear AR not ready No 2784 The automatic reclosure is not ready for reclosure at the moment In addition to the AR is blocked No 2783 mentioned above there are also obstructions during the course of the...

Page 343: ...ad time 3408 T Start MONITOR 0 01 300 00 sec 0 50 sec AR start signal monitoring time 3409 CB TIME OUT 0 01 300 00 sec 3 00 sec Circuit Breaker CB Supervision Time 3410 T RemoteClose 0 00 300 00 sec 0 20 sec Send delay for remote close command 3411A T DEAD EXT 0 50 300 00 sec sec Maximum dead time extension 3420 AR WITH DIFF YES NO YES AR with differential protection 3421 AR w SOTF O C YES NO YES ...

Page 344: ...V 0 01 1800 00 sec 1 20 sec Dead time after evolving fault 3459 1 AR CB CLOSE YES NO NO CB ready interrogation before re closing 3460 1 AR SynRequest YES NO NO Request for synchro check after 3pole AR 3461 2 AR START YES NO NO AR start allowed in this cycle 3462 2 AR T ACTION 0 01 300 00 sec 0 20 sec Action time 3464 2 AR Tdead 1Flt 0 01 1800 00 sec 1 20 sec Dead time after 1phase faults 3465 2 AR...

Page 345: ...483 4 AR START YES NO NO AR start allowed in this cycle 3484 4 AR T ACTION 0 01 300 00 sec 0 20 sec Action time 3486 4 AR Tdead 1Flt 0 01 1800 00 sec 1 20 sec Dead time after 1phase faults 3487 4 AR Tdead 2Flt 0 01 1800 00 sec 1 20 sec Dead time after 2phase faults 3488 4 AR Tdead 3Flt 0 01 1800 00 sec 0 50 sec Dead time after 3phase faults 3489 4 AR Tdead1Trip 0 01 1800 00 sec sec Dead time after...

Page 346: ...cle SP AR Block 3rd AR cycle 2745 BLK 4 n AR SP AR Block 4th and higher AR cycles 2746 Trip for AR SP AR External Trip for AR start 2747 Pickup L1 AR SP AR External pickup L1 for AR start 2748 Pickup L2 AR SP AR External pickup L2 for AR start 2749 Pickup L3 AR SP AR External pickup L3 for AR start 2750 Pickup 1ph AR SP AR External pickup 1phase for AR start 2751 Pickup 2ph AR SP AR External picku...

Page 347: ...le 1st cycle 2853 AR Close1 Cyc3p OUT AR Close command after 3pole 1st cycle 2854 AR Close 2 Cyc OUT AR Close command 2nd cycle and higher 2861 AR T Recl run OUT AR Reclaim time is running 2862 AR successful OUT AR successful 2864 AR 1p Trip Perm OUT AR 1pole trip permitted by internal AR 2865 AR Sync Request OUT AR Synchro check request 2871 AR TRIP 3pole OUT AR TRIP command 3pole 2889 AR 1 CycZo...

Page 348: ...ransformers if a power transformer is located between the measuring points Closing is released for synchronous or asynchronous system conditions In the latter case the device deter mines the time for issuing the close command such that the voltages are identical the instant the breaker poles make contact 2 18 1 Method of Operation General For comparing the two voltages the synchro check uses the v...

Page 349: ...device determines the time for issuing the ON command from the current angle and frequency difference such that the angle difference of the voltages be tween busbar and feeder is almost 0 at the instant the poles make contact For this purpose the device re quires the parameter address 239 T CB close with the set circuit breaker closing time Different frequency limit thresholds apply to switching u...

Page 350: ...control keys or via the serial interface using DIGSI on a PC or from a control centre The release conditions for manual closure apply parameter MC The synchronism check function gives permission for passage Sync release No 2951 of the closing command to the required function Furthermore a separate closing command is available as output indication Sync CloseCmd No 2961 The check of the release cond...

Page 351: ...Functions 2 18 Synchronism and Voltage Check optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 351 ...

Page 352: ...sed at synchronism that is when the critical values AR maxVolt Diff AR maxFreq Diff AR maxAngleDiff are within the set limits AR Usy1 Usy2 Released if measuring point Usy1 is de energised and the measuring point Usy2 is energised AR Usy1 Usy2 Released if measuring point Usy1 is energised and the measuring point Usy2 is de energised AR Usy1 Usy2 Released if measuring point Usy1 is de energised and ...

Page 353: ...ase the closing command to couple a dead overhead line to a live busbar the following conditions are checked Is the feeder voltage below the set value Dead Volt Thr Is the busbar voltage above the setting value Live Volt Thr but below the maximum voltage Umax Is the frequency within the permitted operating range fN 3 Hz After successful check the closing command is released Corresponding condition...

Page 354: ... Notes Preconditions When setting the general power system data Power system data 1 refer to Section 2 1 2 1 a number of pa rameters regarding the measured quantities and the operating mode of the synchronism check function must be applied This concerns the following parameters 203 Unom PRIMARY primary rated voltage of the voltage transformers of the protection functions phase to phase in kV measu...

Page 355: ...arm Sync CloseCmd No 2961 is issued Address 3502 Dead Volt Thr indicates the voltage threshold below which the feeder or the busbar can safely be considered de energised for checking a de energised feeder or busbar The setting is applied in Volts secondary This value can be entered as a primary value when parameterising with a PC and DIGSI De pending on the VT connection these are phase to earth v...

Page 356: ...ess 3513 AR maxAngleDiff The further release conditions for automatic reclosing are set at addresses 3515 to 3519 The following addresses mean 3515 AR SYNC CHECK both measuring points Usy1 and Usy2 must be energised Live Volt Thr address 3503 the synchronism conditions are checked i e AR maxVolt Diff address 3511 AR maxFreq Diff address 3512 and AR maxAngleDiff address 3513 This parameter can only...

Page 357: ...onditions set this address to w o T CB close The permissible difference between the voltages is set in address 3531 MC maxVolt Diff The setting is applied in Volts secondary This value can be entered as a primary value when parameterising with a PC and DIGSI Depending on the VT connection these are phase to earth voltages or phase to phase voltages The permissible frequency difference between the ...

Page 358: ... the following lists or in the previous paragraphs Sync Start MC No 2905 Binary input which enables direct initiation of the synchronism check with setting parameters for manual close This initiation with setting parameter for manual close has always precedence if binary inputs Sync Start MC No 2905 and Sync Start AR No 2906 see below are activated at the same time Sync Start AR No 2906 Measuring ...

Page 359: ...f 2 80 10 Maximum angle difference 3515A AR SYNC CHECK YES NO YES AR at Usy2 Usy1 and Synchr 3516 AR Usy1 Usy2 YES NO NO AR at Usy1 and Usy2 3517 AR Usy1 Usy2 YES NO NO AR at Usy1 and Usy2 3518 AR Usy1 Usy2 YES NO NO AR at Usy1 and Usy2 3519 AR OVERRIDE YES NO NO Override of any check before AR 3530 Op mode with MC with T CB close w o T CB close w o T CB close Operating mode with Man Cl 3531 MC ma...

Page 360: ...verride OUT Synchro check override bypass 2943 Synchronism OUT Synchronism detected 2944 SYNC Usy1 Usy2 OUT SYNC Condition Usy1 Usy2 true 2945 SYNC Usy1 Usy2 OUT SYNC Condition Usy1 Usy2 true 2946 SYNC Usy1 Usy2 OUT SYNC Condition Usy1 Usy2 true 2947 Sync Udiff OUT Sync Voltage diff greater than limit 2948 Sync fdiff OUT Sync Freq diff greater than limit 2949 Sync ϕ diff OUT Sync Angle diff greate...

Page 361: ... times delay Abnormally high voltages often occur e g in low loaded long distance transmission lines in islanded systems when generator voltage regulation fails or after full load shutdown of a generator with the generator discon nected from the system Even if compensation reactors are used to avoid line overvoltages by compensation of the line capacitance and thus reduction of the overvoltage the...

Page 362: ...ltage The phase to phase overvoltage protection operates just like the phase to earth protection except that it detects phase to phase voltages Accordingly phase to phase voltages which have exceeded one of the stage thresholds Uph ph address 3712 or Uph ph address 3714 are also indicated Beyond this Figure 2 172 applies in principle The phase to phase overvoltage protection can also be blocked vi...

Page 363: ... BLK Figure 2 173 Logic diagram of the overvoltage protection for the positive sequence voltage system Overvoltage protection U1 with configurable compounding The overvoltage protection for the positive sequence system may optionally operate with compounding The compounding calculates the positive sequence system of the voltage at the remote line end This option is thus particularly well suited fo...

Page 364: ...d voltage at the remote line end UMeas the measured voltage at the local line end IMeas the measured current at the local line end CL the line capacitance RL the line resistance LL the line inductance Figure 2 174 PI equivalent diagram for compounding Overvoltage negative sequence system U2 The device calculates the negative sequence system voltages according to its defining equation U2 1 3 UL1 a2...

Page 365: ... by the asymmetrical power flow not by the fault in the system If the device cooperates with an external automatic reclosure function or if a single pole tripping can be triggered by a different protection system working in parallel the overvoltage protection for the negative sequence system must be blocked via a binary input during single pole tripping Overvoltage zero sequence system 3U0 Figure ...

Page 366: ...e co operates with an external automatic reclosure function or if a single pole tripping can be triggered by a different protection system working in parallel the overvoltage protection for the zero sequence system must be blocked via a binary input during single pole tripping According to Figure 2 176 the device calculates the voltage to be monitored 3 U0 UL1 UL2 UL3 This applies if no suitable v...

Page 367: ...e phase voltage As the zero sequence voltage stages operate separately and independently of the other protection overvoltage functions they can be used for any other single phase voltage Therefore the fourth voltage input U4 of the device must be assigned accordingly also see Section 2 1 2 Voltage Transformer Connection The stages can be blocked via a binary input 3U0 BLK Internal blocking is not ...

Page 368: ...bar side after a trip command and opening of the circuit breaker it becomes zero on the outgoing side For the undervoltage pro tection this results in a pickup state being present if the voltage transformers are on the outgoing side If this pickup must be reset the current can be used as an additional criterion current supervision CURR SUP Uphe address 3758 to achieve this result Undervoltage will...

Page 369: ...nctions 2 19 Undervoltage and Overvoltage Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 369 Figure 2 177 Logic diagram of the undervoltage protection for phase voltages ...

Page 370: ...ed phase provided that the voltage transformers are located on the outgoing side Only such stages are blocked during the single pole dead time that can actually initiate tripping according to their setting Undervoltage positive sequence system U1 The device calculates the positive sequence system according to its defining equation U1 1 3 UL1 a UL2 a2 UL3 where a ej120 The resulting positive sequen...

Page 371: ...rvoltage protection for positive sequence voltage system During single pole dead time for automatic reclosure the stages of positive sequence undervoltage protection are automatically blocked In this way the stages do not respond to the reduced positive sequence voltage caused by the disconnected phase in case the voltage transformers are located on the outgoing side ...

Page 372: ...p command only for the U stage The settings of the voltage threshold and the timer values depend on the type of application To detect steady state overvoltages on long lines carrying no load set the Uph e stage address 3702 to at least 5 above the maximum stationary phase to earth voltage expected during operation Additionally a high dropout to pickup ratio is required address 3709 Uph e RESET pre...

Page 373: ...ompounding If the values provided here do not correspond to real conditions the compounding may calculate an excessively high voltage at the remote end which will cause immediate pickup as soon as the measured values are applied In such a case the pickup state can only be reset by switching off the measuring voltage Compounding can be switched ON or OFF separately for each of the U1 stages for the...

Page 374: ... transf the device multiplies this voltage by the matching ratio Uph Udelta address 211 usually with 1 73 Therefore the voltage measured is 3 Uen 3 U0 When the voltage triangle is fully displaced the voltage will be 3 times the phase to phase voltage If any other voltage is connected to U4 which is not used for voltage protection and if this was already set in the Power System Data 1 refer also to...

Page 375: ...issing when the line is disconnected To avoid that the undervoltage levels in these cases are or remain picked up the current criterion CURR SUP Uphph address 3768 is switched ON With busbar side voltage transformers it can be switched OFF However if the busbar is dead the undervoltage protection will pick up and expire and then remain in a picked up state It must therefore be ensured in such case...

Page 376: ...V Uph ph Pickup 3713 T Uph ph 0 00 100 00 sec 2 00 sec T Uph ph Time Delay 3714 Uph ph 2 0 220 0 V 175 0 V Uph ph Pickup 3715 T Uph ph 0 00 100 00 sec 1 00 sec T Uph ph Time Delay 3719A Uphph RESET 0 30 0 99 0 98 Uph ph Reset ratio 3721 3U0 or Ux OFF Alarm Only ON U Alarm U Trip OFF Operating mode 3U0 or Ux over voltage 3722 3U0 1 0 220 0 V 30 0 V 3U0 Pickup or Ux 3723 T 3U0 0 00 100 00 sec 2 00 s...

Page 377: ...e 1 0 100 0 V 0 10 0 V Uph e Pickup 3755 T Uph e 0 00 100 00 sec 1 00 sec T Uph e Time Delay 3758 CURR SUP Uphe ON OFF ON Current supervision Uph e 3759A Uph e RESET 1 01 1 20 1 05 Uph e Reset ratio 3761 Uph ph OFF Alarm Only ON U Alarm U Trip OFF Operating mode Uph ph under voltage prot 3762 Uph ph 1 0 175 0 V 0 50 0 V Uph ph Pickup 3763 T Uph ph 0 00 100 00 sec 2 00 sec T Uph ph Time Delay 3764 ...

Page 378: ...BLK OUT Uph ph Overvolt is BLOCKED 10219 3U0 OFF OUT 3U0 Overvolt is switched OFF 10220 3U0 BLK OUT 3U0 Overvolt is BLOCKED 10221 U1 OFF OUT U1 Overvolt is switched OFF 10222 U1 BLK OUT U1 Overvolt is BLOCKED 10223 U2 OFF OUT U2 Overvolt is switched OFF 10224 U2 BLK OUT U2 Overvolt is BLOCKED 10225 Uph e OFF OUT Uph e Undervolt is switched OFF 10226 Uph e BLK OUT Uph e Undervolt is BLOCKED 10227 U...

Page 379: ...10270 3U0 Pickup OUT 3U0 Pickup 10271 3U0 Pickup OUT 3U0 Pickup 10272 3U0 TimeOut OUT 3U0 TimeOut 10273 3U0 TimeOut OUT 3U0 TimeOut 10274 3U0 TRIP OUT 3U0 TRIP command 10280 U1 Pickup OUT U1 Pickup 10281 U1 Pickup OUT U1 Pickup 10282 U1 TimeOut OUT U1 TimeOut 10283 U1 TimeOut OUT U1 TimeOut 10284 U1 TRIP OUT U1 TRIP command 10290 U2 Pickup OUT U2 Pickup 10291 U2 Pickup OUT U2 Pickup 10292 U2 TimeO...

Page 380: ...h Pickup OUT Uph ph Pickup 10327 Uphph PU L12 OUT Uphph Pickup L1 L2 10328 Uphph PU L23 OUT Uphph Pickup L2 L3 10329 Uphph PU L31 OUT Uphph Pickup L3 L1 10330 Uphph TimeOut OUT Uphph TimeOut 10331 Uphph TimeOut OUT Uphph TimeOut 10332 Uphph TRIP OUT Uphph TRIP command 10333 Uphph PU L12 OUT Uph ph Pickup L1 L2 10334 Uphph PU L23 OUT Uph ph Pickup L2 L3 10335 Uphph PU L31 OUT Uph ph Pickup L3 L1 10...

Page 381: ... is set to a value above the rated frequency it is automatically interpreted to be an overfrequency stage f If a stage is set to a value below the rated frequency it is automatically interpreted to be an underfrequency stage f If a stage is set exactly to the rated frequency it is inactive Each stage can be blocked via binary input and also the entire frequency protection function can be blocked F...

Page 382: ... frequency stages power swings may cause the frequency protection to pickup and even to trip In such cases out of step trips cannot be prevented by operating the distance protection with power swing blocking see also Section 2 6 Rather it is reasonable to block the frequency protection once power swings are detected This can be accomplished via binary inputs and binary outputs or by corresponding ...

Page 383: ...Functions 2 20 Frequency Protection optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 383 Figure 2 179 Logic diagram of the frequency protection ...

Page 384: ...frequency it is automatically interpreted to be an underfrequency stage f If a stage is set exactly to the rated frequency it is inactive A pickup value can be set for each stage according to above rules The addresses and possible setting ranges are determined by the nominal frequency as configured in the Power System Data 1 Section 2 1 2 1 in Rated Frequency address 230 Please note that none of t...

Page 385: ...d by disconnecting it from the power system on time The turbo regulator regulates the machine set to the nominal speed Consequently the sta tion s own demands can be continuously supplied at nominal frequency Since the dropout threshold is 20 mHz below or above the trip frequency the resulting minimum trip frequency is 30 mHz above or below the nominal frequency A frequency increase can for exampl...

Page 386: ...OCKED OUT Frequency protection is BLOCKED 5213 Freq ACTIVE OUT Frequency protection is ACTIVE 5215 Freq UnderV Blk OUT Frequency protection undervoltage Blk 5232 f1 picked up OUT Frequency protection f1 picked up 5233 f2 picked up OUT Frequency protection f2 picked up 5234 f3 picked up OUT Frequency protection f3 picked up 5235 f4 picked up OUT Frequency protection f4 picked up 5236 f1 TRIP OUT Fr...

Page 387: ...such as a short cable followed by an overhead line In such protected objects you can configure each section individually Without this information the fault locator uses the general line data see Section 2 1 4 For the internal decision whether the single ended or the double ended fault locating method will be used the device calculates on the basis of the line s known voltage profile a distance dif...

Page 388: ...on the assumption that in a line without branches with known currents and voltages at the inputs the voltage can be calculated for any location x of the line This applies for both the left and the right side of the line Since the voltage at the fault location calculated from both sides must be the same the fault is located at the intersection of the two voltage characteristics These characteris ti...

Page 389: ... the event of a new fault the data of the former fault are cleared automatically The output range extends from 0 to 195 Output 197 means that a negative fault was detected Output 199 describes an overflow i e the calculated value is higher than the maximum possible value of 195 Note If no different line sections are parameterised the distance output in kilometers miles or percent is only accu rate...

Page 390: ...o faults on the protected feeder For external faults including those on the parallel line compensation is impossible Correction of measured values for load current on double end fed lines single ended fault locator When faults occur on loaded lines fed from both ends Figure 2 182 the fault voltage UF1 is influenced not only by the source voltage E1 but also by the source voltage E2 when both volta...

Page 391: ...RT TRIP In this case a fault location is only output if the device has also issued a trip The fault location calcu lation can however also be started with each fault detection of the device address 3802 START Pickup In this case the fault location is also calculated if for example a different protection device cleared the fault If the fault is located outside the protected line only the single end...

Page 392: ...wo line types that line section 1 and 2 configured for device A must be line section 2 and 1 of device B If the devices are correctly configured indication no 1111 FL active will be output as ON If address 160 is set to 2 Sections or 3 Sections the line impedance angle of the first line section must be set at address 6001 S1 Line angle the reactance per unit length at address 6002 S1 x and the cap...

Page 393: ...t length x in Ω km 5 A 0 0050 9 5000 Ω km without 0 0 1500 Ω km 1 A A2 Line reactance per unit length x in Ω mile 5 A 0 0050 15 0000 Ω mile without 0 0 2420 Ω mile 6023 S2 c 1 A A2 Capacitance per unit length C in μF km 5 A 0 000 100 000 µF km 0 0 010 µF km 1 A A2 Capacitance per unit length C in μF mile 5 A 0 000 160 000 µF mile 0 0 016 µF mile 6024 S2 Line length A2 Line length in kilometers A2 ...

Page 394: ...t YES in address 3806 Load Compensat If high fault resistances are expected for single phase faults e g at over head lines without overhead earth wire or unfavourable earthing conditions of the towers this will improve the accuracy of the distance calculation If two ended fault location is not desired set address 3807 two ended to OFF The default setting is ON If the fault location is required to ...

Page 395: ...5 FL Loop L3E OUT_Ev Fault Locator Loop L3E 1126 FL Loop L1L2 OUT_Ev Fault Locator Loop L1L2 1127 FL Loop L2L3 OUT_Ev Fault Locator Loop L2L3 1128 FL Loop L3L1 OUT_Ev Fault Locator Loop L3L1 1131 RFpri VI Flt Locator primary FAULT RESISTANCE 1132 Flt Loc invalid OUT Fault location invalid 1133 Flt Loc ErrorK0 OUT Fault locator setting error K0 angle K0 1134 two ended FO OUT_Ev Two ended fault loca...

