Siemens SIPROTEC 7UT613 series Manual Download

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Contents

7UT613/63x Manual
C53000-G1176-C160-2

Dynamic Cold Load Pickup for Time Overcurrent Protection . . . . . . . . . . . . . . . . . . . . . . 191

2.6.1

Function Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 191

2.6.2

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 193

2.6.3

Settings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194

2.6.4

Information List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 195

2.7

Single-Phase Time Overcurrent Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 196

2.7.1

Function Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 196

2.7.2

High-impedance Differential Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 198

2.7.3

Tank Leakage Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200

2.7.4

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200

2.7.5

Settings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 205

2.7.6

Information List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 205

2.8

Unbalanced Load Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 206

2.8.1

Function Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 206

2.8.2

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 212

2.8.3

Settings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 218

2.8.4

Information List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 219

2.9

Thermal Overload Protection. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 220

2.9.1

General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 220

2.9.2

Overload Protection Using a Thermal Replica . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 220

2.9.3

Overload protection using a thermal replica with ambient temperature influence . . . . . . . 223

2.9.4

Hot-Spot Calculation and Determination of the Ageing Rate . . . . . . . . . . . . . . . . . . . . . . 223

2.9.5

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 226

2.9.6

Settings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 230

2.9.7

Information List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 231

2.10

RTD-Boxes for Overload Detection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 232

2.10.1

Function Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 232

2.10.2

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 232

2.10.3

Settings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 233

2.10.4

Information List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 237

2.11

Overexcitation Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 239

2.11.1

Function Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 239

2.11.2

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 241

2.11.3

Settings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 243

2.11.4

Information List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 244

2.12

Reverse Power Protection. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 245

2.12.1

Function Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 245

2.12.2

Setting Notes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 246

2.12.3

Settings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 249

2.12.4

Information List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 249

Summary of Contents for SIPROTEC 7UT613 series

Page 1: ...SIPROTEC Differential Protection 7UT613 63x V4 60 Manual C53000 G1176 C160 2 Preface Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Appendix A Literature Glossary Index ...

Page 2: ...s for improvement We reserve the right to make technical improvements without notice Copyright Copyright Siemens AG 2006 All rights reserved The reproduction transmission or use of this document or its con tents is not permitted without express written authority Offenders will be liable for damages All rights reserved particularly for the purposes of patent application or trademark registration Re...

Page 3: ...ctrical facilities and power plants Applicability of this Manual This manual is valid for SIPROTEC 4 Differential Protection 7UT613 63x firmware version V4 60 Indication of Con formity This product is UL certified according to the Technical Data This product complies with the directive of the Council of the European Commu nities on the approximation of the laws of the Member States relating to ele...

Page 4: ...operation and maintenance by qualified personnel under observance of all warnings and hints contained in this manual Of particular importance are the general installation and safety regulations for work in a high voltage environment for example ANSI IEC EN DIN or other national and international regulations These regulations must be observed Instructions and Warnings The warnings and notes contain...

Page 5: ...ors of configuration or function parameters which may appear word for word in the display of the device or on the screen of a personal computer with DIGSI are marked in bold letters of a monospace font The same goes for the titles of menus 1234A Parameter addresses have the same character style as parameter names Param eter addresses in overview tables contain the suffix A if the parameter is only...

Page 6: ...Exclusive OR antivalence output is active if only one of the inputs is active Coincidence gate equivalence output is active if both inputs are active or inactive at the same time Dynamic inputs edge triggered above with positive below with negative edge Formation of one analog output signal from a number of analog input signals Limit stage with setting address and parameter designator name Timer p...

Page 7: ...on of the Functional Scope 36 2 1 3 1 Setting Notes 36 2 1 3 2 Settings 43 2 1 4 Power System Data 1 45 2 1 4 1 Topology of the Protected Object 45 2 1 4 2 General Power System Data Power System Data 1 65 2 1 4 3 Assignment of Protection Functions to Measuring Locations Sides 79 2 1 4 4 Circuit Breaker Data 83 2 1 4 5 Settings 84 2 1 4 6 Information List 96 2 1 5 Setting Groups 96 2 1 5 1 Setting ...

Page 8: ...se and Residual Currents 150 2 4 1 General 150 2 4 1 1 Definite Time Instantaneous Overcurrent Protection UMZ 150 2 4 1 2 Inverse Time Overcurrent Protection 154 2 4 1 3 Manual Close Command 158 2 4 1 4 Dynamic Cold Load Pickup 158 2 4 1 5 Inrush Restraint 159 2 4 1 6 Fast Busbar Protection Using Reverse Interlocking 160 2 4 2 Time Overcurrent Protection for Phase Currents 161 2 4 2 1 Setting Note...

Page 9: ...ion List 219 2 9 Thermal Overload Protection 220 2 9 1 General 220 2 9 2 Overload Protection Using a Thermal Replica 220 2 9 3 Overload protection using a thermal replica with ambient temperature influence 223 2 9 4 Hot Spot Calculation and Determination of the Ageing Rate 223 2 9 5 Setting Notes 226 2 9 6 Settings 230 2 9 7 Information List 231 2 10 RTD Boxes for Overload Detection 232 2 10 1 Fun...

Page 10: ...ge Protection 259 2 15 1 Function Description 259 2 15 2 Setting Notes 260 2 15 3 Settings 261 2 15 4 Information List 262 2 16 Frequency Protection 263 2 16 1 Function Description 263 2 16 2 Setting Notes 265 2 16 3 Settings 266 2 16 4 Information List 267 2 17 Circuit Breaker Failure Protection 268 2 17 1 Function Description 268 2 17 2 Setting Notes 272 2 17 3 Settings 274 2 17 4 Information Li...

Page 11: ... Function Description 288 2 19 2 2 Setting Notes 291 2 19 2 3 Settings 291 2 19 2 4 Information List 291 2 19 3 Malfunction Responses of the Device 291 2 19 3 1 Summary of the most important Monitoring Functions 292 2 19 4 Parameterisation Error 293 2 20 Protection Function Control 294 2 20 1 Pickup Logic for the Entire Device 294 2 20 1 1 General Device Pickup 294 2 20 2 Tripping Logic for the En...

Page 12: ...ed Set Points 313 2 22 6 Energy Metering 314 2 22 6 1 Energy Metering 314 2 22 6 2 Information List 315 2 22 7 Flexible Function 315 2 22 7 1 Function Description 315 2 22 7 2 Setting Notes 317 2 22 7 3 Settings 321 2 22 7 4 Information List 324 2 22 8 Oscillographic Fault Recording 325 2 22 8 1 Function Description 325 2 22 8 2 Setting Notes 326 2 22 8 3 Settings 326 2 22 8 4 Information List 327...

Page 13: ...System Connections 377 3 3 Commissioning 379 3 3 1 Test Mode Transmission Block 380 3 3 2 Test Time Synchronisation Interface 380 3 3 3 Testing the System Interface 381 3 3 4 Checking the switching states of the binary Inputs Outputs 383 3 3 5 Checking the Setting Consistency 385 3 3 6 Secondary Check 389 3 3 7 Circuit Breaker Failure Protection Tests 395 3 3 8 Symmetrical Primary Current Tests on...

Page 14: ... for Phase and Residual Currents 442 4 5 Time Overcurrent Protection for Earth Current Starpoint Current 453 4 6 Dynamic Cold Load Pickup for Time Overcurrent Protection 455 4 7 Single Phase Time Overcurrent Protection 456 4 8 Unbalanced Load Protection 457 4 9 Thermal Overload 465 4 10 RTD Boxes for Overload Detection 468 4 11 Overload Protection 469 4 12 Reverse Power Protection 471 4 13 Forward...

Page 15: ...2 A 2 Terminal Assignments 505 A 2 1 Panel Flush and Cubicle Mounting 505 A 2 2 Panel Surface Mounting 514 A 3 Connection Examples 523 A 3 1 Current Transformer Connection Examples 523 A 3 2 Voltage Transformer Connection Examples 536 A 3 3 Assignment of Protection Functions to Protected Objects 538 A 4 Current Transformer Requirements 539 Current Transformer in accordance with BS 3938 IEC 60044 1...