Page 396: ... circuit breaker will open and interrupt the fault current The current monitoring stage quickly resets typical 10 ms and stops the timer T BF If the trip command is not carried out circuit breaker failure case current continues to flow and the timer runs to its set limit The circuit breaker failure protection then issues a command to trip the backup circuit breakers and interrupt the fault current...

Page 397: ...of the current transformer set will be used if it is connected to the device If this current is not available the device will calculate it from the phase currents using this formula 3 I0 IL1 IL2 IL3 Additionally the value calculated by 7SD5 of three times the negative sequence current 3 I2 is used for plausi bility check This is calculated according to the equation 3 I2 IL1 a2 IL2 a IL3 where a ej...

Page 398: ...itor ing Once the current flow criterion has picked up during the trip signal from the feeder protection the circuit breaker is assumed to be open as soon as the current disappears even if the associated auxiliary contacts do not yet indicate that the circuit breaker has opened Figure 2 186 This gives preference to the more reliable current criterion and avoids overfunctioning due to a defect e g ...

Page 399: ...mmand of the external protection to the binary input BF Start 3pole no 1415 it is recommended to connect also the general device pickup to binary input BF release no 1432 For Buchholz protection it is recommended that both inputs are connected to the device by two separate wire pairs Nevertheless it is possible to initiate the circuit breaker failure protection in single channel mode should a sep ...

Page 400: ...tection is initiated by the internal input Start internal w o I if the trip signal comes from the internal voltage protection or frequency protection or by the external input BF Start w o I In this case the start signal is maintained until the circuit breaker is reported to be open by the auxiliary contact criterion Initiation can be blocked via the binary input BLOCK BkrFail e g during test of th...

Page 401: ...iate the circuit breaker failure protection in single channel mode should a sep arate release criterion not be available The binary input BF release must then not be assigned to any physical input of the device during configuration If the external protection device does not provide a general fault detection signal a general trip signal can be used instead Alternatively the parallel connection of a...

Page 402: ...sed for each individual breaker pole If however the breaker aux iliary contacts are not available for each individual breaker pole then a single pole trip command is assumed to be executed only if the series connection of the normally open NO auxiliary contacts is interrupted This information is provided to the breaker failure protection by the central function control of the device refer to Secti...

Page 403: ...Functions 2 22 Circuit Breaker Failure Protection SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 403 Figure 2 191 Initiation conditions for single pole trip commands ...

Page 404: ... omitted if the feeder protection always trips 3 pole or if the circuit breaker is not capable of 1 pole tripping If different delay times are required after a 1 pole trip or 3 pole trip it is possible to use the timer stages T1 1pole and T1 3pole according to Figure 2 193 Figure 2 192 Single stage breaker failure protection with common phase initiation Figure 2 193 Single stage breaker failure pr...

Page 405: ...2StartCriteria is used to set whether the delay time T2 will be started after expiry of T1 T2StartCriteria With exp of T1 or simultaneously with it T2StartCriteria Parallel withT1 The time T2 can also be initiated via a separate binary input 1424 BF STARTonlyT2 Figure 2 194 Logic diagram of the two stage breaker failure protection ...

Page 406: ...t the remote line end is often also desired This requires the command to be transmitted In case of 7SD5 the corresponding command usually the trip command which is intended to trip the adjacent breakers is assigned to the input function for intertrip of the devices This can be achieved by external wiring The command output is connected to the binary input Intertrip 3pol No 3504 see also Section 2 ...

Page 407: ...ip signal is transmitted to the opposite end s of the protected object Figure 2 197 Functional scheme of the end fault protection Pole discrepancy supervision The pole discrepancy supervision has the task to detect discrepancies in the position of the three circuit breaker poles Under steady state operating conditions either all three poles of the circuit breaker must be closed or all three poles ...

Page 408: ... 139 enabled w 3I0 the pickup threshold for the zero sequence current 3I0 BF address 3912 can be set independently of I BF Normally the circuit breaker failure protection evaluates the current flow criterion as well as the position of the circuit breaker auxiliary contact s If the auxiliary contact s status is not available in the device this criterion cannot be processed In this case set address ...

Page 409: ... delay times are set dependant on the maximum operating time of the feeder circuit breaker and the reset time of the current detectors of the circuit breaker failure protection plus a safety margin which allows for any tolerance of the delay timers Figure 2 199 illustrates the timing of a typical circuit breaker failure scenario The dropout time for sinusoidal currents is 15 ms If current transfor...

Page 410: ...it breaker the reset time of the current detectors of the circuit breaker failure protection plus a safety margin which allows for any tolerance of the delay timers The time sequence is illustrated in Figure 2 200 The dropout time for sinusoidal currents is 15 ms If current transformer saturation is anticipated the time should be set to 25 ms Figure 2 200 Time sequence example for normal clearance...

Page 411: ...rip signal to the remote end circuit breaker Thus the delay time must be set so that it can bridge out short transient apparent end fault conditions which may occur during switching of the circuit breaker Pole discrepancy supervision In address 3931 PoleDiscrepancy pole discrepancy protection the pole discrepancy supervision can be switched separately ON or OFF It is only useful if the circuit bre...

Page 412: ...p 3905 T1 3pole 0 00 30 00 sec 0 00 sec T1 Delay after 3pole start local trip 3906 T2 0 00 30 00 sec 0 15 sec T2 Delay of 2nd stage busbar trip 3907 T3 BkrDefective 0 00 30 00 sec 0 00 sec T3 Delay for start with de fective bkr 3908 Trip BkrDefect NO with T1 trip with T2 trip w T1 T2 trip NO Trip output selection with defective bkr 3909 Chk BRK CONTACT NO YES YES Check Breaker contacts 3912 3I0 BF...

Page 413: ...rFailON offBI IntSP Breaker failure prot ON OFF via BI 1451 BkrFail OFF OUT Breaker failure is switched OFF 1452 BkrFail BLOCK OUT Breaker failure is BLOCKED 1453 BkrFail ACTIVE OUT Breaker failure is ACTIVE 1461 BF Start OUT Breaker failure protection started 1472 BF T1 TRIP 1pL1 OUT BF Trip T1 local trip only phase L1 1473 BF T1 TRIP 1pL2 OUT BF Trip T1 local trip only phase L2 1474 BF T1 TRIP 1...

Page 414: ...s set the device only generates an alarm even if the end temperature is reached The overtemperatures are calculated separately for each phase in a thermal replica from the square of the as sociated phase current This guarantees a true RMS value measurement and also includes the effect of har monic content A choice can be made whether the maximum calculated overtemperature of the three phases the a...

Page 415: ...ctor k is set under address 4202 K FACTOR It is determined by the relation between the permissible thermal continuous current and this nominal current The permissible continuous current is at the same time the current at which the e function of the overtemper ature has its asymptote It is not necessary to determine the tripping temperature since it results automatically from the final rise tempera...

Page 416: ...5 s t6 time this is the time in seconds for which a current of 6 times the nominal current of the protected object may flow Example Cable as above with Permissible 1 s current 13 5 kA Setting value TIME CONSTANT 29 4 min Alarm levels By setting a thermal alarm stage Θ ALARM address 4204 an alarm can be provided before the tripping tem perature is reached so that a trip can be avoided by preventive...

Page 417: ...y rate 2 23 3 Settings The table indicates region specific presettings Column C configuration indicates the corresponding second ary nominal current of the current transformer 2 23 4 Information List Addr Parameter C Setting Options Default Setting Comments 4201 Ther OVERLOAD OFF ON Alarm Only OFF Thermal overload protec tion 4202 K FACTOR 0 10 4 00 1 10 K Factor 4203 TIME CONSTANT 1 0 999 9 min 1...

Page 418: ...ms do not disturb the operational readiness of the device see for the Technical Data The processor monitors the reference voltage of the ADC analog to digital converter The protection is sus pended if the voltages deviate outside an allowable range and persistent deviations are reported Back up Battery The buffer battery which ensures the operation of the internal clock and the storage of counters...

Page 419: ...ate IE transformer e g cable core balance current transformer ΣI THRESHOLD and ΣI FACTOR are setting parameters The component ΣI FACTOR Σ I takes into account permissible current proportional ratio errors of the input transformers which are particularly prevalent during large fault currents Figure 2 202 Σ I is the sum of all currents Σ I IL1 IL2 IL3 kI IE As soon as the current summation supervisi...

Page 420: ...ith complete restart An additional software watchdog ensures that malfunctions during the processing of programs are discovered This also initiates a restart of the processor system If the fault is not eliminated by the restart a second restart attempt is initiated If the fault is still present after three restart attempts within 30 s the protection system will take itself out of service and the r...

Page 421: ...e smallest phase voltage is compared to the largest Asym metry is recognized if Umin Umax BAL FACTOR U as long as Umax BALANCE U LIMIT Thereby Umax is the largest of the three phase to phase voltages and Umin the smallest The symmetry factor BAL FACTOR U address 2903 represents the allowable asymmetry of the voltages while the limit value BALANCE U LIMIT address 2902 is the lower limit of the oper...

Page 422: ... current has dropped to 0 A In case of a 1 1 2 circuit breaker arrangement the current will not necessarily jump to 0 in case of a wire break because the second primary current transformer will continue to measure one part of the phase current this means that the current of the affected phase will simply jump to a different value For such circuit breaker ar rangements parameter 2935 ΔI min is used...

Page 423: ... have measured a phase current of more than 2 IN 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 critera it is signalled via the protection data in terface to the other devices of the constellation and leads immediately to a wire break message The differen tial protection functions are blocked as well if ...

Page 424: ...Functions 2 24 Monitoring Functions SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 424 Figure 2 206 Broken wire monitoring ...

Page 425: ...ical Measuring Voltage Failure Fuse Failure Monitor In the event of a measured 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 existing load currents may then cause a spurious pickup If fuses are used instead of a voltage transformer miniature circuit breaker...

Page 426: ...The immediate blocking requires that current flows in at least one of the phases The distance protection can be switched to differential protection and or O C emergency operation provided that these functions are pa rameterized accordingly refer also to Sections 2 3 and 2 16 The immediate effect of the Fuse failure monitor is signaled by means of the indication VT FuseFail No 170 To detect an asym...

Page 427: ...maller than the threshold FFM Idelta 3p address 2914 All 3 phase current amplitudes are larger than the minimum current Iph address 1502 for impedance measurement of the distance protection If such a voltage failure is recognized the distance protection and all other functions that operate on the basis of undervoltage e g also weak infeed tripping are blocked until the voltage failure is removed t...

Page 428: ...209 shows the logic diagram of the measured voltage failure monitoring A failure of the measured voltage is detected if the following conditions are met at the same time All 3 phase to earth voltages are less than FFM U max 3ph At least 1 phase current is larger than PoleOpenCurrent or at least 1 breaker pole is closed can be set No protection function has picked up This condition persists for a s...

Page 429: ... and the binary input of the VT miniature circuit breaker FAIL Feeder VT no 361 Figure 2 210 Effect of the measuring voltage failure 2 24 1 4 Monitoring the Phase Angle of the Positive Sequence Power This monitoring function allows determining the direction of power flow You can monitor the phase angle of the complex power and generate an indication when the power phasor is inside a settable segme...

Page 430: ...G1176 C169 5 Release date 02 2011 430 Figure 2 211 Characteristic of the Positive Sequence System Phase Angle Monitoring The monitoring function can also be used for the display of negative active power In this case the areas must be defined as shown in Figure 2 212 ...

Page 431: ... than the value set in parameter 2943 I1 The positive sequence voltage U1 is higher than the value set in parameter 2944 U1 The angles set in address 2941 ϕA and 2942 ϕB must be at least 3 apart Incorrect parameter settings cause the indication 132 ϕ Set wrong to be output The Fuse Failure Monitor and the measured voltage failure monitoring must not have responded and binary input indication 361 F...

Page 432: ...e is taken out of operation After three unsuccessful restart attempts the device is taken out of service The device ready relay drops out and indicates the device failure with its NC contact life contact The red LED ERROR on the device front lights up provided that there is an internal auxiliary voltage and the green LED RUN goes off If the internal auxiliary voltage supply fails all LEDs are dark...

Page 433: ...Jumper setting 1 5 A incorrect Indications Protection out of opera tion Error1A 5Awrong 192 Error A D conv 181 LED ERROR DOK2 drops out Adjustment values Internal EEPROM or RAM Indication using default values Alarm adjustm 193 As allocated Earth current transform er sensitive insensitive I O module does not comply with the order number MLFB of the device Indications Protection out of opera tion Er...

Page 434: ...sin gle two phase Fuse Failure Monitor External voltage transformers Indication Distance protection blocked Undervoltageprotection blocked Weak infeed tripping blocked Frequency protection blocked and Direction determination of the earth fault protec tion blocked VT FuseFail 10s 169 VT FuseFail 170 As allocated Voltage failure three phase External power system or connection Indication Distance pro...

Page 435: ...ce no 163 can be delayed at address 2909 T BAL I LIMIT These settings can only be changed using DIGSI at Additional Settings Sum monitoring Address 2906 ΣI THRESHOLD determines the limit current above which the current sum monitoring is activat ed absolute portion only relative to IN The relative portion relative to the maximum phase current for acti vating the current sum monitoring is set at add...

Page 436: ...o address 1502 Minimum Iph a three phase measured voltage failure is recognized These settings can only be changed via DIGSI at Display Ad ditional Settings In address 2910 FUSE FAIL MON the Fuse Failure Monitor e g during asymmetrical testing can be switched OFF Measured voltage failure monitoring In address 2915 V Supervision the measured voltage supervision can be switched to w CURR SUP w I CBa...

Page 437: ... 0 10 2 00 A 0 25 A Summated Current Moni toring Threshold 5A 0 50 10 00 A 1 25 A 2907A ΣI FACTOR 0 00 0 95 0 50 Summated Current Moni toring Factor 2908A T BAL U LIMIT 5 100 sec 5 sec T Balance Factor for Voltage Monitor 2909A T BAL I LIMIT 5 100 sec 5 sec T Current Balance Monitor 2910 FUSE FAIL MON ON OFF ON Fuse Failure Monitor 2911A FFM U min 10 100 V 30 V Minimum Voltage Thresh old U 2912A F...

Page 438: ... 169 VT FuseFail 10s OUT VT Fuse Failure alarm 10s 170 VT FuseFail OUT VT Fuse Failure alarm instantaneous 171 Fail Ph Seq OUT Failure Phase Sequence 196 Fuse Fail M OFF OUT Fuse Fail Monitor is switched OFF 197 MeasSup OFF OUT Measurement Supervision is switched OFF 289 Failure Σi OUT Alarm Current summation supervision 290 Broken Iwire L1 OUT Alarm Broken current wire detected L1 291 Broken Iwir...

Page 439: ...ch circuit breaker pole provided that the required binary inputs are available 2 24 2 1 Functional Description Supervision with Two Binary Inputs When using two binary inputs these are connected according to Figure 2 214 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 supervision ...

Page 440: ... an abnormality a fault indication is output see Figure 2 215 The repeated measurements determine the delay of the alarm message and avoid that an alarm is output during short transition periods After clearance of the failure in the trip circuit the failure alarm automatically resets with the same time delay Figure 2 215 Logic diagram of the trip circuit supervision with two binary inputs Supervis...

Page 441: ...reaker auxiliary contact if the circuit breaker is closed or through the bypass resistor R Only as long as the trip contact is closed the binary input is short circuited and thereby deactivated logical condition L If the binary input is permanently deactivated during operation an interruption in the trip circuit or a failure of the trip control voltage can be assumed The trip circuit supervision d...

Page 442: ...cted to the trip circuits as the trip circuit supervision does not operate during a system fault If however trip contacts from other devices are connected in parallel in the trip circuit the alarm must be delayed such that the longest trip command duration can be reliably bridged 2 24 2 3 Settings 2 24 2 4 Information List Addr Parameter Setting Options Default Setting Comments 4001 FCT TripSuperv...

Page 443: ...s may be required or desirable Following a manual closure onto a short circuit immediate trip of the circuit breaker is usually desired This is done e g in the overcurrent protection by bypassing the delay time of a current stage For every short circuit protection function which can be delayed at least one stage can be selected that will operate instantaneously in the event of a closing as mention...

Page 444: ...tegrated manual closure logic of the 7SD5 automat ically distinguishes between an external control command via the binary input and an automatic reclosure by the internal automatic reclosure so that the binary input Manual Close can be connected directly to the control circuit of the close coil of the circuit breaker Figure 2 219 Each closing operation that is not initiated by the internal automat...

Page 445: ...on 2 1 4 at margin heading Circuit Breaker Status The phase currents and the phase to earth voltages are available as measuring quantities A flowing current excludes that the circuit breaker is open exception a fault between current transformer and circuit breaker If the circuit breaker is closed it may however still occur that no current is flowing The voltages can only be used as a criterion for...

Page 446: ...rcurrent protec tion and high current switch onto fault protection to trip without delay after energization of their line was detect ed Depending on the configuration of the distance protection an undelayed trip command can be generated after energization for each pickup or for pickup in zone Z1B The stages of the earth fault protection and of the time overcurrent protection generate an undelayed ...

Page 447: ... be switched individually and if the individual auxiliary contacts are available an individual binary input should be used for each auxiliary contact if this is possible and if the device can and is to trip 1 pole With this configuration the device can process the maximum amount of information Three binary inputs are used for this purpose CB Aux L1 No 351 for the auxiliary contact of pole L1 CB Au...

Page 448: ... In 7SD5 the position of the circuit breaker poles detected by the device is also transmitted to the remote end device s This way the circuit breaker positions of all ends are known at all ends The highcurrent switch on to fault protection Section 2 14 makes use of this function Figure 2 222 Circuit breaker position logic ...

Page 449: ...it breaker can be connected separately to the device For this separate binary inputs are available which should be treated the same and configured additionally if necessary These have a similar significance as the inputs described above for protection applications and are marked with CB1 to distinguish them i e CB1 3p Closed No 410 for the series connection of the NO auxiliary contacts of the CB C...

Page 450: ...Functions 2 25 Function Control and Circuit Breaker Test SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 450 Figure 2 223 Open pole detector logic ...

Page 451: ...ls of all protection functions In the case of those protection functions that allow for phase segregated pickup the pickup is output in a phase segregated manner If a protection function detects an earth fault this is also output as a common device alarm Thus the alarms Relay PICKUP L1 Relay PICKUP L2 Relay PICKUP L3 and Relay PICKUP E are available The above indications can be allocated to LEDs o...

Page 452: ...ead lines on which automatic reclosure is to be carried out and where the circuit breakers at both ends of the line are capable of single pole tripping Single pole tripping of the faulted phase with subsequent reclosure is then possible for single phase faults three pole tripping is generally performed in case of two phase or three phase faults with and without earth Device prerequisites for phase...

Page 453: ...se indications is displayed at a time Single pole tripping for two phase faults Single pole tripping for two phase faults is a special feature If a phase to phase fault without earth occurs in an earthed system this fault can be cleared by single pole trip and automatic reclosure in one of the faulted phases as the short circuit path is interrupted in this manner The phase selected for tripping mu...

Page 454: ... opened in the event of single pole tripping the relevant circuit breaker pole In the function control of the device this is checked by means of the circuit breaker position feedback Section Detection of the Circuit Breaker Position and the flow of cur rent In address 1130 PoleOpenCurrent the residual current threshold which may definitely not be exceed ed when the circuit breaker pole is open is ...

Page 455: ...eclosure is used 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 is not activated when an automatic reclosure is still expected In the simplest case you can route t...

Page 456: ...ontact opens so that the tripping of the circuit breaker is not passed on This is only the case if the device is equipped with internal au tomatic reclosure and if the latter was taken into consideration when configuring the protection functions ad dress 133 Also when closing the breaker via the binary input Manual Close No 356 or via the integrated automatic reclosure the contact is interrupted s...

Page 457: ... DIGSI The procedure is described in detail in the SIPROTEC 4 System Description Figure 2 228 shows the chronological sequence of one TRIP CLOSE test cycle The set times are those stated in Section 2 1 2 1 for Trip Command Duration and Circuit Breaker Test Where the circuit breaker auxiliary contacts indicate the status of the circuit breaker or of its poles to the device via binary inputs the tes...

Page 458: ...mments CB1tst L1 CB1 TEST trip close Only L1 CB1tst L2 CB1 TEST trip close Only L2 CB1tst L3 CB1 TEST trip close Only L3 CB1tst 123 CB1 TEST trip close Phases L123 7325 CB1 TESTtrip L1 OUT CB1 TEST TRIP command Only L1 7326 CB1 TESTtrip L2 OUT CB1 TEST TRIP command Only L2 7327 CB1 TESTtrip L3 OUT CB1 TEST TRIP command Only L3 7328 CB1 TESTtrip123 OUT CB1 TEST TRIP command L123 7329 CB1 TEST close...

Page 459: ...sage appears automatically on the display YES or not NO For devices with text display such indi cations will appear anyway after a power system fault Figure 2 229 Generation of spontaneous fault indications on the display Reset of Stored LED Relays Pickup of a new protection function generally deletes all stored LED relays so that only the information of the latest fault is displayed at a time The...

Page 460: ...Notes Fault Annunciations Pickup of a new protection function generally turns off any previously set displays so that only the latest fault is displayed at any one time It can be selected whether the stored LED displays and the spontaneous indica tions on the display appear upon renewed pickup or only after a renewed trip signal is issued In order to enter the desired type of display select the su...

Page 461: ...Stop IntSP Stop data transmission UnlockDT IntSP Unlock data transmission via BI Reset LED IntSP Reset LED SynchClock IntSP_Ev Clock Synchronization Light on SP Back Light on HWTestMod IntSP Hardware Test Mode Error FMS1 OUT Error FMS FO 1 Error FMS2 OUT Error FMS FO 2 Distur CFC OUT Disturbance CFC Brk OPENED IntSP Breaker OPENED FdrEARTHED IntSP Feeder EARTHED 3 Time Synch SP Synchronize Interna...

Page 462: ...re Battery empty 181 Error A D conv OUT Error A D converter 183 Error Board 1 OUT Error Board 1 184 Error Board 2 OUT Error Board 2 185 Error Board 3 OUT Error Board 3 186 Error Board 4 OUT Error Board 4 187 Error Board 5 OUT Error Board 5 188 Error Board 6 OUT Error Board 6 189 Error Board 7 OUT Error Board 7 190 Error Board 0 OUT Error Board 0 191 Error Offset OUT Error Offset 192 Error1A 5Awron...

Page 463: ...rogeneous environments In parallel to the process control integration of the device this interface can also be used for communication with DIGSI and for inter relay communication via GOOSE 2 25 4 2 Setting Notes Interface Selection No settings are required for operation of the Ethernet system interface module IEC 61850 EN100 Modul 1 If the device is equipped with such a module see MLFB the module ...

Page 464: ... device can be simulated using the mouse pointer This feature can be disabled If the device is equipped with an EN100 module operation by DIGSI or the WEB Monitor is possible via Ether net This is done by simply setting the IP configuration of the device accordingly Parallel operation of DIGSI and WEB Monitor via different interfaces is possible WEB Monitor The WEB Monitor is a comprehensive commi...

Page 465: ... display of the most important measuring data and of the distance protection data required for the directional check The measured values list can be selected from the navigation toolbar separately for the local device and remote devices In each case a list with the desired infor mation is displayed see Figure 2 231 and 2 233 Figure 2 232 Local measured values in the WEB Monitor Examples for measur...

Page 466: ...ons buffer event log Fault indications buffer trip log Spontaneous Indications You can print these lists with the Print event buffer button 2 26 1 2 Setting Notes The parameters of the WEB Monitor can be set separately for the front operator interface and the service in terface The relevant IP address of the interface is the one that is used for communication with the PC and the WEB Monitor Make s...

Page 467: ... abnormal occurrence or if the auxiliary voltage fails When auxiliary voltage is present but the relay has an internal malfunction the red LED ERROR lights up and the processor blocks the relay DIGSI enables you to selectively control each output relay and LED of the device and in doing so check the correct connection to the system In a dialog box you can for instance cause each output relay to pi...

Page 468: ...s 1 ms With a PC and the DIGSI protection data processing software it is also possible to retrieve and display the events with the convenience of visualisation on a monitor and a menu guided dialog The data can either be printed out or stored elsewhere for later evaluation Information to a Control Centre If the device has a serial system interface stored information may additionally be transferred...

Page 469: ... time Faults in the power system are indicated with Network Fault and the present fault number The fault indications contain detailed information on the response during system faults Fault Indications Following a system fault it is possible to retrieve important information regarding its progress such as pickup and trip The system clock accurately provides the absolute time when the fault first oc...

Page 470: ...us indications can be read out via DIGSI For more information see the SIPROTEC 4 System De scription General Interrogation The present condition of the SIPROTEC 4 device can be retrieved via DIGSI by viewing the contents of the General Interrogation It shows all indications that are subject to general interrogation with their current value 2 26 3 Statistics Counting includes the number of trips in...

Page 471: ...red and indicated as long as GPS synchronization is intact 2 26 3 2 Information List No Information Type of In formation Comments 1000 TRIPs VI Number of breaker TRIP commands 1001 TripNo L1 VI Number of breaker TRIP commands L1 1002 TripNo L2 VI Number of breaker TRIP commands L2 1003 TripNo L3 VI Number of breaker TRIP commands L3 1027 Σ IL1 VI Accumulation of interrupted current L1 1028 Σ IL2 V...

Page 472: ...rth If multiple devices are connected via their protection data interfaces a common frequency value is calculated via the constellation constellation frequency This value is displayed as the operational measured value Fre quency 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 differential protecti...

Page 473: ... Phase angle of the phase voltages towards the phase currents U1 U2 Positive and negative sequence component of the voltages kV V Nominal operational voltage 3 2 UX UEN Voltage at measuring input U4 V Usy2 Voltage at measuring input U4 kV V Operational rated voltage or Operational rated voltage 32 4 5 U1compound Positive sequence component of volt ages at the remote end if compound ing is active i...

Page 474: ...MV U L12 625 UL23 MV U L23 626 UL31 MV U L31 627 Uen MV Uen 631 3U0 MV 3U0 zero sequence 632 Usy2 MV Measured value Usy2 633 Ux MV Ux separate VT 634 U1 MV U1 positive sequence 635 U2 MV U2 negative sequence 636 Udiff MV Measured value U diff Usy1 Usy2 637 Usy1 MV Measured value Usy1 638 Usy2 MV Measured value Usy2 641 P MV P active power 642 Q MV Q reactive power 643 PF MV Power Factor 644 Freq M...

Page 475: ...2 R L23 MV R L23 973 R L31 MV R L31 974 X L1E MV X L1E 975 X L2E MV X L2E 976 X L3E MV X L3E 977 X L12 MV X L12 978 X L23 MV X L23 979 X L31 MV X L31 7731 Φ IL1L2 MV PHI IL1L2 local 7732 Φ IL2L3 MV PHI IL2L3 local 7733 Φ IL3L1 MV PHI IL3L1 local 7734 Φ UL1L2 MV PHI UL1L2 local 7735 Φ UL2L3 MV PHI UL2L3 local 7736 Φ UL3L1 MV PHI UL3L1 local 7737 Φ UIL1 MV PHI UIL1 local 7738 Φ UIL2 MV PHI UIL2 loca...

Page 476: ...hases Nominaloperational current 1 IRestL1 IRestL2 IRestL3 Calculated restraint currents of the three phases Nominaloperational current 1 IDiff 3I0 Calculated differential current of the zero sequence system Nominaloperational current 1 IcL1 IcL2 IcL3 Measured charging currents of the three phases Nominal operational current No Information Type of In formation Comments 7742 IDiffL1 MV IDiffL1 Oper...

Page 477: ...local end 98 angle 180 By means of the device address the devices can be distinguished one from another Via the device address a polarity reversal of the current transformer can be detected immediately and the line angle can be read if voltages are available Table 2 23 Constellation measured values for device 1 No Information Info type Explanation 7761 Relay ID MW Device address of the first devci...

Page 478: ...ice has a serial system interface the fault recording data can be passed on to a central device via this interface The data is evaluated by applicable programs in the central device The measured quantities are re ferred to their maximum values scaled to their rated values and prepared for graphic representation Binary signal traces marks of particular events e g fault detection tripping are also r...

Page 479: ... then the length of the record equals the time that the binary input is activated static or the MAX LENGTH setting in address 410 which ever is shorter 2 26 7 3 Settings Addresses which have an appended A can only be changed with DIGSI under Additional Settings 2 26 7 4 Information List Addr Parameter Setting Options Default Setting Comments 402A WAVEFORMTRIGGE R Save w Pickup Save w TRIP Start w ...

Page 480: ...value averaging is set at address 2801 DMD Interval The first number spec ifies 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 that time averaging occurs for all measured values that arrive within 15 minutes The output is updated every 15 3 5 minutes At address 2802 DMD Sync Time you can determine w...

Page 481: ...place is set at address 2812 MiMa RESET TIME The reset cycle in days is entered at address 2813 MiMa RESETCYCLE and the beginning date of the cyclical process from the time of the setting procedure in days is entered at address 2814 MinMaxRES START 2 26 9 3 Settings No Information Type of In formation Comments 833 I1dmd MV I1 positive sequence Demand 834 Pdmd MV Active Power Demand 835 Qdmd MV Rea...

Page 482: ...Buffer Reset 837 IL1d Min MVT I L1 Demand Minimum 838 IL1d Max MVT I L1 Demand Maximum 839 IL2d Min MVT I L2 Demand Minimum 840 IL2d Max MVT I L2 Demand Maximum 841 IL3d Min MVT I L3 Demand Minimum 842 IL3d Max MVT I L3 Demand Maximum 843 I1dmdMin MVT I1 positive sequence Demand Minimum 844 I1dmdMax MVT I1 positive sequence Demand Maximum 845 PdMin MVT Active Power Demand Minimum 846 PdMax MVT Act...

Page 483: ...ceeded the limit value monitoring functions do not react as fast as protection functions trip signals 867 UL12Max MVT U L12 Maximum 868 UL23Min MVT U L23 Minimum 869 UL23Max MVT U L23 Maximum 870 UL31Min MVT U L31 Minimum 871 UL31Max MVT U L31 Maximum 874 U1 Min MVT U1 positive sequence Voltage Minimum 875 U1 Max MVT U1 positive sequence Voltage Maximum 880 SMin MVT Apparent Power Minimum 881 SMax...

Page 484: ...t power factor 2 26 10 2Setting Notes Set Points for Measured Values The settings are entered under MEASUREMENT in the sub menu SET POINTS MV MV by overwriting the existing values 2 26 10 3Information List No Information Type of In formation Comments IL1dmd LV Upper setting limit for IL1dmd IL2dmd LV Upper setting limit for IL2dmd IL3dmd LV Upper setting limit for IL3dmd I1dmd LV Upper setting lim...

Page 485: ...ers normally protection core and the device tolerances The metering is therefore not suited for tariff purposes The counters can be reset to zero or any initial value see also SIPROTEC 4 System Description Table 2 24 Operational metered values 2 26 11 2Setting Notes Retrieving parameters The SIPROTEC System Description describes in detail how to read out the statistical counters via the device fro...

Page 486: ...7 1 1 Type of Commands Commands to the Process These commands are directly output to the switchgear to change their process state Commands for the operation of circuit breakers asynchronous or synchronized through integration of the synchronism check and closing control function as well as commands for the control of isolators and earth switches Step commands e g for raising and lowering transform...

Page 487: ...inst parallel switching operation Protection blocking blocking of switching operations by protection functions Checking the synchronism before a close command Fixed commands Internal process time software watch dog which checks the time for processing the control action between initiation of the control and final close of the relay contact Configuration in process if setting modification is in pro...

Page 488: ...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 De interlocked or non interlocked switching means that the configured interlock conditions are not tested Interlocked switching means that all configured interlocking co...

Page 489: ...hecks for each switchgear which were set during the configuration of inputs and outputs see SIPROTEC 4 System Description An overview for processing the interlocking conditions in the relay is shown in Figure 2 238 Figure 2 238 Standard interlockings 1 Source of Command REMOTE includes LOCAL LOCAL Command using substation controller REMOTE Command via telecontrol station to power system management...

Page 490: ...ndicated Figure 2 239 Example of configured interlocking conditions Control Logic via CFC For bay interlocking a release logic can be created using CFC Via specific release conditions the information released or bay interlocked are available e g object Release CD Close and Release CD Open with the information values ON OFF 2 27 1 4 Information List Interlocking Commands Command Display Switching A...

Page 491: ...n Brk Close IntSP Interlocking Breaker Close Disc Open IntSP Interlocking Disconnect switch Open Disc Close IntSP Interlocking Disconnect switch Close E Sw Open IntSP Interlocking Earth switch Open E Sw Cl IntSP Interlocking Earth switch Close Q2 Op Cl CF_D2 Q2 Open Close Q2 Op Cl DP Q2 Open Close Q9 Op Cl CF_D2 Q9 Open Close Q9 Op Cl DP Q9 Open Close Fan ON OFF CF_D2 Fan ON OFF Fan ON OFF DP Fan ...

Page 492: ...the serial digital interface The acknowledgement of commands is therefore not executed by a response indication as it is done with the local command but by ordinary command and feedback information recording Feedback monitoring Command processing time monitors all commands with feedback Parallel to the command a monitoring time period command runtime monitoring is started which checks whether the ...

Page 493: ...formation Type of In formation Comments Door open SP Cabinet door open CB wait SP CB waiting for Spring charged Err Mot U SP Error Motor Voltage ErrCntrlU SP Error Control Voltage SF6 Loss SP SF6 Loss Err Meter SP Error Meter Tx Temp SP Transformer Temperature Tx Danger SP Transformer Danger No Information Type of In formation Comments SysIntErr IntSP Error Systeminterface ...

Page 494: ...Functions 2 27 Command Processing SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 494 ...

Page 495: ...g of protection and control systems with the management of power systems and with the relevant safety rules and guidelines Under certain circumstances adaptations of the hardware to the particular power system data may be necessary The primary tests require the protected object line transformer etc to carry load 3 1 Mounting and Connections 496 3 2 Checking Connections 525 3 3 Commissioning 531 3 ...

Page 496: ...nnection examples for current transformer and voltage trans former circuits are provided in Appendix A 3 It must be checked that the setting of the P System Data 1 Section 2 1 2 1 was made in accordance to the device connections Currents Appendix A 3 shows current transformer connection examples in dependence on network conditions For normal connection address 220 I4 transformer In prot line must ...

Page 497: ...compensated for the synchronism check if used In this case also check the addresses 212 Usy2 connection 214 ϕ Usy2 Usy1 and 215 Usy1 Usy2 ratio You will find detailed notes and an example in Section 2 1 2 1 under Voltage connection Binary Inputs and Outputs The connections to the power plant depend on the possible allocation of the binary inputs and outputs i e how they are assigned to the power e...

Page 498: ... w not be communed with each other or with another binary input If one binary input is used a bypass resistor R must be inserted see following figure The resistor R is con nected in series with the second circuit breaker auxiliary contact Aux2 to allow the detection of a trip circuit failure even when circuit breaker auxiliary contact Aux1 is open and the command relay has dropped out The value of...

Page 499: ...imension Rmax and a lower limit Rmin from which the optimal value of the arithmetic mean R should be selected In order that the minimum voltage for controlling the binary input is ensured Rmax is derived as To keep the circuit breaker trip coil not energized in the above case Rmin is derived as IBI HIGH Constant current with activated BI 1 8 mA UBI min Minimum control voltage for BI 17 V for deliv...

Page 500: ...10 V to 125 V and the threshold of 154 V for 220 V to 250 V Due to the low current consumption of the binary inputs it may be necessary to additionally burden the pilot wire loop with an external shunt connected resistor so that the binary inputs are not blocked by the wire capacitance after an interruption of the loop Alternatively auxiliary relay combinations can be connected Pilot wires used as...

Page 501: ...nges for the auxiliary voltage refer to the Ordering Information in Appendix A 1 The versions for DC 60 V 110 V 125 V and DC 110 V 125 V 220 V 250 V AC 115 V are inter convertible Jumper settings determine the rating The assignment of these jumpers to the nominal voltage ranges and the spatial layout on the PCB are described further below at Input Output Module C I O 1 and Input Output Module C I ...

Page 502: ...r The following sections under Switching Elements on Printed Circuit Boards describe for which relays on which boards this is the case Exchanging Interfaces The serial interfaces can only be replaced in devices designed for panel flush and cubicle mounting and for surface mounted devices with a detached operator panel The following section under margin heading Replac ing Interface Modules describe...

Page 503: ...e a suitable pad for electrostatically sensitive devices ESD Also the follow ing tools are required screwdriver with a 5 to 6 mm wide tip a crosstip screwdriver for Pz size 1 a 5 mm socket wrench Unfasten the screw posts of the D subminiature connectors on the back panel at location A This activity does not apply if the device is for surface mounting If the device has more communication interfaces...

Page 504: ...Disconnect the plug connector of the ribbon cable between processor board C CPU 1 No 1 in Figure 3 3 or 3 4 and the I O input output modules depending on order variant No 2 to No 3 in Figure 3 3 or No 2 to 4 in Figure 3 4 Remove the boards and place them on a surface suitable for electrostatically sensitive devices ESD In devices designed for panel surface mounting a certain amount of force is req...

Page 505: ... Commissioning 3 1 Mounting and Connections SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 505 Figure 3 4 Front view with housing size 1 1 after removal of the front cover simplified and scaled down ...

Page 506: ... O 1 with representation of the jumpers required for checking the setting The power supply is situated On the input output board C I O 1 No 2 in Figure 3 3 slot 19 for housing size 1 2 On the input output board C I O 1 No 2 in Figure 3 4 slot 33 left for housing size 1 1 The preset nominal voltage of the integrated power supply is checked according to Table 3 2 the quiescent state of the life cont...

Page 507: ...for the binary output BO24 Figure 3 4 slot 19 left Table 3 4 shows the jumper settings for the contact mode Table 3 4 Jumper settings for contact mode of the binary outputs BO16 and BO24 on the input output board C I O 1 Checking the control voltages of the binary inputs BI1 to BI8 with housing size 1 2 according to Table 3 5 BI1 to BI24 with housing size 1 1 depending on version according to Tabl...

Page 508: ...ces with rated supply voltages of DC 110 V to 250 V and AC 115 V 3 Factory settings for devices with rated supply voltages of DC 220 V to 250 V and AC 115 V Two different releases of the input output module CI O 10 are available Figure 3 6 shows the layout of the printed circuit board for devices up to release 7SD5 EE figure 3 7 depicts the printed circuit board layout for devices 7SD5 FF Binary i...

Page 509: ...IPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 509 Input output module C I O 10 up to release EE Figure 3 6 Input output board C I O 10 up to release 7SD5 EE with representation of the jumper settings required for checking configuration settings ...

Page 510: ...3 Factory settings for devices with rated supply voltages of DC 220 V to 250 V and AC 115 V Table 3 8 Jumper settings of the module address of the input output module C I O 1 or C I O 10 up to release 7SD5 EE with housing size 1 1 Binary inputs Jumper Threshold 17 V 1 Threshold 73 V 2 Threshold 154 V 3 Slot 33 left side Slot 19 right side Slot 19 left side BI1 BI9 BI17 X21 X22 L M H BI2 BI10 BI18 ...

Page 511: ...OTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 511 Input output module C I O 10 release FF and higher Figure 3 7 Input output board C I O 10 release 7SD5 FF or higher with representation of jumper settings required for checking configuration settings ...

Page 512: ...gs for devices with rated supply voltages of DC 110 V to 250 V and AC 115 V 3 Factory settings for devices with rated supply voltages of DC 220 V to 250 V and AC 115 V Table 3 10 Jumper setting of the module address of the input output module C I O 10 for release 7SD5 FF and higher with housing size 1 1 Binary inputs slot 19 Jumper Threshold 17 V 1 Threshold 73 V 2 Threshold 154 V 3 B9 X21 L M H B...

Page 513: ...printed circuit board is shown in Figure 3 8 for devices of release 7SD5 FF and higher it is shown in Figure 3 9 Figure 3 8 Input output board C I O 2 up to release 7SD5 EE with representation of the jumper settings required for checking configuration settings The contact of the relay for the binary output BO13 can be configured as NO or NC contact see also General Diagrams in Appendix A Section A...

Page 514: ...umper X60 But In the version with sensitive earth fault current input input transformer T8 there is no jumper X64 Jumpers X71 X72 and X73 on the input output board C I O 2 are used to set the bus address and must not be changed The following table lists the jumper presettings Mounting location with housing size 1 2 No 3 in Figure 3 3 slot 33 with housing size 1 1 No 3 in Figure 3 4 slot 33 right T...

Page 515: ... earth fault detection PCB number C53207 A324 B50 Variant with sensitive earth fault detection PCB number C53207 A324 B60 A table imprinted on the printed circuit board indicates the respective PCB number The nominal current or measuring range settings are checked on the input output board C I O 2 Figure 3 9 Input output board C I O 2 release 7SD5 FF or higher with representation of the jumper set...

Page 516: ... the Appendix Table 3 15 Jumper settings for the configuration of the common potential from BO8 to BO11 or for the setting of BO8 BO11 and BO12 as single relays 1 As supplied state Jumpers X71 X72 and X73 serve for setting the bus address Their position must not be changed The follow ing table shows the preset jumper positions Table 3 16 Jumper setting of the module addresses of the input output b...