Page 16: ...Contents 16 7UT613 63x Manual C53000 G1176 C160 2 Literature 631 Glossary 623 Index 633 ...

Page 17: ...ial ProtectionThe SIPROTEC 4 device 7UT613 63x is introduced in this chap ter You are presented with an overview of the scope of application the properties and functional scope of the 7UT613 63x 1 1 Overall Operation 18 1 2 Application Scope 21 1 3 Characteristics 23 ...

Page 18: ...e winding transformer with measuring loca tions M1 M2 and M3 with 3 auxiliary 1 phase inputs X1 X2 and X3 Analogue Inputs The analogue inputs AI transform the currents and voltages derived from the instru ment transformers and match them to the internal signal levels for processing in the device Depending on the version the device features between 12 current inputs 7UT613 7UT633 and 16 current inp...

Page 19: ...idth and processing speed The analogue to digital AD stage consists of a multiplexor an analogue to digital A D converter and memory components for the transmission of digital signals to the microcomputer system Microcomputer system In addition to the control of the measured values the actual protection and control functions are processed in the µC microcomputer system In particular the following ...

Page 20: ...tter also has a key switch and a control key for on site control of the device Serial interfaces Via the serial operator interface in the front panel communication with a personal computer using the operating program DIGSI is possible This facilitates a comfortable handling of all device functions A serial service interface can likewise make communication via PC with the device possible by using D...

Page 21: ... currents in the starpoint leads of the machine and at its terminals Similar applies for series reac tors Short lines or mini busbars with 3 to 5 end or feeders depending on the version can be protected as well Short means that the current transformers lead between the CTs and the device do not form an impermissible burden for the CTs For transformers generators motors or shunt reactors with earth...

Page 22: ...shunt reactors This protection function monitors the ratio U f which is proportional to the induction B in the iron core An imminent iron core saturation which can occur es pecially in power stations following full load shutdown and or frequency reduction is thus detected An undervoltage and overvoltage protection is to be integrated into devices with voltage measuring inputs A 4 stage frequency p...

Page 23: ...erexcitation of transformers using a further harmonic 3rd or 5th harmonic Insensitivity to DC components and current transformer saturation High level of stability even with different degrees of current transformer saturation High speed instantaneous trip in case of high current transformer faults Adjustable to the conditioning of the starpoint s of the power transformer Increased earth fault sens...

Page 24: ...ability with optimum matching Suitable for earth fault detection on earthed generators motors shunt reactors and transformers including auto transformers with or without earthed starpoint Suitable for any voltage measurement via the resistor current for application of high impedance unit protection Tank Leakage Pro tection For transformers or reactors the tank of which is installed isolated or wit...

Page 25: ...e g during cold loaded start up of the power plant 2 time overcurrent protection functions are possible for earth current 1 phase Overcur rent Protection Two definite time delayed overcurrent stages which can be combined as desired For any 1 phase overcurrent detection Can be assigned to the normal 1 phase current input or to the highly sensitive current input Suitable for detection of very small ...

Page 26: ...m positive sequence components Short operating time or exact calculation of the active power via 16 cycles Exact real power calculation for small power factor by compensating the error angle of the measuring locations Insensitive to power fluctuations Short time stage with external criteria e g with closed emergency tripping Forward Power Monitoring devic es with measuring voltage inputs Real powe...

Page 27: ...rip commands With or without trip time delay 2 breaker failure protection functions possible Processing of ex ternal information Inclusion of external signals user defined information in internal information pro cessing Pre defined transformer annunciations for Buchholz protection and oil gassing Transmission to output relays LEDs and via serial system interfaces to central control and data storag...

Page 28: ...f voltage inputs are available for symmetry voltage sum and phase rotation Supervision of the voltage transformer circuits if voltage inputs are available for voltage failure with fast function blocking that measure undervoltages Checking the consistency of protection settings regarding the protected object and possible assignment of the current inputs Blocking of the differential protection syste...

Page 29: ... C160 2 Communication with central control and data storage equipment possible via serial interfaces depending on the individual ordering variant by means of data cable modem or optical fibres Various transmission protocols are provided for this pur pose ...

Page 30: ...1 Introduction 30 7UT613 63x Manual C53000 G1176 C160 2 ...

Page 31: ...for Phase and Residual Currents 150 2 5 Time Overcurrent Protection for Earth Current 179 2 6 Dynamic Cold Load Pickup for Time Overcurrent Protection 191 2 7 Single Phase Time Overcurrent Protection 196 2 8 Unbalanced Load Protection 206 2 9 Thermal Overload Protection 220 2 10 RTD Boxes for Overload Detection 232 2 11 Overexcitation Protection 239 2 12 Reverse Power Protection 245 2 13 Forward P...

Page 32: ...2 Functions 32 7UT613 63x Manual C53000 G1176 C160 2 2 23 Average Values Minimum and Maximum Values 329 2 24 Command Processing 332 ...

Page 33: ... Moreover you have to decide which protective functions you want to use because not all of the functions integrated in the device are neces sary useful or even possible for any relevant case of application In the next step section 2 1 4 you describe the topology of the protected object i e the arrangement of the protected object its sides windings for transformers sides for generators motors ends ...

Page 34: ...cations will appear after a system fault by any means In devices with text display the start page of the basic display can be selected under address 204 Start image DD 2 1 1 2 Settings 2 1 1 3 Information List Addr Parameter Setting Options Default Setting Comments 201 FltDisp LED LCD Target on PU Target on TRIP Target on PU Fault Display on LED LCD 202 Spont FltDisp NO YES NO Spontaneous display ...

Page 35: ...evice is equipped with such a module see MLFB the module is automatically configured to the interface available for it namely Port B 5 Reset LED SP Reset LED 15 Test mode SP Test mode 16 DataStop SP Stop data transmission 51 Device OK OUT Device is Operational and Protecting 52 ProtActive IntSP At Least 1 Protection Funct is Active 55 Reset Device OUT Reset Device 56 Initial Start OUT Initial Star...

Page 36: ...explained below Functions configured as Disabled are not pro cessed by the 7UT613 63x There are no indications and associated settings functions limit values are not displayed during detailed settings 2 1 3 1 Setting Notes Determination of the Functional Scope Configuration settings can be entered using a PC and the software program DIGSI and transferred via the front serial port or the rear servi...

Page 37: ...lable Normal Power transformers with separate windings are set as PROT OBJECT 3 phase transf regardless of the number of windings vector groups and the earthing conditions of the starpoints This is also valid if a neutral earthing reactor is situated within the protected zone If the differential protection shall cover a gen erator or motor and a unit connected power transformer also with more than...

Page 38: ...ies to series reactors and shunt reactors if a com plete 3 phase set of current transformers is connected to both sides For the operation of mini busbars set PROT OBJECT 3ph Busbar The maximum number of feeders is determined by the number of three phase measure ment inputs of the device 7UT613 and 7UT633 allow a maximum number of 3 7UT635 a maximum of 5 measuring locations This setting applies als...

Page 39: ...ease refer to Technical Data Overcurrent Pro tection for Phase Currents 2 and 3 In the case of 7UT613 63x it is possible to use two additional phase overcurrent pro tection functions One overcurrent protection can thus be implemented independently on various sides of the main protection object or three phase measuring locations In the case of DMT IDMT Phase2 a selection can be made under the addre...

Page 40: ...rical load protection monitors the asymmetrical current negative se quence system in three phase protected objects In address 140 UNBALANCE LOAD the trip time characteristics can be set to definite time Definite Time additionally operate according to an IEC characteristic TOC IEC or to an ANSI characteristic TOC ANSI It can also be supplemented by a thermal stage DT thermal The asymmetrical load p...

Page 41: ...endent on the version of 7UT613 63x cf Or dering Information and Accessories in the Appendix Port C service interface is available in all versions Depending on the device version Port D is also possible RTD box Type If RTD boxes with 7UT613 63x are operated set the number and type of transfer of measuring locations RTD Resistance Temperature Detector under address 191 RTD CONNECTION 6 RTD simplex ...