Page 517: ... the processor board C CPU 1 No 1 in Figure 3 3 and 3 4 Figure 3 10 Processor board C CPU 1 with interface modules maximum configuration Note Surface mounted devices with fibre optics connection have their fibre optics module fitted in the inclined housing on the case bottom The CPU module however has an RS232 interface module which communicates electrically with the fibre optics module in the inc...

Page 518: ...odified to interface RS485 and vice versa see Figures 3 11 and 3 12 Figure 3 11 shows the location of the jumpers of the RS232 interface on the interface module Surface mounted devices with fibre optics connection have their fibre optics module fitted in the console housing on the case bottom The fibre optics module is controlled via an RS232 interface module at the asso ciated CPU interface slot ...

Page 519: ...he half duplex mode Please use the connection cable with order number 7XV5100 4 Jumper setting 1 2 This setting makes the modem signals available i e for a direct RS232 connection between the SIPROTEC 4 device and the modem this setting can be selected optionally We recommend to use a standard RS232 modem connection cable converter 9 pin to 25 pin Note For a direct connection to DIGSI with interfa...

Page 520: ...stors must be connected On the 7SD5 device this concerns the variants with RS485 or PROFIBUS7 DNP interfaces The terminating resistors are on the interface module which is located on the processor board C CPU 1 No 1 in Figure 3 3 and 3 4 The interface modules are displayed in Figure 3 12 and in Figure3 13 For the configuration of the terminating resistors both jumpers have to be plugged in the sam...

Page 521: ...n Figure 3 15 There are six covers and six holes for the full housing size 1 1 as indicated in Figure 3 16 Remove the 4 covers at the corners of the front cover for housing size 1 1 the two covers located centrally at the top and bottom also have to be removed The 4 or 6 elongated holes in the mounting bracket are re vealed and can be accessed Insert the device into the panel cut out and fasten it...

Page 522: ...ning 3 1 Mounting and Connections SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 522 Figure 3 15 Panel flush mounting of a device housing size 1 2 Figure 3 16 Panel flush mounting of a device housing size 1 1 ...

Page 523: ... four or six covers back into place Tighten fast the eight screws of the angle brackets in the rack or cabinet Connect a solid low impedance protective earthing at the rear of the device with at least one M4 screw The cross section of the earth wire must be equal to the cross section of any other control conductor connected to the device The cross section of the earth wire must be at least 2 5 mm ...

Page 524: ...st be equal to the cross sectional area of any other control conductor connected to the device It must thus be at least 2 5 mm2 Alternatively there is the possibility to connect the aforementioned earthing to the lateral earthing surface with at least one M4 screw Make the connections according to the circuit diagram via screw terminals connections for optical fibres and electrical communication m...

Page 525: ...ce and the Ethernet interface of the device The position of the connections can be seen in the following figures Figure 3 19 9 pin D subminiature female connectors Figure 3 20 Ethernet connector Operator Interface When the recommended communication cable is used correct connection between the SIPROTEC 4 device and the PC is automatically ensured See the Appendix A 1 for an ordering description of ...

Page 526: ...RTS signal with RS232 level when operated as RS485 Interface Pin 7 must therefore not be con nected RS485 Termination The RS485 interface is bus capable for half duplex service with the signals A A and B B with a common rela tive potential C C GND It is necessary to check that the terminating resistors are connected to the bus only at the last unit and not at other devices on the bus The jumpers f...

Page 527: ...g to EN 60825 1 For the protection data communication refer to the following section The transmission via fiber optics is particularly insensitive to electromagnetic interference and thus ensures gal vanic isolation of the connection Transmit and receive connections are shown with the symbols for trans mit and for receive The character idle state for the optical fibre interface is Light off If the...

Page 528: ...ied with the symbols for trans mit and for receive The visual check of the assignment of the transmission and reception channels is important For short distances laser class 1 is fulfilled if FO5 modules and the recommended fibres are used In other cases the laser output may be higher If using more than one device the connections of all protection data interfaces are checked according to the topol...

Page 529: ...ation The plant must first be switched off and earthed Connection examples for current transformer connections are provided in the Appendix A 3 Please observe the plant diagrams too Proceed as follows in order to check the system connections Protective switches for the power supply and the measured voltages must be opened Check the continuity of all current and voltage transformer connections agai...

Page 530: ...upply protection check the voltage level and if applicable the polarity of the voltage at the device terminals or at the connection modules The measured steady state current should correspond to the quiescent power consumption of the device Transient movement of the ammeter merely indicates the charging current of capacitors Remove the voltage from the power supply by opening the mcb Disconnect th...

Page 531: ...nditions to be firmly established before the device is re energized The limit values given in Technical Data must not be exceeded neither during testing nor during commission ing For tests with a secondary test equipment ensure that no other measurement voltages are connected and the trip and close commands to the circuit breakers are blocked unless otherwise specified DANGER Hazardous voltages du...

Page 532: ...PROTEC 4 System Description describes how to activate and deactivate test mode and blocked data transmission Note that when DIGSI is being used the program must be in the Online operating mode for the test features to be used 3 3 2 Checking Time Synchronisation Interface If external time synchronization sources are used the data of the time source antenna system time generator are checked see Sect...

Page 533: ...ning Do not under any circumstances check them by means of the testing mode during real operation performing transmission and reception of messages via the system interface Note After termination of the hardware test the device will reboot Thereby all annunciation buffers are erased If required these buffers should be extracted with DIGSI prior to the test The interface test is carried out using D...

Page 534: ...mitted to the central station test in Setpoint the desired options in the list which appears Make sure that each checking process is carried out carefully without causing any danger see above and refer to DANGER Click on Send and check whether the transmitted information reaches the control centre and shows the desired reaction Data which are normally linked via binary inputs first character are l...

Page 535: ...ia the system interface Note After termination of the hardware test the device will reboot Thereby all annunciation buffers are erased If required these buffers should be extracted with DIGSI prior to the test The hardware test can be carried out using DIGSI in the Online operating mode Open the Online directory by double clicking the operating functions for the device appear Click on Test the fun...

Page 536: ...iring between the output relay of the 7SD5 and the plant without having to generate the message that is assigned to the relay As soon as the first change of state for any of the output relays is initiated all output relays are separated from the internal device functions and can only be operated by the hardware test function This means that e g a TRIP command coming from a protection function or a...

Page 537: ... input is triggered and the password No 6 has been entered all binary inputs are separated from the system and can only be activated via the hardware test function Test of the LEDs The light emitting diodes LEDs may be tested in a similar manner to the other input output components As soon as the first state change of any LED has been triggered all LEDs are separated from the internal device funct...

Page 538: ...choose to work with the WEB Monitor please note the Help files referring to the WEB Monitor You can either connect the PC to the device locally using the operator interface at the front or the service in terface on the rear of the PC example Figure 3 23 Or you can log into the device using a modem via the service interface example Figure 3 24 Figure 3 23 PC interfacing directly to one device schem...

Page 539: ... Login No 3492 when relay 2 has been contacted In case of an incorrect communication link the message PI1 Data fault No 3229 or PI2 Data fault No 3231 will appear In this case recheck the fibre optical cable link Have the devices been linked correctly and no cables been mixed up Are the cables free from mechanical damage intact and the connectors locked Otherwise repeat check Continue with the mar...

Page 540: ... 1 Address 4602 CONNEC 2 OVER F optic direct if you are testing protection data interface 2 Check the Event Log or spontaneous annunciations Message 3217 PI1 Data reflec Protection interface 1 data reflection ON when you test protec tion data interface 1 Indication 3218 PI2 Data reflec Protection data interface 2 data reflection ON if you are testing protection data interface 2 When working with b...

Page 541: ...nsistent i e the prerequisites for setting the functional scope Section 2 1 1 of system data 1 2 1 2 1 system data 2 2 1 4 1 the topology and protection data in terface parameters Section 2 2 3 1 have been considered the fault message i e no 3229 PI1 Data fault or 3231 PI2 Data fault for the checked interface will disappear The communication and consistency check has now been completed If the faul...

Page 542: ... TD R are dis played corresponding to protection data interface 1 In all other cases the mean value for both directions will be indicated Indication No 7751 PI1 TD indicates the transmission time for protection data interface 1 Indication No 7752 PI2 TD indicates the transmission time for protection data interface 2 Checking further links If more than two devices are connected that is if the prote...

Page 543: ...ey An LED is used to select whether the communication topology or the protection topology is to be displayed for the participating device The display of the connections changes correspondingly To get an overview of the quality of the individual communication paths a connection status is displayed for each connection The statuses can be OK asynchronous connection and unknown status annehmen The sta...

Page 544: ...with 2 protection data interfaces The values for the runtime propagation times and the availability are displayed Both RX and TX direction of the transmission delay times are displayed symmetric conditions are assumed if there is no GPS synchronisation In this case the values displayed for the runtime propagation time are identical Figure 3 28 Example of runtime propagation times and availability ...

Page 545: ...breaker failure pro tection Although the following list does not claim to be complete it may also contain points which are to be ignored in the current application Auxiliary Contacts of the CB The circuit breaker auxiliary contact s form an essential part of the breaker failure protection system in case they have been connected to the device Make sure the correct assignment has been checked Extern...

Page 546: ...rs in case of breaker failure 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 fault is connected A general detailed test guide cannot be specified because the layo...

Page 547: ... 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 earth and the phase to phase voltages the phase differences of the voltages are also displayed so that the correct phase sequence and polarity of individu...

Page 548: ...monitoring could occur because there actually are asymmetrical condi tions in the primary system If they are part of normal operation the corresponding monitoring function is set less sensitive see Section 2 24 1 under margin heading Symmetry Monitoring The currents 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 ...

Page 549: ...re 3 30 Remote measured values in the WEB Monitor Examples of plausible measured values Polarity check If the device is connected to voltage transformers the local measured values already allow a polarity check If there are more than two ends one current path is still tested first A load current of at least 5 of the rated operational current is still required Any direction is possible but it must ...

Page 550: ...whereas the other end features an in creased negative reactive power The lower the load current for the test the higher the significance of this influence In order to get unambiguous results you should increase the load current if necessary Figure 3 31 Apparent load power The power measurement provides an initial indication as to whether the measured values of one end have the correct polarity If ...

Page 551: ...nd voltage check function which must be configured under address 135 Enabled see section 2 1 1 3 The synchronisation voltage Usy2 must be entered correctly at address 212 Usy2 connection see Section 2 1 2 1 If there is no transformer between the two measuring points address 214 ϕ Usy2 Usy1 must be set to 0 see Section 2 1 2 1 If the measurement is made across a transformer this angle setting must ...

Page 552: ...is set for synchronism check Open the VT mcb of the measuring point Usy2 No 362 FAIL U4 VT Via binary input no 2906 Sync Start AR a measuring request is entered There is no close release If there is the VT mcb for the measuring point Usy2 is not allocated Check whether this is the required state alternatively check the binary input FAIL U4 VT no 362 Reclose the VT mcb of the measuring point Usy2 O...

Page 553: ...transformer is available the corresponding phase is open circuited on the secondary side Via the current path only the current from the current transformer in the phase from which the voltage in the voltage path is missing is connected the other CTs are short circuited If the line carries resistive inductive load the protection is in principle subject to the same conditions that exist during an ea...

Page 554: ...ry load while the protected line should carry load The line remains switched on for the duration of the measurement If the polarity of the parallel line earth current measurement is correct the impedance measured in the tested loop in the example of Figure 3 34 this is L1 E should be reduced by the influence of the parallel line power flow in both lines in the same direction The impedance can be r...

Page 555: ...source Caution Feeding of zero sequence currents via a transformer without broken delta winding Inadmissible heating of the transformer is possible Zero sequence current should only be routed via a transformer if it has a delta winding therefore e g Yd Dy or Yy with a compensating winding DANGER Energized equipment of the power system Capacitive coupled voltages at disconnected equipment of the po...

Page 556: ...After switching the test source on and off again the direction indication must be checked The fault log must at least contain the messages EF Pickup and EF forward If the directional pickup is missing a connec tion error of the earth current connection I4 is present If the wrong direction is indicated the earth current con nection I4 has a swapped polarity In the latter case the connection must be...

Page 557: ...olerated Such as the locally permissible current transformer errors ac cording to address 253 E ALF ALF_N see Section 2 1 2 the permissible current transformer errors at the other ends according to the respective setting as well as the internal estimation of the system errors frequency synchronisation and delay time difference errors With the default values for I DIFF 0 3 IN and E ALF ALF_N 5 0 0 ...

Page 558: ...cuit breakers are reopened after the last test If parameters were changed for these tests they must be returned to their original state after completion of the test 3 3 10 Measuring the Operating Time of the Circuit Breaker Only for Synchronism Check If the device is equipped with the function for synchronism and voltage check and it is applied it is necessary under asynchronous system conditions ...

Page 559: ...losing time 3 3 11 Checking the Teleprotection System with Distance Protection Note If the device is intended to operate with teleprotection all devices used for the transmission of the signals must initially be commissioned according to the corresponding instructions The entire paragraph that follows is only relevant for the conventional transmission methods It is irrelevant for the use with prot...

Page 560: ...the reverse interlocking The following paragraphs describe the testing in a blocked state i e the pickup signals of the outgoing devices are connected in parallel and block the tested device of the infeed In case of release the NC contacts of the outgoing devices are connected in series the tests have to be reinterpreted respectively A fault is simulated within zone Z1 and overreaching zone Z1B As...

Page 561: ...posite to the sequence described here the operating mode of the corre sponding binary input H active L active at the opposite line end must be rectified The circuit breaker must be opened again These tests must be performed at both line ends on a three terminal line at each line end for each transmission path However please finally observe the last margin heading Important for all procedures Check...

Page 562: ...e changed for the test e g mode of the echo function or timers for unambiguous observation of sequences these must now be re set to the prescribed values 3 3 12 Testing of the Teleprotection System with Earth fault Protection This section is only relevant if the device is connected to an earthed system and earth fault protection is applied The device must therefore be provided with the earth fault...

Page 563: ... time of the device at the opposite line end 0 04 s presetting address 2502 Trip Echo DELAY If the response of the echo delay is contrary to the sequence described here the operating mode of the corre sponding binary input H active L active at the opposite line end must be rectified The circuit breaker must be opened again This test must also be carried out at both line ends in the case of three t...

Page 564: ... If the signal transmission path is the same and has already been checked as part of the previous sections it need not be checked again here Otherwise the initiating event is simulated and the response of the circuit breaker at the opposite line end is verified In the case of the distance protection the permissive underreach scheme may be used to trip the remote line end The procedure is then the ...

Page 565: ...25 1 Furthermore the ready state of the circuit breaker for the CB test must be indicated to the binary input with No 371 3 3 17 Switching Test of the Configured Operating Equipment Switching by Local Command If the configured operating devices were not switched sufficiently in the hardware test already described all configured switching devices must be switched on and off from the device via the ...

Page 566: ...ase a fault record is triggered e g via binary input when the protected object is energized Such a test fault record triggered externally i e not caused by pickup of a protection function is processed like a normal oscillographic record i e a fault log with number is generated which univocally identifies an oscillo graphic record However these recordings are not displayed in the trip log as they a...

Page 567: ...urther details on this subject are described in 1 The indication buffers are deleted under Main Menu Annunciation Set Reset so that in the future they only contain information on actual events and states The numbers in the switching statistics should be reset to the values that were existing prior to the testing The counters of the operational measured values e g operation counter if available are...

Page 568: ...Mounting and Commissioning 3 4 Final Preparation of the Device SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 568 ...

Page 569: ...ptional 596 4 8 Teleprotection for Distance Protection optional 597 4 9 Earth Fault Protection in Earthed Systems optional 598 4 10 Teleprotection for Earth Fault Protection optional 608 4 11 Weak Infeed Tripping classical optional 609 4 12 Weak Infeed Tripping French Specification optional 610 4 13 Direct Remote Trip and Transmission of Binary Information 611 4 14 Instantaneous High Current Switc...

Page 570: ...Technical Data 4 SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 570 4 26 Additional Functions 634 4 27 Dimensions 637 ...

Page 571: ...ent Overload Capability for Sensitive Earth Current Input thermal rms 300 A for 1 s 100 A for 10 s 15 A continuous dynamic pulse current 750 A half cycle 1st condition For a maximum fault current the current transformers must not be saturated under steady state conditions 2nd condition The operational accuracy limit factor n must be at least 30 or a non saturated period t AL of at least 1 4 AC cyc...

Page 572: ...oltage Power input Quiescent Approx 5 W Energized 7SD5 A E J Approx 12 W 7SD5 C G L N Q S Approx 15 W 7SD5 D H M P R T Approx 18 W Plus approx 1 5 W per interface module Bridging time for failure short circuit of the power supply IEC 60255 11 50 ms at UAux 48 V and UAux 110 V 20 ms at UAux 24 V and UAux 60 V Voltage supply via integrated converter Nominal auxiliary voltage AC UAUX AC 115 V Admissi...

Page 573: ...50 V in 3 ranges bipolar Pickup threshold Adjustable with jumpers For nominal voltages DC 24 V 48 V DC 60 V 110 V 125 V Uhigh DC 19 V Ulow DC 10 V For nominal voltages DC 110 V 125 V 220 V 250 V Uhigh DC 88 V Ulow DC 44 V For nominal voltages DC 220 V 250 V Uhigh DC 176 V Ulow DC 88 V Current consumption energized Approx 1 8 mA independent of control voltage Maximum permissible voltage DC 300 V Im...

Page 574: ... Switching voltage DC 250 V AC 250 V 200 V max Permissible current per contact continuous 5 A Permissible current per contact close and hold pulse current 30 A for 0 5 s NO contact Permissible total current on common path contacts 5 A continuous 30 A for 0 5 s Operating time approx 8 ms 5 ms 8 ms 1 ms Alarm relay 1 With 1 NC contact or 1 NO contact switchable Switching capability MAKE 1000 W VA BR...

Page 575: ...emale connector Shielded data cable Connection for panel surface mounting housing Shielded data cable Up to release BB At the two tier terminal on the case bottom Release CC and higher In the console housing on the case bottom 9 pole D subminiature female connector Test voltage 500 V 50 Hz transmission rate Min 4800 Baud max 115200 Baud Factory setting 38400 Baud RS232 Transmission distance 15 m 5...

Page 576: ...5 m RS485 Connection for panel flush mounting Housing rear panel slot B 9 pole D subminiature female connector Connection for surface mounting housing up to BB at the two tier terminal at the case bottom CC and higher in console housing at the case bottom 9 pole D subminiature female connector Test voltage 500 V 50 Hz Transmission rate min 4800 baud max 38 400 baud Factory setting 19 200 baud Tran...

Page 577: ...l optical converter Transmission rate Conversion by means of external OLM up to 1 5 MBaud 500 kBaud for normal version 57 600 Baud with detached operator panel recommended transmission rate 500 kbaud optical wavelength λ 820 nm Laser class 1 according to EN 60825 1 2 when using glass fiber 50 μm 125 µm or when using glass fibre 62 5 μm 125 µm Permissible optical signal attenuation max 8 dB with gl...

Page 578: ...SI Connection for panel flush mounting housing rear panel slot B 2 x RJ45 female connector 100BaseT acc to IEEE802 3 Connection for surface mounting housing at the bottom side of the console housing Test voltage regarding connector 500 V 50 Hz Transmission rate 100 Mbit s Transmission distance 20 m Ethernet optical EN 100 for IEC 61850 and DIGSI FO connector type ST connector transmitter receiver ...

Page 579: ... UI 8 7 V 3780 Ω at UI 17 V 640 Ω at UI 6 V 1700 Ω at UI 15 8 V 3560 Ω at UI 31 V PPS Signal for GPS ON OFF pulse duty factor 1 999 to 1 1 max rise fall time deviation of all receivers 3 μs For GPS receiver antenna and power supply unit please refer to Appendix A1 2 Accessories Standards IEC 60255 product standards IEEE Std C37 90 0 1 2 UL 508 VDE 0435 For more standards see also individual functi...

Page 580: ...35 V m 900 MHz 50 PM repetition frequency 200 Hz Fast transient disturbances Burst IEC 60255 22 4 and IEC 61000 4 4 Class IV 4 kV 5 ns 50 ns 5 kHz burst length 15 ms repetition rate 300 ms both polarities Ri 50 Ω test duration 1 min High energy surge voltages SURGE IEC 61000 4 5 installation Class 3 Auxiliary voltage Analog measuring inputs binary inputs relay outputs Impulse 1 2 µs 50 µs Common m...

Page 581: ...eration Frequency sweep 1 octave min 20 cycles in 3 orthogonal axes Shock IEC 60255 21 2 Class 1 IEC 60068 2 27 Semi sinusoidal 5 g acceleration duration 11 ms each 3 shocks in both directions of the 3 axes Seismic vibration IEC 60255 21 3 Class 1 IEC 60068 3 3 Sinusoidal 1 Hz to 8 Hz 3 5 mm amplitude horizontal axis 1 Hz to 8 Hz 1 5 mm amplitude vertical axis 8 Hz to 35 Hz 1 g acceleration horizo...