Page 42: ...ly only possible in device variant that have a voltage measuring input Frequency Protection The frequency protection address 156 FREQUENCY Prot has the task to detect increased or decreased frequencies in the power station sector It can be applied for example as load shedding in the system It can only be used in three phase protected objects thus not at address 105 PROT OBJECT 1 phase transf or 1p...

Page 43: ...ion pa rameters is carried out at a later stage see section 2 22 7 2 1 3 2 Settings Addr Parameter Setting Options Default Setting Comments 103 Grp Chge OPTION Disabled Enabled Disabled Setting Group Change Option 105 PROT OBJECT 3 phase transf 1 phase transf Autotransf Autotr node Generator Motor 3ph Busbar 1ph Busbar 3 phase transf Protection Object 112 DIFF PROT Disabled Enabled Enabled Differe...

Page 44: ...ite Time TOC IEC TOC ANSI User Defined PU User def Reset Disabled DMT IDMT Earth 2 140 UNBALANCE LOAD Disabled Definite Time TOC IEC TOC ANSI DT thermal Disabled Unbalance Load Negative Se quence 142 THERM OVERLOAD Disabled th rep w o sen th repl w sens IEC354 Disabled Thermal Overload Protection 143 OVEREXC PROT Disabled Enabled Disabled Overexcitation Protection U f 144 THERM OVERLOAD2 Disabled ...

Page 45: ...d Enabled Disabled Breaker Failure Protection 2 180 DISCON MEAS LOC Disabled Enabled Disabled Disconnect measurment location 181 M V SUPERV Disabled Enabled Enabled Measured Values Supervision 182 Trip Cir Sup Disabled 2 Binary Inputs 1 Binary Input Disabled Trip Circuit Supervision 186 EXT TRIP 1 Disabled Enabled Disabled External Trip Function 1 187 EXT TRIP 2 Disabled Enabled Disabled External ...

Page 46: ...with the sides Differences between measure ment locations and sides arise for example if a power transformer winding 1 side is fed from 2 galvanically connected lead wires via 2 sets of current transformers mea suring locations The measuring locations which feed a side of the main protected object are the as signed measuring locations If the device provides more 3 phase current measuring inputs th...

Page 47: ...ause of its branch point to the auxiliaries system circuit M3 and M4 The sum of these currents flows into the low voltage side S2 of the main protected object The 4 measuring locationsM1 to M4 are assigned to the sides of the main protected object thus assigned measuring locations They are the basis for the measured value processing of three phase currents for the differential protection Basically...

Page 48: ...on not assigned to the main protected object The auxiliary measuring location X3 provides the starpoint current of the transformer It is assigned to side 1 of the main protected object as an assigned measuring location This measuring location can be used by the differential protection function for the for mation of the differential current For the restricted earth fault protection operating at the...

Page 49: ...mpares the triple zero sequence current from M5 with the earth fault current of X4 Figure 2 3 Topology of a three winding transformer as main protected object and a neutral reactor arranged outside of the protected zone as a further protected object right hand three phase illustration of the neutral reactor Sides S1 High voltage side of the main protected object power transformer S2 Low voltage si...

Page 50: ...should be edited from the left tab to the right First of all number the sides of the main protected object consecutively next number the measuring locations beginning with those for the main object then for the remain ing In the example Figure 2 2 there are 2 sides S1 and S2 the 5 measuring locations are M1 to M5 The following sequence of sides is advised For power transformers start with the high...

Page 51: ...12 No AssigMeasLoc number of assigned measuring locations Of course this number cannot be higher than that of address 211 The difference No Conn MeasLoc No AssigMeasLoc is the number of non assigned three phase measuring locations Both examples in the Figures 2 2 and 2 3 show five of the four assigned 3 phase measuring locations M1 to M4 M5 is a non assigned measuring lo cation The number of sides...

Page 52: ...to the main protected object side 1 M2 Measuring location assigned to the main protected object side 2 M3 Measuring location assigned to the main protected object side 3 Special Consider ations on Auto Transformers As mentioned above the common windings on auto transformers must always be defined as S1 and S2 A third side may be present if the compensation winding is di mensioned as power winding ...

Page 53: ... transformer bank the connections of the starpoint leads of the auto windings are accessible and often pro vided with current transformers During configuration of the functional scope in section 2 1 3 you have decided whether a differential protection must be realised via the entire transformer bank or whether you prefer a current comparison via the winding of each phase by means of current law Di...

Page 54: ...ormer bank consisting of 3 single phase auto transformers with compensation winding dimensioned as accessible tertiary winding Sides S1 High voltage side of the auto connected winding of the main protected object S2 Low voltage side tap of the auto connected winding of the main protected object S3 Tertiary winding side accessible compensation winding of the main protected object Measuring location...

Page 55: ...Autotransf Autotr node the current comparison protection of the auto transf node is supported On the other hand the compensation winding cannot and must not be included into this protection even if it is accessible and equipped with current transformers This ap plication variant is based on the current law in that all currents flowing in to a winding must total to zero In auto transformers with st...

Page 56: ...ata for 1 Phase Busbar Pro tection If the device is used as busbar protection either as single phase protection or as three phase protection via external summation transformers set the number of feeders of the busbar in address 216 NUMBER OF ENDS The minimum number amounts to 3 ends with less than that the operation of a 7UT613 63x would not make sense The maximum number of feeders amounts to 9end...

Page 57: ... been selected for 2 sides address 213 Only one option is possible M1 M2 i e the 2 measuring locations are assigned M1 to side S1 M2 to side S2 Since no other possibilities exist there are no further options Address 221 ASSIGNM 3M 2S appears if 3 assigned measuring locations address 212 have been selected for 2 sides address 213 The following options are possi ble M1 M2 M3 i e the 3 measuring loca...

Page 58: ...he 5 measuring locations are assigned M1 and M2 and M3 and M4 to side S1 M5 to side S2 M1 M2 M3 M4 M5 i e the 5 measuring locations are assigned M1 to side S1 M2 and M3 and M4 and M5 to side S2 Address 227 ASSIGNM 5M 3S appears if 5 assigned measuring locations address 212 have been selected for 3 sides address 213 The following options are possi ble M1 M2 M3 M4 M5 i e the 5 measuring locations ar...

Page 59: ...earth winding is included as a side due to the parameterisation Table 2 2 Configuration Versions in an auto transformer Table 2 3 Configuration Versions in an auto transformer node address 241 SIDE 1 of the auto transformer must be assigned to a auto connected primary winding as recommended above This is imperative and there fore cannot be changed Address 242 SIDE 2 of the auto transformer must al...

Page 60: ...ons Each of the auxiliary 1 phase current inputs must now be assigned in the addresses 251 to 254 The number of auxiliary inputs depends on the device type cf Table 2 1 In 7UT635 all inputs IX1 to IX3 are only available as additional 1 phase measuring inputs if they are not needed for a fifth 3 phase measuring location i e if only four 3 phase measuring locations are needed The auxiliary inputs ca...

Page 61: ...easuring location that is not assigned to the main protected object In the example shown in Figure 2 3 you can use the restricted earth fault protection for the neutral reactor The auxiliary measuring location X4 is in this case assigned to the measuring location M5 This informs the device that the measured values of the non assigned measuring location M5 3 phase must be compared with the measured...

Page 62: ...ll as described above High Sensitivity Additional 1 phase Measuring Loca tions Depending on the version the devices of the 7UT613 63x family are equipped with 1 or 2 auxiliary high sensitivity measuring inputs which can detect currents as low as 3mA present at the input These inputs can be used for single phase overcurrent pro tection The single phase independent overcurrent protection is suited e...

Page 63: ...ed that are not assigned to the main protected object For voltage measurement at Ue the voltages are measured on Side 2 of the main protected object As these examples show you can select sides busbars assigned or non assigned measuring locations In 1 phase busbar protection voltages can only be measured on the Busbar In practice the voltage assignment depends therefore on the voltages which the de...

Page 64: ... is also advis able here to not to assign the voltage to measuring location M2 or to side S2 but to measuring location M1 or to side S1 For the power calculation the voltages at U with currents at M1 are taken into consideration It is thus ensured that the active power supply of the generator from the network is evaluated as reverse power Figure 2 9 Power measurement at generator If you have the c...

Page 65: ...under address 270 Rated Frequency The available rated frequencies are 50 Hz 60 Hz and 16 7 Hz Phase Sequence Under address 271 PHASE SEQ the presetting for clockwise rotation L1 L2 L3 can be changed if a power plant has an anticlockwise rotation L1 L3 L2 The phase se quence has no influence on the vector group conversion of the differential protection as long as the identical phase rotation is pre...

Page 66: ...rimary value even if the device is generally configured in secondary values The device calculates the rated current of the protected winding from this power The starpoint condition under address 313 STARPNT SIDE 1 Earthed or Isolated If the starpoint is earthed via a current limiting circuit e g low resistive or via a Petersen coil high reactive set Earthed too The starpoint is also treated as Ear...

Page 67: ...e vector group designation For instance for a transformer Yd5 is CONNECTION S2 D and VECTOR GRP S2 5 Every vector group from 0 to 11 can be set provided it is possible for instance Yy Dd and Dz allow only even Yd Yz and Dy allow only odd numerals For the auto connected winding of auto transform ers and for single phase transformers only Y 0 is permissible If a reference winding other than the high...

Page 68: ...g of the transformer In case of different rating of the windings the rated apparent power of the most pow erful winding is the rated apparent power of the transformer In general no circuits are required for matching of the vector group and no manual calculations for converting of rated current are normally necessary Object Data with Generators Motors and Reactors Using the 7UT613 63x for protectio...

Page 69: ...es of the differential protection are referred to this rated current of the main protected object here the busbar If the current rating of the busbar is known set this rated current in address 371 I PRIMARY OP If no rated current of the busbar is defined you should select the highest of the rated currents of the sides feeders In Figure 2 12 the rated object current busbar current would be 1000 A F...

Page 70: ...wn set this rated current in address 371 I PRIMARY OP If no rated current of the busbar is defined you should select the highest of the rated currents of the sides feeders In Figure 2 12 the rated object current busbar current would be 1000 A Under address 381 I PRIMARY OP 1 set the rated primary current of feeder 1 The same considerations apply for the further feeders Address 382 I PRIMARY OP 2 f...

Page 71: ...onsiderations apply to address 409 UN PRI U4 Current Transform er Data for 3 phase Measuring Loca tions The rated primary operational currents for the protected object and its sides derive from the object data The data of the current transformer sets at the sides of the pro tected object generally differ slightly from the object data before described They can also be completely different Currents ...

Page 72: ...2 Functions 72 7UT613 63x Manual C53000 G1176 C160 2 Figure 2 13 Position of CT starpoints at 3 phase measuring locations example ...

Page 73: ...ted current of CTs for measuring location M4 Address 543 IN SEC CT M4 sec rated current of CTs for measuring location M4 Measuring Location 5 Address 551 STRPNT OBJ M5 starpoint position of CTs for measuring location M5 Address 552 IN PRI CT M5 prim rated current of CTs for measuring location M5 Address 553 IN SEC CT M5 sec nominal current CT for measuring location M5 If the device is applied as t...

Page 74: ...The interrogation only applies to data of the number of feeders determined during the configuration accord ing to section 2 1 4 margin heading Global Data for 1 phase Busbar Protection ad dress 216 NUMBER OF ENDS For rated secondary currents please make sure that rated secondary transformer cur rents match with the rated current of the corresponding current input of the device Rated secondary curr...

Page 75: ... primary transformer current for feeder 5 Address 603 IN SEC CT I5 rated secondary current for feeder 5 Feeder 6 Address 611 STRPNT BUS I6 transformer starpoint versus busbar for feeder 6 Address 612 IN PRI CT I6 rated primary transformer current for feeder 6 Address 613 IN SEC CT I6 rated secondary current for feeder 6 Feeder 7 Address 621 STRPNT BUS I7 transformer starpoint versus busbar for fee...

Page 76: ...urrent transformer which is connected and assigned to a further 1 phase current input of the device Please note the previous assignment of the measuring locations see section 2 1 4 1 margin heading Assignment of Auxiliary 1 phase Measuring Locations Distinction must be made for the secondary rated currents whether the 1 phase current input is a normal or a high sensitivity input of the device If a...

Page 77: ...secondary rated CT current For the auxiliary measuring input X3 Address 731 EARTH IX3 AT with the options Terminal R7 or Terminal R8 not for high sensitivity input Address 732 IN PRI CT IX3 primary rated CT current Address 733 IN SEC CT IX3 sec rated CT current not for high sensitivity input Address 734 FACTOR CT IX3 CT transform ratio only for high sensitivity input For the auxiliary measuring in...

Page 78: ...e current and voltage transformers relevant for the reverse power protection under address 803 CORRECT U Ang In electrical machines determina tion of the corrective value is possible at primary commissioning of the machine For the 1 phase voltage input you set at address 811 UN PRI VT U4 the primary rated voltage of the connected 1 phase voltage transformer and at address 812 UN SEC VT U4 the seco...

Page 79: ...sformer it is defined that the 1 phase earth fault current measured at X3 flows into the starpoint of the high voltage winding subsection 2 1 4 Topology of the Protected Object under margin heading Assignment of Auxiliary 1 phase Measuring Locations As the topology thus provides for the differential protection a full description of the pro tected object with all its sides and measuring locations n...

Page 80: ...protective object e g a neutral reactor Set address 414 REF PROT 2 AT in accordance with the aspects as for the first earth fault differential protection Further 3 phase Protection Func tions A reminder the single phase power transformer is treated like a three phase power transformer without phase L2 Therefore the three phase protection functions apply also for this except the overcurrent protect...

Page 81: ... phase currents This means that in the example shown in figure 2 2 the overcurrent protection can be easily used for phase currents DMT IDMT Ph AT at the higher voltage side of the transformer Side 1 and the overcurrent protection for residual currents DMT IDMT 3I0 AT at the lower voltage side Measuring loc 4 The two additional protection functions in addresses 434 DMT IDMT3I0 2AT can also be assi...

Page 82: ... the breaker position but not any current flow for its operation This allows even to monitor a circuit breaker the current of which is not connected to the device But you have to ensure that the feedback information of this breaker is correctly connected and configured With the second circuit breaker failure protection an additional circuit breaker can be monitored The aspects regarding the assign...

Page 83: ...sses 831 to 835 SwitchgCBaux S1 to SwitchgCBaux S5 if a side is concerned or ad dresses 836 to 840 SwitchgCBaux M1 to SwitchgCBaux M5 if a measuring loca tion is concerned You can alternatively monitor any desired circuit breaker exclusively by means of the CB position indication i e without consideration of current flow In this case you must have selected 470 under address BREAKER FAIL AT Ext swi...

Page 84: ...tion during the con figuration of the binary inputs that corresponds to the side or measuring location to which the protection function is assigned From the internal control the device uses the same switching objects that were selected at the addresses 831 to 840 Example If you have assigned the time overcurrent protection for phase currents to measuring location M4 and want it to receive the manu...

Page 85: ...M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 Assignment at 5 assig Meas Loc 2 Sides 227 ASSIGNM 5M 3S M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 Assignment at 5 assig Meas Loc 3 Sides 228 ASSIGNM 5M 4S M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 M1 M2 M3 M4 M5 Assignment at 5 assig Meas Loc 4 Sides 229 ASSIGNM 5M 5S M1 M...

Page 86: ... 3 earth Side 4 earth MeasLoc 1 earth MeasLoc 2 earth MeasLoc 3 earth MeasLoc 4 earth Not connected Auxiliary CT IX3 is used as 254 AUX CT IX4 Not connected conn not assig Side 1 earth Side 2 earth Side 3 earth Side 4 earth Side 5 earth MeasLoc 1 earth MeasLoc 2 earth MeasLoc 3 earth MeasLoc 4 earth MeasLoc 5 earth Not connected Auxiliary CT IX4 is used as 255 AUX CT IX3 TYPE 1A 5A input sensitive...