Page 582: ...ible humidity Annual average 75 relative humidity On 56 days of the year up to 93 relative humidity Condensa tion must be avoided in operation It is recommended that all devices be installed so that they are not exposed to direct sunlight nor subject to large fluctua tions in temperature that may cause condensation to occur The protection device is designed for installation in normal relay rooms a...

Page 583: ...ction 4 27 Device for maximum number of components Size Weight In flush mounting housing 1 2 6 kg 13 23 lb 1 1 10 kg 22 04 lb In panel surface mounting housing 1 2 11 kg 24 24 lb 1 1 19 kg 41 88 lb Degree of protection according to IEC 60529 For equipment in surface mounting housing IP 51 For equipment in flush mounting housing Front IP 51 Back IP 50 For human safety IP 2x with cover cap UL certif...

Page 584: ...tion optical fibre Mounting location D for one connection or D and E for two connections For flush mounting housing On the rear side For panel surface mounting housing In console housing at device bottom Connection modules for protection data interface depending on the ordering version FO5 FO30 IEEE C37 94 Distance maximum 1 5 km or 0 9 miles Connector Type ST connector Optical wavelength λ 820 nm...

Page 585: ...glass fibre 62 5 μm 125 μm and 50 μm 125 μm Reach for multimode optical fibre an optical signal attenuation of 3 dB km is used for calculating light with a wavelength of λ 820 nm Attenuators required no FO17 Distance maximum 24 km or 14 9 miles Connector Type LC duplex connector SFF IEC 61754 20 Standard Protocol full duplex Baudrate 155 MBits s Receiver interfacing AC Optical wavelength λ 1300 nm...

Page 586: ...d in Monomodefaster min 5 0 dBmavg max 0 dBmavg Receiver sensitivity min 34 0 dBmavg max 34 5 dBmavg Optical budget 29 0 dB Laser Class 1 according to EN 60825 1 2 Using glass fibre 9 µm 125 µm Reach for multimode optical fibre an optical signal attenuation of 0 3 dB km is used for calculating light with a wavelength of λ 1300 nm Attenuators required for distances of less than 25 km 15 5 miles 1 F...

Page 587: ...Connection via communication networks Communication converter see Appendix A 1 Section Accessories Supported network interfaces G703 1 with 64 kbit s G703 T1 with 1 455 Mbit s G703 E1 with 2 048 Mbit s X 21 with 64 kBit s or 128 kBit s or 512 kBit s Pilot wires with 128 kbit s Connection to the communication converter Transmission rate 64 kbit s with G703 1 1 455 Mbit s for G703 T1 2 048 Mbit s fo...

Page 588: ... A or stage inactive Tolerances For 2 or 3 ends 5 of setting value or 1 IN per end For 6 ends 10 of setting value or 1 IN per end The operating times depend on the number of ends and the communication speed The following data require a transfer rate of 512 kbit s and the output of commands via high speed output relays 7SD5 N P Q R S T Pickup trip times of the I DIFF stages at 50 or 60 Hz approx fo...

Page 589: ... to 50 0 Increments 0 1 Transformer error at n IN class 0 5 to 50 0 Increments 0 1 Further restraint quantities adaptive self restraint Frequency deviations delay time differences harmonics synchronous quality jitter Restraint ratio 2nd harmonics to the fundamental I2fN IfN 0 to 45 Increments 1 Max current for restraint IN 1 A 1 1 A to 25 0 A Increments 0 1 A IN 5 A 5 5 A to 125 0 A Crossblock Fun...

Page 590: ...2 00 A Increment 0 01 A for IN 5 A 0 25 A to 10 00 A Threshold angle ϕEDS 100 fixed Trip characteristic see Figure below Pick up tolerance for ϕ 3I0 3I0 90o and address 221 I4 Iph CT and address 4113 SLOPE 5 plus 0 01 IN Delay time TEDS 0 00 s to 60 00 s or no trip Increments 0 01 s Expiry tolerances 1 of set value or 10 ms The set times are pure delay times Pickup time at frequency 50 Hz 60 Hz at...

Page 591: ...of commands via high speed output relays 7SD5 N P Q R S T Tripping of remote ends by a command that is coupled into a binary input The tripping times depend on the number of ends and the communication speed The following data presuppose a trans mission rate of 512 kBit s and the output of commands via high speed output relays 7SD5 N P Q R S T Operating time total approx for 2 ends minimum 7 ms typ...

Page 592: ...0 01 XM XL 0 00 to 8 00 Increments 0 01 The matching factors for the mutual impedance ratio are valid also for fault locating For double earth fault in earthed net Block leading phase earth Block lagging phase earth Release all associated loops Release only phase to earth loops Release of phase to phase loops For double earth fault in isolated or resonant earthed systems L3 L1 acyclic L1 L3 acycli...

Page 593: ...for IN 1 A 0 10 A to 8 00 A Increments 0 01 A for IN 5 A 0 50 A to 40 00 A Undervoltage phase earth Uphe segregated for Iph Iϕ and Iph 20 V to 70 V Increments 1 V Undervoltage phase phase Uphph segregated for Iph Iϕ and Iph 40 V to 130 V Increments 1 V Lower threshold angle ϕ 30 to 60 In increments of 1 Upper threshold angle ϕ 90 to 120 In increments of 1 Dropout to pickup ratio Iph If Approx 0 95...

Page 594: ...nal characteristic For all types of faults With phase true memorized or cross polarized voltages Directional sensitivity Dynamically unlimited Stationary approx 1V Each zone can be set to operate in forward or reverse direction non directional or ineffective Setting ranges of the MHO characteristic IPH min current phases for IN 1 A 0 05 A to 4 00 A Increments 0 01 A for IN 5 A 0 25 A to 20 00 A Zr...

Page 595: ...time setting pos sibilities for single phase and multi phase faults for the zones Z1 Z2 and Z1B Increments 0 01 s Time expiry tolerances 1 of setting value or 10 ms The set times are pure delay times with definite time protection If the differential protection and the distance protection operate in parallel in the protective relay emergency operation will not be activated unless both protection fu...

Page 596: ...ith impedance pickup optional Power swing detection Rate of change of the impedance phasor and observation of the impedance trajectory Maximum power swing frequency Approx 10 Hz Power swing blocking programs Blocking of Z1 and Z1B Blocking of Z2 and higher zones Blocking of Z1 and Z2 Block all zones Power swing trip Trip following instable power swings out of step ...

Page 597: ...verreaching zone Z1B PUTT Pickup Direct transfer trip Send signal prolongation 0 00 s to 30 00 s Increments 0 01 s Method Permissive Overreach Transfer Trip POTT with overreaching zone Z1B Directional comparison Unblocking with overreaching zone Z1B Blocking with overreaching zone Z1B Pilot wire comparison Reverse interlock with pilot wires Send signal prolongation 0 00 s to 30 00 s Increments 0 0...

Page 598: ... for IN 5 A 0 25 A to 125 00 A Delay T3I0 0 00 s to 30 00 s or ineffective Increments 0 01 s Dropout ratio Approx 0 95 for I IN 0 5 Pickup time fast relays high speed relays Approx 30 ms 25 ms Dropout time Approx 30 ms Tolerances Current 3 of setting value or 1 nominal current Time 1 of setting value or 10 ms The set times are pure delay times with definite time protection Pickup value 3I0 for IN ...

Page 599: ... Approx 30ms 25 ms Dropout time Approx 30 ms Tolerances Current 3 of setting value or 1 nominal current Time 1 of setting value or 10 ms The set times are pure delay times with definite time protection Pickup value 3I0P for IN 1 A 0 05 A to 25 00 A or 0 003 A to 25 000 A Increments 0 01 A Increments 0 001 A for IN 5 A 0 25 A to 125 00 A or 0 015 A to 125 000 A Increments 0 01 A Increments 0 001 A ...

Page 600: ...ue or 1 nominal current Pickup time for 2 I 3I0P 20 and D3I0P 1 s 5 of set value 15 ms Defined times 1 of set value or 10 ms Pickup value 3I0P for IN 1 A 0 05 A to 25 00 A or 0 003 A to 25 000 A Increments 0 01 A Increments 0 001 A for IN 5 A 0 25 A to 125 00 A or 0 015 A to 125 000 A Increments 0 01 A Increments 0 001 A Start current factor 3I0P FACTOR 1 0 to 4 0 Increments 0 1 Time factor T3I0P ...

Page 601: ...95 for I IN 0 5 Voltage Approx 0 95 for 3U0 1 V Pickup value 3I0P for IN 1 A 0 05 A to 25 00 A or 0 003 A to 25 000 A Increments 0 01 A Increments 0 001 A for IN 5 A 0 25 A to 125 00 A or 0 015 A to 125 000 A Increments 0 01 A Increments 0 001 A Pickup value S FORWARD for IN 1 A 0 1 VA to 10 0 VA Increments 0 1 VA for IN 5 A 0 5 VA to 50 0 VA Additional time delay T3I0P add 0 00 s to 30 00 s Steps...

Page 602: ...ence quantities With zero sequence power Limit values Displacement voltage 3U0 0 5 V to 10 0 V Increments 0 1 V Starpoint current of a power transformer IY for IN 1 A 0 05 A to 1 00 A Increments 0 01 A for IN 5 A 0 25 A to 5 00 A Negative sequence current 3I2 for IN 1 A 0 05 A to 1 00 A Increments 0 01 A for IN 5 A 0 25 A to 5 00 A Negative sequence voltage 3U2 0 5 V to 10 0 V Increments 0 1 V For...

Page 603: ...4 9 Earth Fault Protection in Earthed Systems optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 603 Figure 4 2 Trip time characteristics of inverse time overcurrent stage acc IEC phases and earth ...

Page 604: ... Earth Fault Protection in Earthed Systems optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 604 Figure 4 3 Trip time characteristics of inverse time overcurrent stage acc ANSI IEEE phases and earth ...

Page 605: ... Earth Fault Protection in Earthed Systems optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 605 Figure 4 4 Trip time characteristics of inverse time overcurrent stage acc ANSI IEEE phases and earth ...

Page 606: ...e date 02 2011 606 Figure 4 5 Trip time characteristic of the inverse time overcurrent stage with logarithmic inverse charac teristic Logarithmic inverse t T3I0Pmax T3I0P ln I 3I0P Note For I 3I0P 35 the time for I 3I0P 35 applies Figure 4 6 Trip time characteristics of the zero sequence voltage protection U0 inverse ...

Page 607: ...ion in Earthed Systems optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 607 Figure 4 7 Tripping characteristics of the zero sequence power protection This characteristic applies for Sref 10 VA and T3IOPAdd T_DELAY 0 s ...

Page 608: ...or phase segregated transmission For three line ends With one channel for each direction or connection Method Dir comp pickup Directional unblocking scheme Directional blocking scheme Send signal prolongation 0 00 s to 30 00 s Increments 0 01 s Enable delay 0 000 s to 30 000 s Increments 0 001 s Transient blocking time 0 00 s to 30 00 s Increments 0 01 s Wait time for transient blocking 0 00 s to ...

Page 609: ...tion after reception of a carrier signal from the remote end Setting value UPhE 2 V to 70 V Increments 1 V Dropout to pickup ratio Approx 1 1 Pickup tolerance 5 of setting value or 0 5 V Echo delay release delay 0 00 s to 30 00 s Increments 0 01 s Echo impulse duration release prolongation 0 00 s to 30 00 s Increments 0 01 s Echo blocking duration after echo 0 00 s to 30 00 s Increments 0 01 s Pic...

Page 610: ...arrier signal from the remote end Setting value UPhE 0 10 to 1 00 Increments 0 01 Dropout pickup ratio Approx 1 1 Pickup tolerance 5 Receive prolongation 0 00 s to 30 00 s Increments 0 01 s Extension time 3I0 0 00 s to 30 00 s Increments 0 01 s Alarm time 3I0 0 00 s to 30 00 s Increments 0 01 s Delay single pole 0 00 s to 30 00 s Increments 0 01 s Delay multi pole 0 00 s to 30 00 s Increments 0 01...

Page 611: ...ox for 2 ends minimum 8 ms typical 12 ms for 3 ends minimum 10 ms typical 14 ms for 6 ends minimum 15 ms typical 18 ms Dropout times total approx for 2 ends typical 19 ms for 3 ends typical 20 ms for 6 ends typical 26 ms Number of possible remote signals 24 The operating times depend on the number of ends and the communication speed The following data require a transfer rate of 512 kbit s and the ...

Page 612: ...SOTF Pickup Times High current pickup I for IN 1 A 0 10 A to 15 00 A or disabled Increments 0 01 A for IN 5 A 0 50 A to 75 00 A or disabled High current pickup I for IN 1 A 1 00 A to 25 00 A or disabled Increments 0 01 A for IN 5 A 5 00 A to 125 00 A or disabled Dropout to pickup ratio Approx 90 Pickup tolerance 3 of setting value or 1 of IN Shortest trip time fast relays high speed relays Approx ...

Page 613: ...delay time TSens E F TRIP 0 00 s to 320 00 s Increments 0 01 s Measuring tolerance 5 of set value Time tolerance 1 of setting value or 10 ms The set times are pure delay times Measuring principle Voltage measurement phase earth Earth fault phase Uph min 10 V to 100 V Increments 1 V Healthy phases Uph max 10 V to 100 V Increments 1 V Measuring tolerance 5 of set value Measuring principle Real react...

Page 614: ...ntial protection not config ured Effective when the distance protection system is blocked e g because of a trip of the voltage transformer mcb via binary input a measuring voltage failure or a pickup of the fuse failure monitor Back up overcurrent protection operates independent of any events Definite dime stages definite IPh 3I0 IPh 3I0 IPh 3I0 Inverse time stages IDMT IP 3I0P one of the characte...

Page 615: ...f setting value or 1 nominal current Times 1 of setting value or 10 ms The set times are pure delay times Pickup value IP phases for IN 1 A 0 10 A to 4 00 A or ineffective Increments 0 01 A for IN 5 A 0 50 A to 20 00 A or ineffective Pickup value 3I0P earth for IN 1 A 0 05 A to 4 00 A or ineffective Increments 0 01 A for IN 5 A 0 25 A to 20 00 A or ineffective Time multipliers TIP phases 0 05 s to...

Page 616: ...ee Figure 4 3 and 4 4 Tolerances Pickup dropout thresholds Ip 3I0p 3 of set value or 1 nominal current Pickup time for 2 I IP 20 and DIP 1 s Pickup time for 2 I 3I0P 20 and D3I0P 1 s 5 of set value 15 ms 5 of set value 15 ms Defined times 1 of setting value or 10 ms Pickup value IPh phases for IN 1 A 0 10 A to 25 00 A or ineffective Increments 0 01 A for IN 5 A 0 50 A to 125 00 A or ineffective Pi...

Page 617: ...o 1800 00 s Increments 0 01 s Reclaim time after reclosure 0 50 s to 300 00 s Increments 0 01 s Blocking time after dynamic blocking 0 5 s Blocking time after manual closing 0 50 s to 300 00 s 0 Increments 0 01 s Start signal monitoring time 0 01 s to 300 00 s Increments 0 01 s Circuit breaker monitoring time 0 01 s to 300 00 s Increments 0 01 s Adaptive dead time With voltage measurement or with ...

Page 618: ...re independently selectable Maximum operating voltage 20 V to 140 V phase to phase Increments 1 V U for dead status 1 V to 60 V phase to phase Increments 1 V U for live status 20 V to 125 V phase to phase Increments 1 V Tolerances 2 of pickup value or 1 V Dropout to pickup ratio Approx 0 9 U or 1 1 U Voltage difference 1 0 V to 60 0 V phase to phase Increments 0 1V Tolerance 1 V Dropout to pickup ...

Page 619: ...optional SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 619 Times Minimum time for filtering the measured values Approx 80 ms Maximum measuring time 0 01 s to 600 00 s Increments 0 01 s Tolerance of all timers 1 of setting value or 10 ms ...

Page 620: ... Times 1 of setting value or 10 ms Overvoltage UPhPh 2 0 V to 220 0 V Increments 0 1 V Delay TUPhPh 0 00 s to 100 00 s Increments 0 01 s Overvoltage UPhPh 2 0 V to 220 0 V Increments 0 1 V Delay TUPhPh 0 00 s to 100 00 s Increments 0 01 s Dropout ratio 0 30 to 0 99 Increments 0 01 Pick up times Approx 35 ms Dropout time Approx 30 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of setting ...

Page 621: ...ncrements 0 1 V Delay T3U0 0 00 s to 100 00 s Increments 0 01 s Overvoltage 3U0 1 0 V to 220 0 V Increments 0 1 V Delay T3U0 0 00 s to 100 00 s Increments 0 01 s Dropout ratio 0 30 to 0 99 Increments 0 01 Pick up times With repeated measurement Approx 75 ms Without repeated measurement Approx 35 ms Dropout time With repeated measurement Approx 75 ms Without repeated measurement Approx 30 ms Tolera...

Page 622: ...0 01 s Dropout ratio 1 01 to 1 20 Current criterion Can be switched on off Pick up times Approx 35 ms Dropout time Approx 30 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of setting value or 10 ms Undervoltage U1 1 0 V to 100 0 V Increments 0 1 V Delay TU1 0 00 s to 100 00 s Increments 0 01 s Undervoltage U1 1 0 V to 100 0 V Increments 0 1 V Delay TU1 0 00 s to 100 00 s Increments 0 01 ...

Page 623: ...50 Hz Increments 0 01 Hz Pickup times f f Approx 85 ms Dropout times f f Approx 30 ms Delay times T 0 00 s to 600 00 s Increments 0 01 s The set times are pure delay times Note on dropout times Dropout was enforced by current 0 A and voltage 0 V Enforcing the dropout by means of a frequency change below the dropout threshold extends the dropout times Δf pickup value dropout value Approx 20 mHz In ...

Page 624: ...ngth must be set for each line section A1 to A3 Parallel line compensation optional Can be switched on off The setting values are the same as for distance protection see Section 4 6 Taking into consideration the load current in case of single phase earth faults Correction of the X value can be enabled and disabled Output of the fault distance In Ω primary and Ω secondary in km or miles line length...

Page 625: ... also operate without the indicated circuit breaker auxiliary contacts but the func tion range is then reduced Auxiliary contacts are necessary for the circuit breaker failure protection for tripping without or with a very low current flow e g Buchholz protection and for stub fault protection and circuit breaker pole discrepancy supervision For circuit breaker failure protection Internal or extern...

Page 626: ...min Thermal Alarm ΘAlarm ΘTrip 50 to 100 of the trip overtemperature Increments 1 Current Overload IAlarm for IN 1 A 0 10 A to 4 00 A Increments 0 01 A for IN 5 A 0 50 A to 20 00 A Calculation method temperature rise Maximum temperature rise of 3 phases Average of temperature rise of 3 phases Temperature rise from maximum current Θ ΘTrip Θ ΘAlarm I IAlarm Drops out with ΘAlarm Approx 0 99 Approx 0...

Page 627: ...Technical Data 4 23 Thermal Overload Protection SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 627 Figure 4 8 Trip time characteristics of the overload protection ...

Page 628: ...o 100 V Increments 1 V T BAL ULIMIT 5 s to 100 s Increments 1 s Voltage phase sequence UL1 before UL2 before UL3 while UL1 UL2 UL3 40 V 3 Asymmetrical measuring voltage failure Fuse Failure Monitor 3 U0 FFM U OR 3 U2 FFM U AND simultaneously 3 I0 FFM I AND 3 I2 FFM I FFM U 10 V to 100 V Increments 1 V FFM I for IN 1 A 0 10 A to 1 00 A Increments 0 01 A for IN 5 A 0 50 A to 5 00 A Increments 0 01 A...

Page 629: ...000 G1176 C169 5 Release date 02 2011 629 Number of monitored circuits 1 to 3 Operation per circuit With 1 binary input or with 2 binary inputs Pickup and dropout time Approx 1 s to 2 s Settable delay time for operation with 1 binary input 1 s to 30 s Increments 1 s ...

Page 630: ...ured value comparison X X X X CONNECT Connection X X X COUNTER Counter X X X X CV_GET_STATUS Information status of the metered value decoder X X X X D_FF D Flipflop X X X D_FF_MEMO Status Memory for Restart X X X X DI_GET_STATUS Information status double point indication decoder X X X X DI_SET_STATUS Double point indication with status encoder X X X X DI_TO_BOOL Double Point to Boolean conversion ...

Page 631: ...on X Description Limit Comments Maximum number of all CFC charts considering all task levels 32 When the limit is exceeded an error message is output by the device Conse quently the device is put into monitoring mode The red ERROR LED lights up Maximum number of all CFC charts considering one task level 16 Only error message evolving error in processing procedure Maximum number of all CFC inputs c...

Page 632: ...vice i e 5 ms otherwise the blocks will not start with the starting impulse issued Maximum Number of TICKS in the Task Levels 1 When the sum of TICKS of all blocks exceeds the limits before mentioned an error message is output by CFC Description Limit Comments Maximum number of concurrent changes to planned inputs per task level Chart inputs per task level 50 When the limit is exceeded an error me...

Page 633: ...ion to an input signal 6 Connection to an output signal 7 Additional for each chart 1 Operating sequence module CMD_CHAIN 34 Flipflop D_FF_MEMO 6 Loop module LOOP 8 Decoder DM_DECODE 8 Dynamic OR DYN_OR 6 Addition ADD 26 Subtraction SUB 26 Multiplication MUL 26 Division DIV 54 Square root SQUARE_ROOT 83 Timer TIMER_SHORT 8 Timer LONG_TIMER 11 Blinker lamp BLINK 11 Counter COUNTER 6 Adaptor REAL_TO...

Page 634: ...l current Operational measured values for impedances RL1 L2 RL2 L3 RL3 L1 RL1 E RL2 E RL3 E XL1 L2 XL2 L3 XL3 L1 XL1 E XL2 E XL3 E in Ω primary and secondary Operational measured values for power S P Q apparent active and reactive power in MVA MW Mvar primary and SN operational nominal power 3 UN IN Tolerance for S 1 of SN at I IN and U UN in range 50 to 120 Tolerance for P 1 of PN at I IN and U U...

Page 635: ...alues for voltages UL1 UL2 UL3 of remote end in of UNOperation 3 ϕ UL1 ϕ UL2 ϕ UL3 remote versus local in Capacity 200 records Capacity 8 faults with a total of max 600 messages and up to 100 binary signal traces marks Number of stored fault records Max 8 Storage time Max 5 s for each fault Approx 15 s in total Sampling rate at fN 50 Hz 1 ms Sampling rate at fN 60 Hz 0 83 ms Availability of transm...

Page 636: ...ion Operating modes of the clock management No Operating mode Explanations 1 Internal Internal synchronisation via RTC or Timing Master 2 IEC 60870 5 103 External synchronisation via system interface IEC 60870 5 103 or Timing Master 3 Time signal IRIG B External synchronisation via IRIG B telegram format IRIG B000 or Timing Master 4 Time signal DCF 77 External synchronization via DCF 77 or Timing ...

Page 637: ... SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 637 4 27 Dimensions 4 27 1 Panel Flush Mounting and Cubicle Mounting Size 1 2 Figure 4 9 Dimensions of a device for panel flush mounting or cubicle installation size 1 2 ...

Page 638: ...ensions SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 638 4 27 2 Panel Flush Mounting and Cubicle Mounting Size 1 1 Figure 4 10 Dimensions of a device for panel flush mounting or cubicle installation size 1 1 ...

Page 639: ...C169 5 Release date 02 2011 639 4 27 3 Panel Surface Mounting Housing Size 1 2 Figure 4 11 Dimensions of a device for panel surface mounting size 1 2 4 27 4 Panel Surface Mounting Housing Size 1 1 Figure 4 12 Dimensions of a device for panel surface mounting size 1 1 ...

Page 640: ...Technical Data 4 27 Dimensions SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 640 ...

Page 641: ... diagrams default settings as well as tables with all parameters and information for the device with its maximum extent A 1 Ordering Information and Accessories 642 A 2 Terminal Assignments 652 A 3 Connection Examples 666 A 4 Default Settings 674 A 5 Protocol dependent Functions 681 A 6 Functional Scope 682 A 7 Settings 685 A 8 Information List 706 A 9 Group Alarms 746 A 10 Measured Values 747 ...

Page 642: ...shold ranges can be selected with plug in jumper Line Differential Protection 5 6 7 8 9 10 11 12 13 14 15 16 With Distance Protection 7 S D 5 L M N Function Package Version Pos 5 Line differential protection with 4 line display 2 Line differential protection with graphical display 3 Device Type Pos 6 Line differential protection for two end operation1 2 Line differential protection for multi end o...

Page 643: ... by 5 ms N Flush mounting housing with screwed terminals 1 1 x 19 24 BI 31 BO 1 life contact With 5 high speed relays trip command accelerated by 5 ms P Surface mounting housing with two tier terminals 1 1 x 19 16 BI 23 BO 1 life contact With 5 high speed relays trip command accelerated by 5 ms Q Surface mounting housing with two tier terminals 1 1 x 19 24 BI 31 BO 1 life contact With 5 high speed...

Page 644: ...tection 7 S D 5 L System Interfaces Port B Pos 11 No system interface 0 IEC 60870 5 103 protocol electrical RS232 1 IEC 60870 5 103 protocol electrical RS485 2 IEC 60870 5 103 protocol optical 820 nm ST connector 3 Profibus FMS Slave electrical RS485 4 Profibus FMS Slave optical 820 nm double ring ST connector 1 6 For more interface options see Additional Specification L 9 Additional Specification...

Page 645: ...IGSI Modem Browser optical 820 nm ST connector 3 Port D FO5 optical 820 nm 2 ST connectors length of optical fibre up to 1 5 km for FO direct connection or communication networks using multimode fibre A Port D FO6 optical 820 nm 2 ST connectors length of optical fibre up to 3 5 km for FO direct connection using multimode fibre B Port D FO17 optical 1300 nm LC duplex connector length of optical fib...

Page 646: ... check 0 Three pole tripping with automatic reclosure without synchronism check 1 Single three pole tripping without automatic reclosure without synchronism check 2 Single three pole tripping with automatic reclosure without synchronism check 3 Three pole tripping without automatic reclosure with synchronism check 4 Three pole tripping with automatic reclosure with synchronism check 5 Single three...

Page 647: ...vercurrent Pro tection Circuit Breaker Failure Protection Earth fault Protec tion Distance Protection pickup Z polygon parallel line compensa tion 1 Power Swing Option with Erdschlusserfassung für gel iso Netze2 MHO3 I U I ϕ pickup4 with without without without without C with without without with without D with without with without without E with with without without without F with with without wi...

Page 648: ...km 37 5 miles 1 7XV5461 0BH00 Wide area fibre optical repeater 100 km 62 miles 1 7XV5461 0BJ00 Wide area fibre optical repeater 170 km 105 5 miles 1 7XV5461 0BM00 Bidirectional fibre optical repeater 40 km 25 miles The communication is performed via fibre optic cables 2 7XV5461 0BK00 Bidirectional fibre optical repeater 40 km 25 miles The communication is performed via fibre optic cables 2 7XV5461...

Page 649: ... Number Isolation transformer test voltage 20 kV 7XR9516 GPS Name Order No GPS receiver with antenna and cable 7XV5664 0AA00 Power supply 7XV5810 0BA00 Time synchronization converter 7XV5656 0BA00 Bus cable for 7SD52 for GPS sync 7XV5105 0AA00 Voltage Transformer Miniature Circuit Breaker Nominal Values Order No Thermal 1 6 A magnetic 6 A 3RV1611 1AG14 External Converters Optical interfaces for Pr...

Page 650: ... 1 FO6 with ST connector 820 nm multimode optical fibre maximum length 3 5 km for surface mounting housing C53207 A406 D50 1 FO17 with LC duplex connector 1300 nm monomode optical fibre maximum length 24 km 15 miles C53207 A351 D655 1 FO18 with LC duplex connector 1300 nm monomode optical fibre maximum length 60 km 37 5 miles C53207 A351 D656 1 FO19 with LC duplex connector 1550 nm monomode optica...

Page 651: ...19 Racks Name Order No a pair of mounting rails one for top one for bottom C73165 A63 D200 1 Battery Lithium battery 3 V 1 Ah type CR 1 2 AA Order No VARTA 6127 101 501 Interface Cable An interface cable and the DIGSI operating software are required for the communication between the SIPRO TEC 4 device and a PC or laptop The PC or laptop must run MS WINDOWS 95 MS WINDOWS 98 MS WINDOWS NT 4 MS WINDO...

Page 652: ...s SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 652 A 2 Terminal Assignments A 2 1 Panel Flush Mounting or Cubicle Mounting 7SD5 A J Figure A 1 General diagram 7SD5 A J panel flush mounting or cubicle mounting size1 2 ...

Page 653: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 653 7SD5 C L Figure A 2 General diagram 7SD5 C L panel flush mounting or cubicle mounting size1 1 ...

Page 654: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 654 7SD5 N S Figure A 3 General diagram 7SD5 N S panel flush mounting or cubicle mounting size1 1 ...

Page 655: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 655 7SD5 D M Figure A 4 General diagram 7SD5 D M panel flush mounting or cubicle mounting size1 1 ...

Page 656: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 656 7SD5 P T Figure A 5 General diagram 7SD5 P T panel flush mounting or cubicle mounting size1 1 ...

Page 657: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 657 7SD5 W ...

Page 658: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 658 Figure A 6 General diagram 7SD5 W panel flush mounting and cubicle mounting size 1 1 ...

Page 659: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 659 A 2 2 Panel Surface Mounting 7SD5 E Figure A 7 General diagram 7SD5 E panel surface mounting size1 2 ...

Page 660: ...x A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 660 7SD5 E release CC and higher Figure A 8 General diagram 7SD5 E release CC and higher panel surface mounting size1 2 ...

Page 661: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 661 7SD5 G Figure A 9 General diagram 7SD5 G panel surface mounting size1 1 ...

Page 662: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 662 7SD5 Q Figure A 10 General diagram 7SD5 Q panel surface mounting size1 1 ...

Page 663: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 663 7SD5 H Figure A 11 General diagram 7SD5 H panel surface mounting size1 1 ...

Page 664: ...Appendix A 2 Terminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 664 7SD5 R Figure A 12 General diagram 7SD5 R panel surface mounting size1 1 ...

Page 665: ...erminal Assignments SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 665 7SD5 G H Q R release CC and higher Figure A 13 General diagram 7SD5 G H Q R release CC and higher panel surface mounting size 1 1 ...

Page 666: ...ROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 666 A 3 Connection Examples A 3 1 Current Transformer Connection Examples Figure A 14 Current connections to three current transformers and starpoint current normal circuit layout ...

Page 667: ...prefered for solidly or low resistive earthed systems Important The cable shield must be grounded on the cable side In case of an earthing of the current transformers on the busbar side the current polarity of the device is changed via the address 0201 This also reverses the polarity of the current input IE or IEE Therefore the con nections of S1 and S2 must be exchanged at Q8 and Q7 when using a ...

Page 668: ...les SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 668 Figure A 16 Current connections to three current transformers and earth current from the star point connection of a parallel line for parallel line compensation ...

Page 669: ...TEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 669 Figure A 17 Current connections to three current transformers and earth current from the star point current of an earthed power transformer for directional earth fault protection ...

Page 670: ...C 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 670 Figure A 18 Restricted earth fault protection on an earthed transformer winding Figure A 19 Restricted earth fault protection on a non earthed transformer winding with neutral reactor ...

Page 671: ...ion Examples SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 671 A 3 2 Voltage Transformer Connection Examples Figure A 20 Voltage connections to three wye connected voltage transformers normal circuit layout ...

Page 672: ... 3 Connection Examples SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 672 Figure A 21 Voltage connections to three wye connected voltage transformers with additional open delta windings e n winding ...

Page 673: ...les SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 673 Figure A 22 Voltage connections to three wye connected voltage transformers and additionally to a busbar voltage for overvoltage protection or synchronism check ...

Page 674: ...ers DT unequal 3234 Device tables are unequal Par different 3235 Differences between common parameters Equal IDs 3487 Equal IDs in constellation LED6 Relay TRIP 511 Relay GENERAL TRIP command1 Relay TRIP 3ph 515 Relay TRIP command Phases L1232 LED7 no presetting 1 Relay TRIP 1pL1 512 Relay TRIP command Only Phase L12 Relay TRIP 1pL2 513 Relay TRIP command Only Phase L22 Relay TRIP 1pL3 514 Relay T...

Page 675: ...l close signal BI3 no presetting BI4 BLOCK O C I 7104 BLOCK Backup OverCurrent I BLOCK O C I 7105 BLOCK Backup OverCurrent I BLOCK O C Ip 7106 BLOCK Backup OverCurrent Ip BLOCK O C Ie 7107 BLOCK Backup OverCurrent Ie BLOCK O C Ie 7108 BLOCK Backup OverCurrent Ie BLOCK O C Iep 7109 BLOCK Backup OverCurrent Iep BLOCK I STUB 7130 BLOCK I STUB BLOCK O CIe 7132 BLOCK Backup OverCurrent Ie BI5 no preset...

Page 676: ...ase L23 Relay TRIP 3ph 515 Relay TRIP command Phases L1233 BO6 no presetting 2 Relay TRIP 1pL3 514 Relay TRIP command Only Phase L33 Relay TRIP 3ph 515 Relay TRIP command Phases L1233 BO7 AR CLOSE Cmd 2851 AR Close command4 BO8 Diff block 3148 Diff Differential protection is blocked BO9 AR not ready 2784 AR Auto reclose is not ready4 BO10 Test Diff 3190 Diff Set Teststate of Diff protection TestDi...

Page 677: ...tings SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 677 A 4 5 Default Display 4 line Display Table A 5 This selection is available as start page which may be configured Page 1 Page 2 Page 3 Page 4 Page 5 Page 6 ...

Page 678: ...sed time from pick up until the first trip command of a protection function Fault locator Fault distance d in km or miles Spontaneous Fault Annunciations of the Graphic Display All devices featuring a graphic display allow you to select whether or not to view automatically the most impor tant fault data on the display after a general interrogation The information is shown in the display in the fol...

Page 679: ...dix A 4 Default Settings SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 679 Default Display in the Graphic Editor Figure A 23 Standard default display after starting the Display Editor example ...

Page 680: ... 5 Release date 02 2011 680 A 4 6 Pre defined CFC Charts Device and System Logic A negator block of the slow logic PLC1 BEARB is created from the binary input DataStop into the internal single point indication UnblockDT Figure A 24 Logical Link between Input and Output ...

Page 681: ...za tion Via protocol DCF77 IRIG B GPS Interface Protection Data In terface Binary input Via protocol NPT DCF77 IRIG B Interface Protection Data In terface Binary input Via protocol DCF77 IRIG B GPS Interface Protection Data Interface Binary Input Via DCF77 IRIG B GPS Interface Protection Data Interface Binary Input Via protocol DCF77 IRIG B GPS Interface Protection Data Inter face Binary Input Mes...

Page 682: ...up program 119 Iph Z1 Disabled Enabled Disabled Additional Threshold Iph Z1 120 Power Swing Disabled Enabled Disabled Power Swing detection 121 Teleprot Dist PUTT Z1B PUTT Pickup POTT Dir Comp Pickup UNBLOCKING BLOCKING Rev Interlock Pilot wire comp Disabled Disabled Teleprotection for Distance prot 122 DTT Direct Trip Disabled Enabled Disabled DTT Direct Transfer Trip 124 HS SOTF O C Disabled Ena...

Page 683: ...r Overvoltage Protection 138 Fault Locator Disabled Enabled with BCD output Disabled Fault Locator 139 BREAKER FAILURE Disabled Enabled enabled w 3I0 Disabled Breaker Failure Protection 140 Trip Cir Sup Disabled 1 trip circuit 2 trip circuits 3 trip circuits Disabled Trip Circuit Supervision 141 REF PROT Disabled Enabled Disabled Restricted earth fault protection 142 Therm Overload Disabled Enable...

Page 684: ...2011 684 148 GPS SYNC Enabled Disabled Disabled GPS synchronization 149 charge I comp Enabled Disabled Disabled charging current compensation 160 L sections FL 1 Section 2 Sections 3 Sections 1 Section Line sections for fault locator Addr Parameter Setting Options Default Setting Comments ...

Page 685: ...2 E L3 E L1 L2 L2 L3 L3 L1 L1 E VT connection for Usy2 214A ϕ Usy2 Usy1 P System Data 1 0 360 0 Angle adjustment Usy2 Usy1 215 Usy1 Usy2 ratio P System Data 1 0 50 2 00 1 00 Matching ratio Usy1 Usy2 220 I4 transformer P System Data 1 Not connected In prot line In paral line IY starpoint In prot line I4 current transformer is 221 I4 Iph CT P System Data 1 0 010 5 000 1 000 Matching ratio I4 Iph for...

Page 686: ...00 0 MVA 692 8 MVA Operational power of protection zone 1107 P Q sign P System Data 2 not reversed reversed not reversed P Q operational measured values sign 1111 x P System Data 2 1A 0 0050 9 5000 Ω km 0 1500 Ω km x Line Reactance per length unit 5A 0 0010 1 9000 Ω km 0 0300 Ω km 1111 x P System Data 2 1A 0 0050 15 0000 Ω mi 0 2420 Ω mi x Line Reactance per length unit 5A 0 0010 3 0000 Ω mi 0 048...

Page 687: ...hold 5A 1 0 250 0 A 100 0 A 1150A SI Time Man Cl P System Data 2 0 01 30 00 sec 0 30 sec Seal in Time after MANUAL clo sures 1151 SYN MAN CL P System Data 2 with Sync check w o Sync check NO NO Manual CLOSE COMMAND generation 1152 Man Clos Imp P System Data 2 Setting options depend on configuration None MANUAL Closure Impulse after CONTROL 1155 3pole coupling P System Data 2 with PICKUP with TRIP ...

Page 688: ... 1507A 3I0 Iphmax Dis General 0 05 0 30 0 10 3I0 pickup stabilisation 3I0 Iphmax 1508 SER COMP Dis General NO YES NO Series compensated line 1509A E F recognition Dis General 3I0 OR 3U0 3I0 AND 3U0 3I0 OR 3U0 criterion of earth fault recognition 1510 Start Timers Dis General on Dis Pickup on Zone Pickup on Dis Pickup Condition for zone timer start 1511 Distance Angle P System Data 2 Dis General 30...

Page 689: ...100 00 A 1 00 A 1611 Op mode Z2 Dis Quadril Forward Reverse Non Directional Inactive Forward Operating mode Z2 1612 R Z2 Ø Ø Dis Quadril 1A 0 050 600 000 Ω 2 500 Ω R Z2 Resistance for ph ph faults 5A 0 010 120 000 Ω 0 500 Ω 1613 X Z2 Dis Quadril 1A 0 050 600 000 Ω 5 000 Ω X Z2 Reactance 5A 0 010 120 000 Ω 1 000 Ω 1614 RE Z2 Ø E Dis Quadril 1A 0 050 600 000 Ω 5 000 Ω RE Z2 Resistance for ph e fault...

Page 690: ...ch zone 1652 R Z1B Ø Ø Dis Quadril 1A 0 050 600 000 Ω 1 500 Ω R Z1B Resistance for ph ph faults 5A 0 010 120 000 Ω 0 300 Ω 1653 X Z1B Dis Quadril 1A 0 050 600 000 Ω 3 000 Ω X Z1B Reactance 5A 0 010 120 000 Ω 0 600 Ω 1654 RE Z1B Ø E Dis Quadril 1A 0 050 600 000 Ω 3 000 Ω RE Z1B Resistance for ph e faults 5A 0 010 120 000 Ω 0 600 Ω 1655 T1B 1phase Dis General Dis Quadril Dis MHO 0 00 30 00 sec 0 00 ...

Page 691: ... 0 100 0 15 0 Voltage Memory polarization phase e 1772A CrossPolarizPhE Dis MHO 0 0 100 0 15 0 Cross polarization phase e 1773A Mem Polariz P P Dis MHO 0 0 100 0 15 0 Voltage Memory polarization ph ph 1774A CrossPolarizP P Dis MHO 0 0 100 0 15 0 Cross polarization phase phase 1901 PROGAM U I Dis General LE Uphe LL Uphp LE Uphp LL Uphp LE Uphe LL Uphe LE Uphe LL I LE Uphe LL Uphp Pickup program U I...

Page 692: ... 0 00 30 00 sec 0 01 sec Trip Time Delay 2301 INRUSH REST Diff Prot OFF ON OFF Inrush Restraint 2302 2nd HARMONIC Diff Prot 10 45 15 2nd harmonic in of fundamen tal 2303 CROSS BLOCK Diff Prot NO YES NO Cross Block 2305 MAX INRUSH PEAK Diff Prot 1A 1 1 25 0 A 15 0 A Maximum inrush peak value 5A 5 5 125 0 A 75 0 A 2310 CROSSB 2HM Diff Prot 0 00 60 00 sec 0 00 sec Time for Crossblock with 2nd harmoni...