Page 87: ...uence 276 TEMP UNIT Celsius Fahrenheit Celsius Unit of temperature measurement 311 UN PRI SIDE 1 0 4 800 0 kV 110 0 kV Rated Primary Voltage Side 1 312 SN SIDE 1 0 20 5000 00 MVA 38 10 MVA Rated Apparent Power of Transf Side 1 313 STARPNT SIDE 1 Earthed Isolated Earthed Starpoint of Side 1 is 314 CONNECTION S1 Y D Z Y Transf Winding Connection Side 1 321 UN PRI SIDE 2 0 4 800 0 kV 11 0 kV Rated Pr...

Page 88: ...s 334 CONNECTION S3 Y D Z Y Transf Winding Connection Side 3 335 VECTOR GRP S3 0 1 2 3 4 5 6 7 8 9 10 11 0 Vector Group Numeral of Side 3 341 UN PRI SIDE 4 0 4 800 0 kV 11 0 kV Rated Primary Voltage Side 4 342 SN SIDE 4 0 20 5000 00 MVA 10 00 MVA Rated Apparent Power of Transf Side 4 343 STARPNT SIDE 4 Earthed Isolated Earthed Starpoint of Side 4 is 344 CONNECTION S4 Y D Z Y Transf Winding Connect...

Page 89: ...0000 A 200 A Primary Operating Current Side 3 375 I PRIMARY OP S4 1 100000 A 200 A Primary Operating Current Side 4 376 I PRIMARY OP S5 1 100000 A 200 A Primary Operating Current Side 5 381 I PRIMARY OP 1 1 100000 A 200 A Primary Operating Current End 1 382 I PRIMARY OP 2 1 100000 A 200 A Primary Operating Current End 2 383 I PRIMARY OP 3 1 100000 A 200 A Primary Operating Current End 3 384 I PRIM...

Page 90: ...e 1 Side 2 Side 3 Side 4 Side 5 auto connected n assigMeasLoc3 n assigMeasLoc4 n assigMeasLoc5 Side 1 Restricted earth fault prot as signed to 414 REF PROT 2 AT Side 1 Side 2 Side 3 Side 4 Side 5 auto connected n assigMeasLoc3 n assigMeasLoc4 n assigMeasLoc5 Side 1 Restricted earth fault prot2 as signed to 420 DMT IDMT Ph AT Side 1 Side 2 Side 3 Side 4 Side 5 Measuring loc 1 Measuring loc 2 Measur...

Page 91: ... DMT IDMT Ph3 AT Side 1 Side 2 Side 3 Side 4 Side 5 Measuring loc 1 Measuring loc 2 Measuring loc 3 Measuring loc 4 Measuring loc 5 Side 1 DMT IDMT Phase 3 assigned to 434 DMT IDMT3I0 2AT Side 1 Side 2 Side 3 Side 4 Side 5 Measuring loc 1 Measuring loc 2 Measuring loc 3 Measuring loc 4 Measuring loc 5 Side 1 DMT IDMT 3I0 2 assigned to 436 DMT IDMT3I0 3AT Side 1 Side 2 Side 3 Side 4 Side 5 Measurin...

Page 92: ...ing loc 2 Measuring loc 3 Measuring loc 4 Measuring loc 5 Ext switchg 1 Side 1 Breaker Failure Protection as signed to 471 BREAKER FAIL2AT Side 1 Side 2 Side 3 Side 4 Side 5 Measuring loc 1 Measuring loc 2 Measuring loc 3 Measuring loc 4 Measuring loc 5 Ext switchg 1 Side 1 Breaker Failure Protection 2 as signed to 511 STRPNT OBJ M1 YES NO YES CT Strpnt Meas Loc 1 in Dir of Object 512 IN PRI CT M1...

Page 93: ...Current Meas Loc 5 561 STRPNT BUS I1 YES NO YES CT Starpoint I1 in Direction of Busbar 562 IN PRI CT I1 1 100000 A 200 A CT Rated Primary Current I1 563 IN SEC CT I1 1A 5A 0 1A 1A CT Rated Secondary Current I1 571 STRPNT BUS I2 YES NO YES CT Starpoint I2 in Direction of Busbar 572 IN PRI CT I2 1 100000 A 200 A CT Rated Primary Current I2 573 IN SEC CT I2 1A 5A 0 1A 1A CT Rated Secondary Current I2...

Page 94: ...IN SEC CT I8 1A 5A 0 1A 1A CT Rated Secondary Current I8 641 STRPNT BUS I9 YES NO YES CT Starpoint I9 in Direction of Busbar 642 IN PRI CT I9 1 100000 A 200 A CT Rated Primary Current I9 643 IN SEC CT I9 1A 5A 0 1A 1A CT Rated Secondary Current I9 651 STRPNT BUS I10 YES NO YES CT Starpoint I10 in Direction of Busbar 652 IN PRI CT I10 1 100000 A 200 A CT Rated Primary Current I10 653 IN SEC CT I10 ...

Page 95: ...CT IX4 1A 5A 1A CT rated secondary current IX4 744 FACTOR CT IX4 1 0 300 0 60 0 Factor prim over sek current IX4 801 UN PRI VT SET 1 0 1200 0 kV 110 0 kV VT Rated Prim Voltage Set UL1 UL2 UL3 802 UN SEC VT SET 80 125 V 100 V VT Rated Sec Voltage Set UL1 UL2 UL3 803 CORRECT U Ang 5 00 5 00 0 00 Angle correction UL1 UL2 UL3 VT 811 UN PRI VT U4 1 0 1200 0 kV 110 0 kV VT Rated Primary Voltage U4 812 U...

Page 96: ...Group A is the default selection If the changeover option is desired group changeover must be set to Grp Chge OPTION Enabled during configuration of the functional scope address 103 For the setting of the function parameters each of the required 4 setting groups Group A to Group D must be configured 836 SwitchgCBaux M1 Setting options depend on configuration None Switchgear CBaux at Measuring Loc ...

Page 97: ... or control function In contrast to the P System Data 1 as discussed before they can be changed over with the setting groups and set on the operator panel of the device Only a subset of the infor mation contained in the information list can appear depending on the version and the selected protected object 2 1 6 1 Setting Notes Sign of Power For all protective and additional functions in which the ...

Page 98: ...the current measuring location M2 P Q sign reversed must be set because the current flowing out of the generator withU is supposed to be positive power Circuit Breaker Status In order to function optimally several protection and supplementary functions require information regarding the state of the circuit breaker Command processing makes also use of the feedback information from the switching dev...

Page 99: ...emember to also allocate all binary inputs that are needed to generate a manual close pulse for the various protection functions FNos 30351 to 30360 Note In the following settings overview the values are referred to the rated current of the assigned side I INS Address 1121 PoleOpenCurr M1 for measuring location 1 Address 1122 PoleOpenCurr M2 for measuring location 2 Address 1123 PoleOpenCurr M3 fo...

Page 100: ...0 20 A 1122 PoleOpenCurr M2 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold Meas Loc M2 5A 0 20 5 00 A 0 20 A 1123 PoleOpenCurr M3 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold Meas Loc M3 5A 0 20 5 00 A 0 20 A 1124 PoleOpenCurr M4 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold Meas Loc M4 5A 0 20 5 00 A 0 20 A 1125 PoleOpenCurr M5 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold Meas Lo...

Page 101: ...shold End 11 5A 0 20 5 00 A 0 20 A 0 1A 0 004 0 100 A 0 004 A 1142 PoleOpenCurrI12 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold End 12 5A 0 20 5 00 A 0 20 A 0 1A 0 004 0 100 A 0 004 A 1151 PoleOpenCurrIX1 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold AuxiliaryCT1 5A 0 20 5 00 A 0 20 A 1152 PoleOpenCurrIX2 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold AuxiliaryCT2 5A 0 20 5 00 A 0 20 A...

Page 102: ...Adaption factor CT M3 30063 Gen CT M4 VI General Adaption factor CT M4 30064 Gen CT M5 VI General Adaption factor CT M5 30065 Gen VT U1 VI General Adaption factor VT UL123 30067 par too low VI parameter too low 30068 par too high VI parameter too high 30069 settingFault VI setting fault 30070 Man Clos Det M1 OUT Manual close signal meas loc 1 detected 30071 Man Clos Det M2 OUT Manual close signal ...