Page 693: ...taneous trip after Switch OnToFault 2620 Iph Back Up O C 1A 0 05 50 00 A 1 50 A Iph Pickup 5A 0 25 250 00 A 7 50 A 2621 T Iph Back Up O C 0 00 30 00 sec 0 50 sec T Iph Time delay 2622 3I0 Back Up O C 1A 0 05 25 00 A 0 20 A 3I0 Pickup 5A 0 25 125 00 A 1 00 A 2623 T 3I0 Back Up O C 0 00 30 00 sec 2 00 sec T 3I0 Time delay 2624 I Telep BI Back Up O C NO YES NO Instantaneous trip via Tele prot BI 2625...

Page 694: ...r Balance Monitoring 2903A BAL FACTOR U Measurem Superv 0 58 0 95 0 75 Balance Factor for Voltage Monitor 2904A BALANCE I LIMIT Measurem Superv 1A 0 10 1 00 A 0 50 A Current Balance Monitor 5A 0 50 5 00 A 2 50 A 2905A BAL FACTOR I Measurem Superv 0 10 0 95 0 50 Balance Factor for Current Monitor 2906A ΣI THRESHOLD Measurem Superv 1A 0 10 2 00 A 0 25 A Summated Current Monitoring Threshold 5A 0 50 ...

Page 695: ...Current I2 for CT Angle Error 3013 CT Err F2 Sens Earth Flt 0 0 5 0 0 0 CT Angle Error at I2 3101 FCT EarthFltO C Earth Fault O C ON OFF ON Earth Fault overcurrent function 3102 BLOCK for Dist Earth Fault O C every PICKUP 1phase PICKUP multiph PICKUP NO every PICKUP Block E F for Distance protection 3103 BLOCK 1pDeadTim Earth Fault O C YES NO YES Block E F for 1pole Dead time 3104A Iph STAB Slope ...

Page 696: ...ad time 3137 Trip 1p 3I0 Earth Fault O C YES NO YES Single pole trip with 3I0 3140 Op mode 3I0p Earth Fault O C Earth Fault O C Earth Fault O C Earth Fault O C Forward Reverse Non Directional Inactive Inactive Operating mode 3141 3I0p PICKUP Earth Fault O C Earth Fault O C Earth Fault O C Earth Fault O C 1A 0 05 25 00 A 1 00 A 3I0p Pickup 5A 0 25 125 00 A 5 00 A 3141 3I0p PICKUP Earth Fault O C Ea...

Page 697: ...1 00 A 0 05 A Min earth current IY for polariz ing 5A 0 25 5 00 A 0 25 A 3166 3U2 Earth Fault O C 0 5 10 0 V 0 5 V Min neg seq polarizing voltage 3U2 3167 3I2 Earth Fault O C 1A 0 05 1 00 A 0 05 A Min neg seq polarizing current 3I2 5A 0 25 5 00 A 0 25 A 3168 PHI comp Earth Fault O C 0 360 255 Compensation angle PHI comp for Sr 3169 S forward Earth Fault O C 1A 0 1 10 0 VA 0 3 VA Forward direction ...

Page 698: ...ICKUP with TRIP with TRIP Evolving fault recognition 3407 EV FLT MODE Auto Reclose Stops AutoRecl starts 3p AR starts 3p AR Evolving fault during the dead time 3408 T Start MONITOR Auto Reclose 0 01 300 00 sec 0 50 sec AR start signal monitoring time 3409 CB TIME OUT Auto Reclose 0 01 300 00 sec 3 00 sec Circuit Breaker CB Supervision Time 3410 T RemoteClose Auto Reclose 0 00 300 00 sec 0 20 sec S...

Page 699: ...d time after 3pole trip 3469 2 AR Tdead EV Auto Reclose 0 01 1800 00 sec 1 20 sec Dead time after evolving fault 3470 2 AR CB CLOSE Auto Reclose YES NO NO CB ready interrogation before re closing 3471 2 AR SynRequest Auto Reclose YES NO NO Request for synchro check after 3pole AR 3472 3 AR START Auto Reclose YES NO NO AR start allowed in this cycle 3473 3 AR T ACTION Auto Reclose 0 01 300 00 sec 0...

Page 700: ... 0 V 2 0 V Maximum voltage difference 3532 MC maxFreq Diff Sync Check 0 03 2 00 Hz 0 10 Hz Maximum frequency difference 3533 MC maxAngleDiff Sync Check 2 80 10 Maximum angle difference 3535A MC SYNCHR Sync Check YES NO YES Manual Close at Usy2 Usy1 and Synchr 3536 MC Usy1 Usy2 Sync Check YES NO NO Manual Close at Usy1 and Usy2 3537 MC Usy1 Usy2 Sync Check YES NO NO Manual Close at Usy1 and Usy2 35...

Page 701: ...sec T 3U0 Time Delay or T Ux 3724 3U0 Voltage Prot 1 0 220 0 V 50 0 V 3U0 Pickup or Ux 3725 T 3U0 Voltage Prot 0 00 100 00 sec 1 00 sec T 3U0 Time Delay or T Ux 3728A 3U0 Stabil Voltage Prot ON OFF ON 3U0 Stabilization 3U0 Mea surement 3729A 3U0 RESET Voltage Prot 0 30 0 99 0 95 3U0 Reset ratio or Ux 3731 U1 Voltage Prot OFF Alarm Only ON U Alarm U Trip OFF Operating mode U1 overvoltage prot 3732 ...

Page 702: ...ine Comp Fault Locator NO YES YES Mutual coupling parall line com pensation 3806 Load Compensat Fault Locator NO YES NO Load Compensation 3807 two ended Fault Locator ON OFF ON two ended fault location 3811 Tmax OUTPUT BCD Fault Locator 0 10 180 00 sec 0 30 sec Maximum output time via BCD 3901 FCT BreakerFail Breaker Failure ON OFF ON Breaker Failure Protection 3902 I BF Breaker Failure 1A 0 05 20...

Page 703: ... I 1 Prot Interface ON OFF ON State of protection interface 1 4502 CONNEC 1 OVER Prot Interface F optic direct Com conv 64 kB Com conv 128 kB Com conv 512 kB C37 94 1 slot C37 94 2 slots C37 94 4 slots C37 94 8 slots F optic direct Connection 1 over 4505A PROT 1 T DELAY Prot Interface 0 1 30 0 ms 30 0 ms Prot 1 Maximal permissible delay time 4506A PROT 1 UNSYM Prot Interface 0 000 3 000 ms 0 100 m...

Page 704: ...tem Data 2 1A 0 000 100 000 µF km 0 010 µF km S1 feeder capacitance c in µF km 5A 0 000 500 000 µF km 0 050 µF km 6003 S1 c P System Data 2 1A 0 000 160 000 µF mi 0 016 µF mi S1 feeder capacitance c in µF mile 5A 0 000 800 000 µF mi 0 080 µF mi 6004 S1 Line length P System Data 2 0 1 1000 0 km 100 0 km S1 Line length in kilometer 6004 S1 line length P System Data 2 0 1 650 0 Miles 62 1 Miles S1 Li...

Page 705: ...ce per mile x 5A 0 0010 3 0000 Ω mi 0 0484 Ω mi 6043 S3 c P System Data 2 1A 0 000 100 000 µF km 0 010 µF km S3 feeder capacitance c in µF km 5A 0 000 500 000 µF km 0 050 µF km 6043 S3 c P System Data 2 1A 0 000 160 000 µF mi 0 016 µF mi S3 feeder capacitance c in µF mile 5A 0 000 800 000 µF mi 0 080 µF mi 6044 S3 Line length P System Data 2 0 1 1000 0 km 100 0 km S3 Line length in kilometer 6044 ...

Page 706: ...ocatable In column Marked in Oscill Record the following applies UPPER CASE NOTATION M definitely set not allocatable lower case notation m preset allocatable not preset allocatable blank neither preset nor allocatable No Description Function Type of In for matio n Log Buffers Configurable in Matrix IEC 60870 5 103 Event Log ON OFF Trip Fault Log On Off Ground Fault Log ON OFF Marked in Oscill Rec...

Page 707: ...f BO 240 160 20 Breaker Breaker Control Device DP on off BI CB 240 160 1 Yes Disconnect Switch Disc Swit Control Device CF_D 2 on off BO 240 161 20 Disconnect Switch Disc Swit Control Device DP on off BI CB 240 161 1 Yes Earth Switch EarthSwit Control Device CF_D 2 on off BO 240 164 20 Earth Switch EarthSwit Control Device DP on off BI CB 240 164 1 Yes Interlocking Breaker Open Brk Open Control De...

Page 708: ...BO CB 3 Synchronize Internal Real Time Clock Time Synch Device SP LED BI BO 4 Trigger Waveform Capture Trig Wave Cap Osc Fault Rec SP on m LED BI BO 5 Reset LED Reset LED Device SP LED BI BO 7 Setting Group Select Bit 0 Set Group Bit0 Change Group SP LED BI BO 8 Setting Group Select Bit 1 Set Group Bit1 Change Group SP LED BI BO 009 0100 Failure EN100 Modul Failure Modul EN100 Modul 1 IntSP on off...

Page 709: ...uto Reclose IntSP on off LED BO 128 Teleprot ON OFF via system port TelepONoff Device IntSP on off LED BO 130 Load angle Phi PQ Positive se quence ϕ PQ Pos Seq Measurem Superv OUT LED BO 131 Load angle Phi PQ blocked ϕ PQ Pos block Measurem Superv OUT LED BO 132 Setting error PhiA PhiB 3 ϕ Set wrong Measurem Superv OUT LED BO 140 Error with a summary alarm Error Sum Alarm Device OUT on off LED BO ...

Page 710: ...ferent from setting Error1A 5Awrong Device OUT on off LED BO 135 169 1 Yes 193 Alarm Analog input adjustment invalid Alarm adjustm Device OUT on off LED BO 135 181 1 Yes 194 Error Neutral CT different from MLFB Error neutralCT Device OUT on off LED BO 135 180 1 Yes 196 Fuse Fail Monitor is switched OFF Fuse Fail M OFF Measurem Superv OUT LED BO 135 196 1 Yes 197 Measurement Supervision is switched...

Page 711: ...mory Operation exceeded Warn Mem Oper Device OUT on off LED BO 323 Warn Limit of Memory New ex ceeded Warn Mem New Device OUT on off LED BO 351 Circuit breaker aux contact Pole L1 CB Aux L1 P System Data 2 SP LED BI BO 150 1 1 Yes 352 Circuit breaker aux contact Pole L2 CB Aux L2 P System Data 2 SP LED BI BO 150 2 1 Yes 353 Circuit breaker aux contact Pole L3 CB Aux L3 P System Data 2 SP LED BI BO...

Page 712: ...Max meter SP on LED BI BO 404 Pdmd MIN MAX Buffer Reset Pdmd MiMaReset Min Max meter SP on LED BI BO 405 Qdmd MIN MAX Buffer Reset Qdmd MiMaReset Min Max meter SP on LED BI BO 406 Sdmd MIN MAX Buffer Reset Sdmd MiMaReset Min Max meter SP on 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 ...

Page 713: ...from Pickup to TRIP TRIP Time P System Data 2 VI 560 Single phase trip was coupled 3phase Trip Coupled 3p P System Data 2 OUT on LED BO 150 210 2 No 561 Manual close signal detected Man Clos Detect P System Data 2 OUT on LED BO 150 211 1 No 562 CB CLOSE command for manual closing Man Close Cmd P System Data 2 OUT LED BO 150 212 1 No 563 CB alarm suppressed CB Alarm Supp P System Data 2 OUT LED BO ...

Page 714: ...2 4 No 1123 Fault Locator Loop L1E FL Loop L1E Fault Locator OUT_ Ev on 1124 Fault Locator Loop L2E FL Loop L2E Fault Locator OUT_ Ev on 1125 Fault Locator Loop L3E FL Loop L3E Fault Locator OUT_ Ev on 1126 Fault Locator Loop L1L2 FL Loop L1L2 Fault Locator OUT_ Ev on 1127 Fault Locator Loop L2L3 FL Loop L2L3 Fault Locator OUT_ Ev on 1128 Fault Locator Loop L3L1 FL Loop L3L1 Fault Locator OUT_ Ev ...

Page 715: ... Sensitve E F detection picked up SensEF Pickup Sens Earth Flt OUT on off LED BO 1272 Sensitve E F detection Phase L1 SensEF Phase L1 Sens Earth Flt OUT ON LED BO 1273 Sensitve E F detection Phase L2 SensEF Phase L2 Sens Earth Flt OUT ON LED BO 1274 Sensitve E F detection Phase L3 SensEF Phase L3 Sens Earth Flt OUT ON LED BO 1276 Sensitve E F detection Forward SensEF Forward Sens Earth Flt OUT ON ...

Page 716: ...1 Ph L3 EF Rec Ch1 L3 Teleprot E F SP on off on LED BI BO 166 27 1 Yes 1328 E F Unblocking UNBLOCK Chan 1 Ph L1 EF UB ub 1 L1 Teleprot E F SP on off on LED BI BO 166 28 1 Yes 1329 E F Unblocking UNBLOCK Chan 1 Ph L2 EF UB ub 1 L2 Teleprot E F SP on off on LED BI BO 166 29 1 Yes 1330 E F Unblocking UNBLOCK Chan 1 Ph L3 EF UB ub 1 L3 Teleprot E F SP on off on LED BI BO 166 30 1 Yes 1331 Earth fault ...

Page 717: ... SEND L2 Teleprot E F OUT on on LED BO 166 72 1 No 1373 E F Telep Carrier SEND signal Phase L3 EF Tele SEND L3 Teleprot E F OUT on on LED BO 166 73 1 No 1374 E F Telep Block carrier STOP signal L1 EF Tele STOP L1 Teleprot E F OUT on LED BO 166 74 2 No 1375 E F Telep Block carrier STOP signal L2 EF Tele STOP L2 Teleprot E F OUT on LED BO 166 75 2 No 1376 E F Telep Block carrier STOP signal L3 EF Te...

Page 718: ...Yes 1461 Breaker failure protection started BF Start Breaker Failure OUT on off LED BO 166 161 2 Yes 1472 BF Trip T1 local trip only phase L1 BF T1 TRIP 1pL1 Breaker Failure OUT on LED BO 1473 BF Trip T1 local trip only phase L2 BF T1 TRIP 1pL2 Breaker Failure OUT on LED BO 1474 BF Trip T1 local trip only phase L3 BF T1 TRIP 1pL3 Breaker Failure OUT on LED BO 1476 BF Trip T1 local trip 3pole BF T1...

Page 719: ...0 13 2 Yes 2714 AR External trip L3 for AR start Trip L3 AR Auto Reclose SP on LED BI BO 40 14 2 Yes 2715 AR External 1pole trip for AR start Trip 1pole AR Auto Reclose SP on LED BI BO 40 15 2 Yes 2716 AR External 3pole trip for AR start Trip 3pole AR Auto Reclose SP on LED BI BO 40 16 2 Yes 2727 AR Remote Close signal AR RemoteClose Auto Reclose SP on LED BI BO 40 22 2 Yes 2731 AR Sync release fr...

Page 720: ...ose in progress AR in progress Auto Reclose OUT on LED BO 40 101 2 Yes 2809 AR Start signal monitoring time expired AR T Start Exp Auto Reclose OUT on LED BO 40 174 2 Yes 2810 AR Maximum dead time expired AR TdeadMax Exp Auto Reclose OUT on LED BO 40 175 2 Yes 2818 AR Evolving fault recognition AR evolving Flt Auto Reclose OUT on LED BO 40 118 2 Yes 2820 AR is set to operate after 1p trip only AR ...

Page 721: ...R 3rd cycle zone extension release AR 3 CycZoneRel Auto Reclose OUT LED BO 40 170 1 Yes 2892 AR 4th cycle zone extension release AR 4 CycZoneRel Auto Reclose OUT LED BO 40 172 1 Yes 2893 AR zone extension general AR Zone Release Auto Reclose OUT LED BO 40 173 1 Yes 2894 AR Remote close signal send AR Remote Close Auto Reclose OUT on LED BO 40 129 2 Yes 2895 No of 1st AR cycle CLOSE com mands 1pole...

Page 722: ...ition Usy1 Usy2 true SYNC Usy1 Usy2 Sync Check OUT on off LED BO 41 46 1 Yes 2947 Sync Voltage diff greater than limit Sync Udiff Sync Check OUT on off on off LED BO 41 47 1 Yes 2948 Sync Freq diff greater than limit Sync fdiff Sync Check OUT on off on off LED BO 41 48 1 Yes 2949 Sync Angle diff greater than limit Sync ϕ diff Sync Check OUT on off on off LED BO 41 49 1 Yes 2951 Synchronism release...

Page 723: ...in phase L2 Diff Flt L2 Diff Prot OUT on off m LED BO 92 94 2 Yes 3135 Diff Fault detection in phase L3 Diff Flt L3 Diff Prot OUT on off m LED BO 92 95 2 Yes 3136 Diff Earth fault detection Diff Flt E Diff Prot OUT on off m LED BO 92 96 2 Yes 3137 Diff Fault detection of I Diff I Diff Flt Diff Prot OUT on off m LED BO 92 97 2 Yes 3139 Diff Fault detection of I Diff I Diff Flt Diff Prot OUT on off ...

Page 724: ...P on off LED FC TN BO 92 107 1 Yes 3192 Diff Remote relay in Teststate TestDiff remote Diff Prot OUT on off LED BO 92 108 1 Yes 3193 Diff Commissioning state is active Comm Diff act Diff Prot OUT on off LED BO 92 109 1 Yes 3197 Diff Set Teststate of Diff protec tion Test Diff ON Diff Prot SP on off LED BI BO 3198 Diff Reset Teststate of Diff protec Test Diff OFF Diff Prot SP on off LED BI BO 3199 ...

Page 725: ...erface OUT on off LED BO 3249 GPS Prot Int 2 is GPS sy chronized PI 2 GPS sync Prot Interface OUT on off LED BO 3250 GPS PI1 unsym propagation delay too high PI 1 PD unsym Prot Interface OUT on off LED BO 3251 GPS PI2 unsym propagation delay too high PI 2 PD unsym Prot Interface OUT on off LED BO 3252 PI1 Synchronization RESET SYNC PI1 RESET Prot Interface SP on off LED BI BO 3253 PI2 Synchronizat...

Page 726: ...lete Diff Topo OUT on off LED BO 3475 Relay 1 in Logout state Rel1Logout Diff Topo IntSP on off LED FC TN BO 93 143 1 Yes 3476 Relay 2 in Logout state Rel2Logout Diff Topo IntSP on off LED FC TN BO 93 144 1 Yes 3477 Relay 3 in Logout state Rel3Logout Diff Topo IntSP on off LED FC TN BO 93 145 1 Yes 3478 Relay 4 in Logout state Rel4Logout Diff Topo IntSP on off LED FC TN BO 93 146 1 Yes 3479 Relay ...

Page 727: ... Intertrip OUT on off LED BO 3514 I Trip Sending at Prot Interface 2 L1 ITrp sen PI2 L1 Intertrip OUT on off LED BO 3515 I Trip Sending at Prot Interface 2 L2 ITrp sen PI2 L2 Intertrip OUT on off LED BO 3516 I Trip Sending at Prot Interface 2 L3 ITrp sen PI2 L3 Intertrip OUT on off LED BO 3517 I Trip General TRIP ITrp Gen TRIP Intertrip OUT on off m LED BO 3518 I Trip TRIP Only L1 ITrp TRIP 1p L1 ...

Page 728: ...input Rem Signal 5 Remote Signals SP on off LED BI BO 3554 Remote Signal 6 input Rem Signal 6 Remote Signals SP on off LED BI BO 3555 Remote Signal 7 input Rem Signal 7 Remote Signals SP on off LED BI BO 3556 Remote Signal 8 input Rem Signal 8 Remote Signals SP on off LED BI BO 3557 Remote Signal 9 input Rem Signal 9 Remote Signals SP on off LED BI BO 3558 Remote Signal 10 input Rem Signal10 Remot...

Page 729: ...ecv Remote Signals OUT on off LED BO 93 167 1 Yes 3583 Remote signal 11 received Rem Sig11recv Remote Signals OUT on off LED BO 93 168 1 Yes 3584 Remote signal 12 received Rem Sig12recv Remote Signals OUT on off LED BO 93 169 1 Yes 3585 Remote signal 13 received Rem Sig13recv Remote Signals OUT on off LED BO 93 170 1 Yes 3586 Remote signal 14 received Rem Sig14recv Remote Signals OUT on off LED BO...