Page 103: ...Primary fault current IL3 side4 30272 IL1S5 VI Primary fault current IL1 side5 30273 IL2S5 VI Primary fault current IL2 side5 30274 IL3S5 VI Primary fault current IL3 side5 30275 I8 VI Primary fault current I8 30276 I9 VI Primary fault current I9 30277 I10 VI Primary fault current I10 30278 I11 VI Primary fault current I11 30279 I12 VI Primary fault current I12 30351 ManualClose M1 SP Manual close...

Page 104: ...regard less of the type of protected object A single phase system is referred to Particulars with regard to the individual protected objects follow thereafter Basic Principle with Two Sides Differential protection is based on current comparison It makes use of the fact that a protected object carries always the same current i dashed line in 2 17 below at its two sides in healthy operation This cur...

Page 105: ...former with 4 measuring locations single phase il lustration Current Restraint When an external fault causes a heavy current to flow through the protected zone dif ferences in the magnetic characteristics of the current transformers CT1 and CT2 figure 2 17 under conditions of saturation may cause a significant current flow through the measuring element M If it is greater than the respective pickup...

Page 106: ...cording tot he definition of signs therefore I2 I1 moreover I2 I1 Idiff I1 I2 I1 I1 0 Istab I1 I2 I1 I1 2 I1 No tripping effect Idiff 0 the stabilisation Istab corresponds to double the through flowing current 2 Internal short circuit e g fed with equal currents each side The following appliesI2 I1 moreover I2 I1 Idiff I1 I2 I1 I1 2 I1 Istab I1 I2 I1 I1 2 I1 Tripping effect Idiff and restraint val...

Page 107: ...ders the dynamic behaviour of the differential and restraint quantity The dotted line in figure 2 21 shows the instantaneous currents during an external fault with transformer saturation on one side Immediately after the fault A the short circuit currents rise strongly causing a corre spondingly high restraint current 2 through flowing current At the instant of CT sat uration B a differential quan...

Page 108: ...o during parallel connection of transformers or an overexcitation of a power transformer differential quantities may occur due to magne tising currents caused by increased voltage and or decreased frequency The inrush current can amount to a multiple of the rated current and is characterised by a considerable 2nd harmonic content double rated frequency which is practically absent during a short ci...

Page 109: ...twice the set threshold Increase of the Pickup Value on Startup The increase of pickup value is especially suited for motors In contrast to the inrush current of transformers the inrush current of motors is a traversing current Differential currents however can emerge if current transformers still contain different remanent magnetisation before energise Therefore the transformers are energised fro...

Page 110: ...FF and considers constant error currents such as magnetising cur rents Branch b considers current proportional errors which may result from transformation errors of the main CTs or the input CTs of the device or which for example may be caused by mismatching or by the influence of tap changers in transformers with voltage control For high currents which may give rise to current transformer saturat...

Page 111: ...tection is identical to the trip condition Like all SIPROTEC 4 devices however the differential protection feature of the 7UT613 63x has a pickup that is the starting point for a number of subsequent activities The pickup marks the beginning of a fault This is necessary e g for creating fault logs and fault records However internal func tions also require the instant of fault inception even in cas...

Page 112: ...2 Functions 112 7UT613 63x Manual C53000 G1176 C160 2 Figure 2 25 Tripping logic of the differential protection simplified ...

Page 113: ... various power transformer and current transformer ratios and of the phase displacement according to the vector group of the protected transformer is per formed purely mathematically As a rule external matching transformers are not re quired The input currents are converted in relation to the power transformer rated currents This is achieved by entering the rated transformer data such as rated pow...

Page 114: ...r of the protected object i e 72 MVA This results in a rated current i e the current under nominal conditions of the protected object 72 MVA of 4157 A This is the base value for the third winding These currents must be multiplied by the factor k3 Figure 2 27 Magnitude matching example of a three winding power transformer phase relation not considered The device carries out this magnitude matching ...

Page 115: ...ce there is no point earthed within the protected zone no considerable zero se quence current can be produced within the protected zone in case of an earth fault outside the protected zone regardless whether or not the system starpoint is earthed anywhere else in the system In case of an earth fault within the protected zone a zero sequence current may occur at a measuring location if the system s...

Page 116: ...3 negative here is compensated by the starpoint current ISP In this way almost full sensitivity with zero sequence current is achieved for internal earth faults and full elimination of the zero sequence current in case of external earth faults For consider ation of the earth fault current the advanced parameter diff protection with measured earth current side x must be switched on addresses 1211 D...

Page 117: ...the left side Comparison of the phase currents without zero sequence current elimination and without inclusion of the starpoint current would cause a wrong result current difference in spite of an external fault Figure 2 30 Matching the transformer vector group example YNd5 magnitudes not consid ered Figure 2 31 shows an example of an earth fault on the delta side outside the protected zone if an ...

Page 118: ...3 343 STARPNT SIDE 4 353 STARPNT SIDE 5 Use on Auto Trans formers In order to achieve comparable currents for the differential protection all currents are referred to the winding side with the highest power rating This apparent power is named the rated power of the protected object If this rated apparent power occurs several times the side with the higher nominal current is selected as reference s...

Page 119: ...se of the physical sep aration of the three transformers A current comparison protection can be built up over each of the auto connected windings which compares the currents flowing into the total winding However a further galvanically separated winding usually delta wind ing can not be protected by means of this protection method A further requirement is that during configuration of the functiona...

Page 120: ...rth faults in the network in case of an earth point in the protected zone transformer starpoint are rendered harmless without any special external measures The matrices for the left and the right winding as per figure 2 34 are The disadvantage of elimination of the zero sequence current is that the differential protection becomes less sensitive by factor 1 2 because the zero sequence current amoun...

Page 121: ...d zone is limited by the sets of current transformers at each side of the protected object On generators and motors the CT are installed in starpoint connection at the terminal side Since the current direction is normally defined as positive in the direction of the protected object for differential protection schemes the definitions shown in figure 2 36 apply Figure 2 36 Definition of current dire...

Page 122: ...y the Restricted Earth Fault Protection see section 2 3 or the High impedance Differential Protection see section 2 7 2 2 4 Differential Protection for Shunt Reactors If current transformers are available for each phase at both sides of a shunt reactor the same considerations apply for series reactors In most cases current transformers are installed in the lead phases and in the star point connect...

Page 123: ...e is also suitable for short lines or cables Short means in this context that the current transformer connections from the CTs to the device do not cause impermissible load to the current transformers On the other hand capacitive charging currents do not harm this operation because the differential protection is nor mally less sensitive with this application Since the current direction is normally...

Page 124: ...ferential current in the range of operational currents indicates a fault in the secondary circuit of the current transformers This monitor operates phase selectively When during normal load conditions a dif ferential current is detected in the order of the load current of a feeder this indicates a missing secondary current i e a fault in the secondary current leads short circuit or open circuit Th...

Page 125: ...er nal matching devices are necessary even if the feeders and or the current transformer sets at the ends of the protected zone have different primary currents Figure 2 42 Single phase busbar protection illustrated L1 Connection via Summation CT One single device 7UT613 63xis sufficient for a busbar with up to 7 feeders if the device is connected via summation current transformers The phase curren...

Page 126: ...s of the conditioning of the system neutral It is characterised by an increased sensitivity for earth faults Figure 2 44 Summation Transformer Connection L1 L3 E For a symmetrical three phase current where the earth residual component IE 0 the single phase summation current is W 3 times the winding unit value as shown in figure 2 45 i e the summation flux ampere turns is the same as it would be fo...

Page 127: ...ial protection is more sensitive to earth faults and to double earth faults than to those without earth path component This increased sensi tivity is due to the fact that the summation transformer winding in the CT starpoint con nection IE residual current refer to figure 2 44 has the largest number of turns and thus the weighting factor W 3 If the higher earth current sensitivity is not necessary...

Page 128: ...eutral can be obtained by cyclic or acyclic exchange of the phases Further increase of the earth current can be performed by introducing an auto CT in the residual path as a further possibility The type 4AM5120 is recommended for summation current transformers These transformers have different input windings which allow for summation of the currents with the ratio 2 1 3 as well as matching of diff...

Page 129: ...condary current i e a fault in the secondary current leads short circuit or open circuit This condition is annunciat ed with time delay The differential protection is blocked at the same time Feeder Current Guard With busbars a release of the trip command can be set if a threshold is exceeded by one of the incoming currents The currents of each feeder are monitored for over shooting of a set value...

Page 130: ...cted Object under margin heading Assignment of Further 1 phase Measuring Locations The conclusion is If the starpoint of a side of the protected power transformer is earthed and the starpoint current is fed to the device via a further 1 phase current input you can nevertheless leave the default setting for inclusion of the earth current unchanged in address 1211DIFFw IE1 MEAS for side 1 on Yes Thi...

Page 131: ...The pickup value is referred to the rated current of the respective side With setting 0 00 I InS pre setting this release criterion will not be used If the feeder current guard is set i e to a value of 0 the differential protection will not trip before the release criterion is given This is also the case if in conjunction with very high differential currents the extremely fast instantaneous value ...

Page 132: ...e of high currents which may lead to current transformer saturation Its base point is set at address 1244 BASE POINT 2 and is referred to the rated object current The slope is set at address 1243 SLOPE 2 The restraint during current transformer saturation can be influenced by this parameter branch A higher gradient results in a higher restraint This parameter can only be set with DIGSI at Addition...

Page 133: ...i e it is twice the tra versing current The additional stabilisation does not influence the stage I DIFF The maximum duration of the add on restraint after detection of an external fault is set to multiples of an AC cycle address 1262 T ADD ON STAB This parameter can only be set with DIGSI at Additional Settings The add on restraint is disabled auto matically even before the set time period expire...

Page 134: ...th harmonic is more commonly used Converter transformers also produce odd harmonics which are practically absent in the case of an internal short circuit The harmonic content intended for blocking the differential protection is set at address 1276 n HARMONIC For example if the 5th harmonic restraint is used to avoid trip during overexcitation 30 default setting are convenient Harmonic restraint wi...

Page 135: ...S NO Diff Prot with meas Earth Current S5 1216A DIFFw IE3phMEAS NO YES NO Diff Prot with meas current earth electr 1221 I DIFF 0 05 2 00 I InO 0 20 I InO Pickup Value of Differential Curr 1226A T I DIFF 0 00 60 00 sec 0 00 sec T I DIFF Time Delay 1231 I DIFF 0 5 35 0 I InO 7 5 I InO Pickup Value of High Set Trip 1236A T I DIFF 0 00 60 00 sec 0 00 sec T I DIFF Time Delay 1241A SLOPE 1 0 10 0 50 0 2...

Page 136: ...47 Diff n Harm L1 OUT Diff Blocked by n Harmon L1 5648 Diff n Harm L2 OUT Diff Blocked by n Harmon L2 5649 Diff n Harm L3 OUT Diff Blocked by n Harmon L3 5651 Diff Bl exF L1 OUT Diff prot Blocked by ext fault L1 5652 Diff Bl exF L2 OUT Diff prot Blocked by ext fault L2 5653 Diff Bl exF L3 OUT Diff prot Blocked by ext fault L3 5657 DiffCrosBlk 2HM OUT Diff Crossblock by 2 Harmonic 5658 DiffCrosBlk ...

Page 137: ... I5 VI Diff prot Adaption factor CT I5 5726 Diff CT I6 VI Diff prot Adaption factor CT I6 5727 Diff CT I7 VI Diff prot Adaption factor CT I7 5728 Diff CT I8 VI Diff prot Adaption factor CT I8 5729 Diff CT I9 VI Diff prot Adaption factor CT I9 5730 DiffCT I10 VI Diff prot Adaption factor CT I10 5731 DiffCT I11 VI Diff prot Adaption factor CT I11 5732 DiffCT I12 VI Diff prot Adaption factor CT I12 5...

Page 138: ...e starpoint connection i e between the starpoint and the earth ing electrode The starpoint CT and the phase CTs define the limits of the protected zone exactly Restricted earth fault protection is not applicable to busbars 7UT613 63x provides a second earth fault differential protection The following func tion description refers to the 1st instance address 13xx The 2nd instance is set via addresse...

Page 139: ...00 G1176 C160 2 Figure 2 52 Restricted earth fault protection on a non earthed transformer winding with neutral reactor starpoint former within the protected zone Figure 2 53 Restricted earth fault protection on an earthed shunt reactor with CTs in the reactor leads ...

Page 140: ...x Manual C53000 G1176 C160 2 Figure 2 54 Restricted earth fault protection on an earthed shunt reactor with 2 CT sets treated like an auto transformer Figure 2 55 Restricted earth fault protection on an earthed auto transformer ...

Page 141: ...can for example implement an earth fault differential protection for both of the windings at a YNyn transformer that is earthed at both starpoints Or use the first earth fault differential protection for an earthed transformer winding and the second for a further protective object e g a neutral reactor Allocation of both earth fault differential protection functions to the sides or measuring locat...

Page 142: ...on of the phase current transformers under strong through current conditions This current could simulate a fault in the protected zone Measures must be taken to prevent this current from causing a trip For this the re stricted earth fault protection provides stabilisation methods which differ strongly from the usual stabilisation methods of differential protection schemes since it uses besides the...

Page 143: ...ary side in counter phase with the starpoint current and has equal magnitude The maximum information of the currents is evaluated for restraint the magnitude of the currents and their phase posi tion The following is defined a tripping effect current Ifrom 3I0 and the stabilisation or restraining current Istab k 3I0 3I0 3I0 3I0 k is a stabilisation factor which will be explained below at first we ...

Page 144: ...o 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 small earth current can cause tripping In con trast strong restraint becomes effective for external earth faults Figure 2 60 shows that the restraint is the strongest when the residual current from the phase cu...

Page 145: ...mparison Figure 2 61 Phasor diagram of the restraint quantity during external fault The restraint quantity can be influenced by means of 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 7UT613 63x k is equal to 4 The restraint quantit...

Page 146: ... re straint characteristic can be set Pickup Normally a differential protection does not need a pickup since the condition for a fault detection is identical to the trip condition As with all protective functions the earth fault differential protection has a pickup that displays a precondition for tripping and defines the fault inception instant for a number or further activities As soon as the fu...

Page 147: ...l scope section 2 1 4 under address 113 REF PROT to Enabled If the second restricted earth fault protection is used it also needs to be set at address 114REF PROT 2Enabled Furthermore a further 1 phase measured current input must be assigned to the same side or measuring location where the starpoint current is to be processed see section 2 1 4 margin heading As signment of Auxiliary 1 phase Measur...

Page 148: ... current magnitudes which is set at ad dress1313 SLOPE This parameter can only be set with DIGSI at Additional Settings The preset value 0 is normally adequate In special cases it may be advantageous to delay the trip signal of the protection This can be done by setting an additional delay time address 1312 T I REF This pa rameter can only be set with DIGSI at Additional Settings This additional t...

Page 149: ...ched OFF 199 2412 REF BLOCKED OUT Restricted earth fault is BLOCKED 199 2413 REF ACTIVE OUT Restricted earth fault is ACTIVE 199 2421 REF picked up OUT Restr earth flt picked up 199 2451 REF TRIP OUT Restr earth flt TRIP 199 2491 REF Not avail OUT REF err Not available for this object 199 2492 REF Err CTstar OUT REF err No starpoint CT 199 2494 REF Adap fact OUT REF err adverse Adaption factor CT ...

Page 150: ...ts where each can be used independent of each other at different locations They can e g be implemented independently on various sides of the main protection object or three phase measuring locations Assigning the different protective functions to the sides or one phase measuring locations are according to Section Assigning the pro tective functions to the measuring locations sides is performed The...

Page 151: ...for Phase and Residual Currents 151 7UT613 63x Manual C53000 G1176 C160 2 Figures 2 65 and 2 66 show the logic diagrams for the high set stages I and 3I0 Figure 2 65 Logic diagram of the high set stages I for phase currents simplified ...

Page 152: ...mes T I or T 3I0 have elapsed a trip signal is issued assuming that no inrush current is detected or inrush restraint is disabled If inrush restraint is enabled and inrush current is detected there will be no tripping Nevertheless an annunciation is gener ated indicating that the time expired Tripping signals and signals on the expiration of time delay are available separately for each stage The r...