Page 730: ...General OUT LED BO 28 53 1 Yes 3654 Setting error K0 Z1 or Angle K0 Z1 Dis ErrorK0 Z1 Dis General OUT on off LED BO 3655 Setting error K0 Z1 or Angle K0 Z1 DisErrorK0 Z1 Dis General OUT on off LED BO 3656 Setting error K0 or Angle K0 Dist Error K0 Dis General OUT on off LED BO 3657 Setting Warning Zone sequence Dist Warn Zseq Dis General OUT on off LED BO 3671 Distance PICKED UP Dis PICKUP Dis Gen...

Page 731: ...f Dis General OUT on off LED BO 3704 Distance Loop L12 selected forward Dis Loop L1 2 f Dis General OUT on off LED BO 3705 Distance Loop L23 selected forward Dis Loop L2 3 f Dis General OUT on off LED BO 3706 Distance Loop L31 selected forward Dis Loop L3 1 f Dis General OUT on off LED BO 3707 Distance Loop L1E selected reverse Dis Loop L1 E r Dis General OUT on off LED BO 3708 Distance Loop L2E s...

Page 732: ...l OUT LED BO 3751 Distance Pickup Z1B Loop L23 Dis Z1B L23 Dis General OUT LED BO 3752 Distance Pickup Z1B Loop L31 Dis Z1B L31 Dis General OUT LED BO 3755 Distance Pickup Z2 Dis Pickup Z2 Dis General OUT LED BO 3758 Distance Pickup Z3 Dis Pickup Z3 Dis General OUT LED BO 3759 Distance Pickup Z4 Dis Pickup Z4 Dis General OUT LED BO 3760 Distance Pickup Z5 Dis Pickup Z5 Dis General OUT LED BO 3762 ...

Page 733: ...3phase in Z4 Dis TRIP 3p Z4 Dis General OUT LED BO 28 209 2 No 3822 Distance TRIP 3phase in Z5 Dis TRIP 3p Z5 Dis General OUT LED BO 28 210 2 No 3823 DisTRIP 3phase in Z1 with single ph Flt DisTRIP3p Z1sf Dis General OUT LED BO 28 224 2 No 3824 DisTRIP 3phase in Z1 with multi ph Flt DisTRIP3p Z1mf Dis General OUT LED BO 28 225 2 No 3825 DisTRIP 3phase in Z1B with single ph Flt DisTRIP3p Z1Bsf Dis ...

Page 734: ...BO 4051 Teleprotection is switched ON Telep ON Device IntSP LED BO 29 51 1 Yes 4052 Dis Teleprotection is switched OFF Dis Telep OFF Teleprot Dist OUT on off LED BO 4054 Dis Telep Carrier signal received Dis T Carr rec Teleprot Dist OUT LED BO 29 54 2 No 4055 Dis Telep Carrier CHANNEL FAILURE Dis T Carr Fail Teleprot Dist OUT LED BO 29 55 1 Yes 4056 Dis Telep Carrier SEND signal Dis T SEND Telepro...

Page 735: ... off LED BI BO 4221 Weak Infeed is switched OFF WeakInf OFF Weak Infeed OUT on off LED BO 25 21 1 Yes 4222 Weak Infeed is BLOCKED Weak Inf BLOCK Weak Infeed OUT on off on off LED BO 25 22 1 Yes 4223 Weak Infeed is ACTIVE Weak Inf ACTIVE Weak Infeed OUT LED BO 25 23 1 Yes 4225 Weak Infeed Zero seq current detected 3I0 detected Weak Infeed OUT on off on off LED BO 4226 Weak Infeed Undervoltg L1 WI U...

Page 736: ...5 86 2 Yes 4287 High Speed O C Pickup I L3 I O C p upL3 SOTF Overcurr OUT on LED BO 25 87 2 Yes 4289 High Speed SOTF O C TRIP Only L1 HS SOF TRIP1pL1 SOTF Overcurr OUT on LED BO 25 89 2 Yes 4290 High Speed SOTF O C TRIP Only L2 HS SOF TRIP1pL2 SOTF Overcurr OUT on LED BO 25 90 2 Yes 4291 High Speed SOTF O C TRIP Only L3 HS SOF TRIP1pL3 SOTF Overcurr OUT on LED BO 25 91 2 Yes 4292 High Speed SOTF O...

Page 737: ...uency Prot OUT on off LED BO 70 183 1 Yes 5215 Frequency protection undervolt age Blk Freq UnderV Blk Frequency Prot OUT on off on off LED BO 70 238 1 Yes 5232 Frequency protection f1 picked up f1 picked up Frequency Prot OUT on off LED BO 70 230 2 Yes 5233 Frequency protection f2 picked up f2 picked up Frequency Prot OUT on off LED BO 70 231 2 Yes 5234 Frequency protection f3 picked up f3 picked ...

Page 738: ...ripCirc Superv OUT on off LED BO 170 53 1 Yes 6865 Failure Trip Circuit FAIL Trip cir TripCirc Superv OUT on off LED BO 192 36 1 Yes 6866 TripC1 blocked Binary input is not set TripC1 ProgFAIL TripCirc Superv OUT on off LED BO 6867 TripC2 blocked Binary input is not set TripC2 ProgFAIL TripCirc Superv OUT on off LED BO 6868 TripC3 blocked Binary input is not set TripC3 ProgFAIL TripCirc Superv OUT...

Page 739: ...No 7176 Backup O C Pickup L12 O C Pickup L12 Back Up O C OUT on LED BO 64 76 2 No 7177 Backup O C Pickup L12E O C Pickup L12E Back Up O C OUT on LED BO 64 77 2 No 7178 Backup O C Pickup Only L3 O C PU 1p L3 Back Up O C OUT on LED BO 64 78 2 No 7179 Backup O C Pickup L3E O C Pickup L3E Back Up O C OUT on LED BO 64 79 2 No 7180 Backup O C Pickup L31 O C Pickup L31 Back Up O C OUT on LED BO 64 80 2 N...

Page 740: ...sting OUT on off LED BO 153 28 1 Yes 7329 CB1 TEST CLOSE command CB1 TEST close Testing OUT on off LED BO 153 29 1 Yes 7345 CB TEST is in progress CB TEST running Testing OUT on off LED BO 153 45 1 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...

Page 741: ...h e BLK Voltage Prot OUT on off on off LED BO 73 26 1 Yes 10227 Uph ph Undervolt is switched OFF Uph ph OFF Voltage Prot OUT on off LED BO 73 27 1 Yes 10228 Uphph Undervolt is BLOCKED Uph ph BLK Voltage Prot OUT on off on off LED BO 73 28 1 Yes 10229 U1 Undervolt is switched OFF U1 OFF Voltage Prot OUT on off LED BO 73 29 1 Yes 10230 U1 Undervolt is BLOCKED U1 BLK Voltage Prot OUT on off on off LE...

Page 742: ... Voltage Prot OUT LED BO 73 141 2 Yes 10266 Uph ph Pickup L1 L2 Uph ph PU L12 Voltage Prot OUT LED BO 73 142 2 Yes 10267 Uph ph Pickup L2 L3 Uph ph PU L23 Voltage Prot OUT LED BO 73 143 2 Yes 10268 Uph ph Pickup L3 L1 Uph ph PU L31 Voltage Prot OUT LED BO 73 144 2 Yes 10270 3U0 Pickup 3U0 Pickup Voltage Prot OUT on off LED BO 73 70 2 Yes 10271 3U0 Pickup 3U0 Pickup Voltage Prot OUT on off LED BO 7...

Page 743: ...oltage Prot OUT LED BO 73 146 2 Yes 10320 Uph e Pickup L3 Uph e PU L3 Voltage Prot OUT LED BO 73 147 2 Yes 10321 Uph e Pickup L1 Uph e PU L1 Voltage Prot OUT LED BO 73 148 2 Yes 10322 Uph e Pickup L2 Uph e PU L2 Voltage Prot OUT LED BO 73 149 2 Yes 10323 Uph e Pickup L3 Uph e PU L3 Voltage Prot OUT LED BO 73 150 2 Yes 10325 Uph ph Pickup Uph ph Pickup Voltage Prot OUT on off LED BO 73 125 2 Yes 10...

Page 744: ...D PU L23 HighSpeedDIS OUT on off LED BO 10826 High Speed Distance Pick Up L31 HSD PU L31 HighSpeedDIS OUT on off LED BO 10830 High Speed Distance General Trip HSD Gen Trip HighSpeedDIS OUT on off LED BO 10831 High Speed Distance Trip Command only L1 HSD Trip 1pL1 HighSpeedDIS OUT on off LED BO 10832 High Speed Distance Trip Command only L2 HSD Trip 1pL2 HighSpeedDIS OUT on off LED BO 10833 High Sp...

Page 745: ...Q8 OpCnt Control Device VI 31009 Q9 operationcounter Q9 OpCnt Control Device VI No Description Function Type of In for matio n Log Buffers Configurable in Matrix IEC 60870 5 103 Event Log ON OFF Trip Fault Log On Off Ground Fault Log ON OFF Marked in Oscill Record LED Binary Input Function Key Relay Chatter Suppression Type Information Number Data Unit General Interrogation ...

Page 746: ...71 177 183 184 185 186 187 188 189 190 191 193 361 3654 3655 Failure Σi Fail I balance Fail Σ U Ph E Fail U balance Fail U absent VT FuseFail 10s VT FuseFail Fail Ph Seq Fail Battery Error Board 1 Error Board 2 Error Board 3 Error Board 4 Error Board 5 Error Board 6 Error Board 7 Error Board 0 Error Offset Alarm adjustm FAIL Feeder VT Dis ErrorK0 Z1 DisErrorK0 Z1 161 Fail I Superv 289 163 Failure ...

Page 747: ...D DD 621 U L1 E UL1E Measurement 134 129 No 9 4 CFC CD DD 622 U L2 E UL2E Measurement 134 129 No 9 5 CFC CD DD 623 U L3 E UL3E Measurement 134 129 No 9 6 CFC CD DD 624 U L12 UL12 Measurement 134 129 No 9 10 CFC CD DD 625 U L23 UL23 Measurement 134 129 No 9 11 CFC CD DD 626 U L31 UL31 Measurement 134 129 No 9 12 CFC CD DD 627 Uen Uen Measurement CFC CD DD 631 3U0 zero sequence 3U0 Measurement CFC C...

Page 748: ...er CFC CD DD 847 Reactive Power Demand Minimum QdMin Min Max meter CFC CD DD 848 Reactive Power Demand Maximum Qd Max Min Max meter CFC CD DD 849 Apparent Power Demand Minimum SdMin Min Max meter CFC CD DD 850 Apparent Power Demand Maximum Sd Max Min Max meter CFC CD DD 851 I L1 Minimum IL1Min Min Max meter CFC CD DD 852 I L1 Maximum IL1Max Min Max meter CFC CD DD 853 I L2 Mimimum IL2Min Min Max m...

Page 749: ...D DD 974 X L1E X L1E Measurement CFC CD DD 975 X L2E X L2E Measurement CFC CD DD 976 X L3E X L3E Measurement CFC CD DD 977 X L12 X L12 Measurement CFC CD DD 978 X L23 X L23 Measurement CFC CD DD 979 X L31 X L31 Measurement CFC CD DD 1040 Active Power Minimum Forward Pmin Forw Min Max meter CFC CD DD 1041 Active Power Maximum Forward Pmax Forw Min Max meter CFC CD DD 1042 Active Power Minimum Rever...

Page 750: ... CD DD 7748 Diff3I0 Differential current 3I0 Diff3I0 IDiff IRest CFC CD DD 7751 Prot Interface 1 Transmission delay PI1 TD Statistics 134 122 No 9 7 CFC CD DD 7752 Prot Interface 2 Transmission delay PI2 TD Statistics 134 122 No 9 9 CFC CD DD 7753 Prot Interface 1 Availability per min PI1A m Statistics CFC CD DD 7754 Prot Interface 1 Availability per hour PI1A h Statistics 134 122 No 9 8 CFC CD DD...

Page 751: ...loc ΦI L1 Measure relay3 CFC CD DD 7804 IL2 of Operational nominal current IL2_opN Measure relay3 CFC CD DD 7805 Angle IL2_rem IL2_loc ΦI L2 Measure relay3 CFC CD DD 7806 IL3 of Operational nominal current IL3_opN Measure relay3 CFC CD DD 7807 Angle IL3_rem IL3_loc ΦI L3 Measure relay3 CFC CD DD 7809 UL1 of Operational nominal voltage UL1_opN Measure relay3 CFC CD DD 7810 Angle UL1_rem UL1_loc ΦU ...

Page 752: ...l nominal current IL1_opN Measure relay6 CFC CD DD 7863 Angle IL1_rem IL1_loc ΦI L1 Measure relay6 CFC CD DD 7864 IL2 of Operational nominal current IL2_opN Measure relay6 CFC CD DD 7865 Angle IL2_rem IL2_loc ΦI L2 Measure relay6 CFC CD DD 7866 IL3 of Operational nominal current IL3_opN Measure relay6 CFC CD DD 7867 Angle IL3_rem IL3_loc ΦI L3 Measure relay6 CFC CD DD 7869 UL1 of Operational nomin...

Page 753: ... Max Zero Sequence Voltage 3U0 3U0max Min Max meter CFC CD DD 30654 Idiff REF Operational nominal current Id iffREF IDiff IRest CFC CD DD 30655 Irest REF Operational nominal current Ir estREF IDiff IRest CFC CD DD No Description Function IEC 60870 5 103 Configurable in Matrix Type Information Number Compatibility Data Unit Position CFC Control Display Default Display ...

Page 754: ...Appendix A 10 Measured Values SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 754 ...

Page 755: ...417 H1176 C098 A9 4 SIPROTEC SIGRA 4 Manual E50417 H1100 C070 A4 5 Digital Distance Protection Basics and Applications Edition 2 completely revised and extended version May 14 2008 Language German ISBN 10 389578320X ISBN 13 987 3895783203 6 Application Examples for SIPROTEC Protection Devices E50001 K4451 A101 A1 7 Case Studies for SIPROTEC Protection Devices and Power Quality E50001 K4452 A101 A1...

Page 756: ...Literature SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 756 ...

Page 757: ...ytes BP_xx Bit pattern indication Bitstring Of x Bit x designates the length in bits 8 16 24 or 32 bits C_xx Command without feedback CF_xx Command with feedback CFC Continuous Function Chart CFC is a graphical editor with which a program can be created and configured by using ready made blocks CFC blocks Blocks are parts of the user program delimited by their function their structure or their pur...

Page 758: ...e of such a con tainer Control display The display which is displayed on devices with a large graphic display after you have pressed the control key is called the control display It contains the switchgear that can be controlled in the feeder with status display It is used to perform switching operations Defining this display is part of the configuration Data pane The right hand area of the projec...

Page 759: ...one data area to another Earth The conductive earth whose electric potential can be set equal to zero at every point In the area of earth elec trodes the earth can have a potential deviating from zero The term Earth reference plane is often used for this state Earth verb This term means that a conductive part is connected via an earthing system to the earth Earthing Earthing is the total of all me...

Page 760: ...nt indication ExSI_F External single point indication via an ETHERNET connection device specific Transient information Single point indication Field devices Generic term for all devices assigned to the field level Protection devices combination devices bay control lers Floating Without electrical connection to the Earth FMS communication branch Within an FMS communication branch the users communic...

Page 761: ...s which exist in a ModPara project The actual field infor mation of each field is stored in a HV field description file Within the HV project description file each field is allocated such a HV field description file by a reference to the file name HV project description All the data is exported once the configuration and parameterization of PCUs and sub modules using ModPara has been completed Thi...

Page 762: ...an inter relay communication Each user of the combination and all the necessary communication parameters are defined in this object The type and scope of the information exchanged between the users is also stored in this object IRIG B Time signal code of the Inter Range Instrumentation Group IS Internal single point indication Single point indication IS_F Internal indication transient Transient in...

Page 763: ...designa tion This is the equivalent of an order number The type and version of a SIPROTEC 4 device are coded in the order number Modem connection This object type contains information on both partners of a modem connection the local modem and the remote modem Modem profile A modem profile consists of the name of the profile a modem driver and may also comprise several initialization commands and a...

Page 764: ...information On line When working in online mode there is a physical connection to a SIPROTEC 4 device This connection can be implemented as a direct connection as a modem connection or as a PROFIBUS FMS connection OUT Output indication Parameter set The parameter set is the set of all parameters that can be set for a SIPROTEC 4 device Phone book User addresses for a modem connection are saved in t...

Page 765: ...r a cleanup also reassigns the VD addresses The consequence is that all SIPROTEC 4 devices have to be reinitialized RIO file Relay data Interchange format by Omicron RSxxx interface Serial interfaces RS232 RS422 485 SCADA Interface Rear serial interface on the devices for connecting to a control system via IEC or PROFIBUS Service port Rear serial interface on the devices for connecting DIGSI for e...

Page 766: ...n system base V4 SIPROTEC 4 device This object type represents a real SIPROTEC 4 device with all the setting values and process data it contains SIPROTEC 4 variant This object type represents a variant of an object of type SIPROTEC 4 device The device data of this variant may well differ from the device data of the original object However all variants derived from the original object have the same...

Page 767: ...n communicate with one another in an Inter Relay Communication combination The individual participating devices are called users VD A VD Virtual Device includes all communication objects and their properties and states that are used by a communication user through services A VD can be a physical device a module of a device or a software module VD address The VD address is assigned automatically by...

Page 768: ...Glossary SIPROTEC 7SD5 Manual C53000 G1176 C169 5 Release date 02 2011 768 ...

Page 769: ...uts 467 573 Blocking 232 234 Blocking of zone Z1 130 Blocking scheme 203 Breaker intertrip Receiving circuit 111 Remote tripping 112 Transmission circuit 110 Broken Wire Monitoring 422 Busbar Tripping 546 C Calculation of the impedances 124 Certifications 583 Chain topology 75 Change of Operating Stage 536 Changing Setting Groups 497 Characteristics Definite time overcurrent protection 25 Inverse ...

Page 770: ...rolled zone 159 173 Counters and memories 470 Cross polarisation 166 CT error characteristic 51 Cubicle Mounting 523 Cubicle mounting 637 638 Current direction 266 Current flow monitoring 397 Current Inputs 571 current pickup voltage and angle dependentU I ϕ 122 voltage dependentU I 120 Current Symmetry 420 Current transformer characteristic 49 Current transformer requirements 571 Current transfor...

Page 771: ...rpoint current 268 Through fault current 268 Transformer saturation 269 Tripping Characteristic 269 Earth fault detection 115 132 Earth Fault Detection in a non earthed system 613 Earth fault differential protection Delay times 271 Measurement principle 266 Pickup value 271 Sensitivity 271 Earth Fault Direction Determination 296 Earth Fault Location 297 Earth Fault Protection 598 Characteristics 5...

Page 772: ...pendent Zones 157 172 Independent zones 152 Indication memory 34 Indications 469 Information exchange 90 Information to a Control Centre 468 Input output board C I O 2 513 Input output module C I O 1 506 C I O 10 509 511 Inrush restraint 226 244 Installation Panel Surface Mounting 524 Instantaneous trip I stage 290 I stage 291 Instantaneous tripping 281 before automatic reclosure 307 Instrument Tr...

Page 773: ...rator interface Check 525 Optical Fibres 527 Optical fibres 528 Ordering Data 642 Oscillographic Recording for Test 566 Output Relays 467 Overcurrent pickup 119 U I ϕ pickup 138 U Ipickup 138 Overcurrent stage 3I0 definite time overcurrent protection 311 3I0P inverse time overcurrent protection with ANSI characteristics 313 3I0P inverse time overcurrent protection with IEC characteristics 312 I de...

Page 774: ...accuracy limit factor 50 Rated frequency 48 Real Time Clock and Buffer Battery 636 Reclose Cycle 340 341 Reclosure Blocking 322 Reclosure cycle 339 Reference Voltages 418 Remote Commands 611 Remote commands 287 Remote Indications 611 Remote indications 287 Remote transmission 31 Remote trip 285 Remote Tripping 591 Remote tripping 113 Remote CLOSE 327 Reset 481 Reset of Stored LED Relays 459 Resist...

Page 775: ... with the Circuit Breaker 565 Testing User defined Functions 564 Thermal Overload Protection 626 Tripping Characteristic 626 Three phase measuring voltage failure 436 Three pole coupling 66 Time constant τ 416 Time Overcurrent Protection 31 614 High set Current Stages 614 Overcurrent Stages 615 Time overcurrent protection 25 Characteristics 614 Time Synchronisation Interface 532 Time synchronisati...

Page 776: ...French Specification 610 Weak infeed Tripping Operating Mode 609 Times 609 Undervoltage 609 WEB Monitor 24 548 WEB Monitor 34 464 542 557 WI teleprotection schemes 275 WI undervoltage 275 Work on plug connectors 503 Z Zero Infeed 260 Zero sequence current 267 Zero sequence power protection 224 Zero sequence voltage stages for single phase voltage 367 Zero sequence voltage time protection 222 Zero ...

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