Page 153: ...2 4 Time Overcurrent Protection for Phase and Residual Currents 153 7UT613 63x Manual C53000 G1176 C160 2 Figure 2 67 Logic diagram of the overcurrent stage I for phase currents simplified ...

Page 154: ...e Technical Data When configuring one of the inverse time characteristics definite time stages I and I are also enabled Pickup Tripping Each phase current and the zero sequence current sum of phase currents are com pared individually to a common setting value Ip or 3I0p If a current exceeds the setting value by 1 1 times the corresponding stage picks up and is signalled selective ly If inrush rest...

Page 155: ...ere will be no tripping Neverthe less an annunciation is generated indicating that the time expired For the zero sequence current 3I0p the characteristic can be selected independently of the characteristic used for the phase currents The pickup values of the stages Ip phases and 3I0p zero sequence current and the time multipliers valid for each of these states can be set individually Figures 2 69 ...

Page 156: ...2 Functions 156 7UT613 63x Manual C53000 G1176 C160 2 Figure 2 69 Logic diagram of the inverse overcurrent protection for phase currents example of IEC characteristic simplified ...

Page 157: ...nting which begins after de energization and this process corresponds to the reset rotation of a Ferraris disk explaining its denomination disk emulation In case several faults occur successively it is ensured that due to the inertia of the Ferraris disk the history is taken into consideration and the time behaviour is adapted Reset begins as soon as 90 of the setting value is undershot in accorda...

Page 158: ...ch delay when the circuit breaker is closed manually Figure 2 71 Manual close processing simplified Processing of the manual close command can be executed for each measuring loca tion or side Manual close signal is also generated when an internal control command is given to a breaker which is assigned to the same protection function as the time overcurrent protection in the Power System Data 1 Sub...

Page 159: ...stages not I for phase and residual cur rents in cash of inrush detection After detection of inrush currents above a pickup value special inrush signals are generated These signals also initiate fault annuncia tions and start the assigned trip delay time If inrush current is still detected after expi ration of the delay time an annunciation is output only reporting that time elapsed but tripping i...

Page 160: ...ether the binary input operates in the normally open i e energise input to block or the normally closed i e energise input to release mode Thus the overcurrent time protection can be used as fast busbar protection in star connected networks or in open ring networks ring open at one location using the re verse interlock principle This is used in high voltage systems in power station auxil iary supp...

Page 161: ...ection 2 4 1 The following paragraphs contain the specific information for setting the overcurrent protection for phase currents Phase O C 2 4 2 1 Setting Notes General Note The first overcurrent protection for phase currents is described in the setting instruc tions The parameter addresses and message numbers of the second and third over current protection are described at the end of the setting ...

Page 162: ...sly with a detected manual close Settings I instant and I instant can be set independently from the selected type characteristics Ip instant is only available if one of the inverse time stages is configured This setting can only be made with DIGSI under Additional Settings If time overcurrent protection is applied on the feeding side of a trans former select the higher stage I which does not pick ...

Page 163: ...ted current of the side is cancelled Thus the formula gives With the same safety factor results Setting value I 0 8 IINS rated current of the side Increased inrush currents if their fundamental oscillation exceeds the setting value are rendered harmless by delay times address 2013T I The inrush restraint does not apply to the stages I Using the principle of the Reverse Interlocking the multi stage...

Page 164: ...up indication or a trip will be triggered Overcurrent Stage sIp with IEC charac teristics The inverse time stages depending on the configuration Functional Scope address 120 see section 2 1 3 1 enables the user to select different characteristics With the IEC characteristics address 120 DMT IDMT Phase TOC IEC the follow ing options are available at address 2026 IEC CURVE Normal Inverse inverse typ...

Page 165: ... value and the setting value This means that a pickup will only occur if a current of about 1 1 times of the setting value is present The current value is set under address 2021 Ip or 2022 Ip The maximum operating current is of primary importance for the setting Pickup due to overload should never occur since the device in this modem operates as fault protection with correspond ingly short trippin...

Page 166: ...r may define his own tripping and dropout characteristic For configuration in DIGSI a dialogue box appears Enter up to 20 pairs of current value and tripping time value The characteristics can also be viewed in DIGSI as an illustration Figure 2 75 Entry and visualisation of a user specific trip characteristic with DIGSI example In order to be able to create a user defined tripping characteristic t...

Page 167: ...d add the corresponding time values Deviating values I Ip are rounded to the next adjacent value This however will not be indicated Currents smaller than the current value of the smallest characteristic point do not lead to a prolongation of the tripping time The pickup characteristic see Figure 2 76 right side goes parallel to the current axis up to the smallest characteristic point Currents grea...

Page 168: ... in the inrush current The ratio of 2nd harmonics to the fundamental component 2 HARM Phase address 2041 is set to I2fN IfN 15 as default setting It can be used without being changed To provide more restraint in exceptional cases where ener gising conditions are particularly unfavourable a smaller value can be set in the afore mentioned address If the current exceeds the value indicated in address...

Page 169: ...ers Addresses of the dynamic parameters Message no 1 Overcurrent protection for phase currents 20xx 21xx 023 xxxx 01 2 Overcurrent protection for phase currents 30xx 31xx 207 xxxx 01 3 Overcurrent protection for phase currents 32xx 33xx 209 xxxx 01 Addr Parameter C Setting Options Default Setting Comments 2001 PHASE O C ON OFF Block relay OFF Phase Time Overcurrent 2002 InRushRest Ph ON OFF OFF In...

Page 170: ... TIp 2032 MofPU Res T Tp 0 05 0 95 I Ip 0 01 999 00 TD Multiple of Pickup TI TIp 2041 2 HARM Phase 10 45 15 2nd harmonic O C Ph in of fundamental 2042 I Max InRr Ph 1 A 0 30 25 00 A 7 50 A Maximum Current for Inr Rest O C Phase 5 A 1 50 125 00 A 37 50 A 2043 I Max InRr Ph 0 30 25 00 I InS 7 50 I InS Maximum Current for Inr Rest O C Phase 2044 CROSS BLK Phase NO YES NO CROSS BLOCK O C Phase 2045 T ...

Page 171: ...023 2501 BLK Ph O C Inr SP BLOCK time overcurrent Phase InRush 023 2502 BLOCK I SP BLOCK I 023 2503 BLOCK I SP BLOCK I 023 2504 BLOCK Ip SP BLOCK Ip 023 2514 I BLOCKED OUT I BLOCKED 023 2515 I BLOCKED OUT I BLOCKED 023 2516 Ip BLOCKED OUT Ip BLOCKED 023 2521 I picked up OUT I picked up 023 2522 I picked up OUT I picked up 023 2523 Ip picked up OUT Ip picked up 023 2524 I InRush PU OUT I InRush pic...

Page 172: ... 3I0 2 and 136 DMT IDMT 3I0 3 Each protection function must be assigned to a side of the main protected object or another 3 phase current measuring location This can be carried out separately from the phase overcurrent protection section 2 1 4 under margin heading Additional Three phase Protection Functions Consider also the assignment of the measured current inputs of the device against the measu...

Page 173: ...fast busbar protection with a short safety delay T 3I0 e g 50 ms Stage 3I0 is blocked for faults at the outgoing feeders Stages 3I0 or 3I0p serve as backup protection The pickup values of both elements 3I0 or 3I0p and 3I0 are set equal Delay time T 3I0 or T 3I0p IEC characteristic or D 3I0p ANSI characteristic is set in such manner that it overgrades the delay for the outgoing feeders Here the gra...

Page 174: ...inated with the grading coordination chart of the network For earth cur rents with earthed network you can mostly set up a separate grading coordination chart with shorter delay times If you set a very small pickup value consider that the inrush restraint function cannot operate below 10 nominal current lower limit of har monic filtering An adequate time delay could be reasonable if inrush restrai...

Page 175: ...scribed in section Dropout Be haviour Dynamic Cold Load Pickup An alternative set of pickup values can be set for each stage It may be selected au tomatically in a dynamic manner during operation The following alternative values are set for the stages here section 2 6 for definite time overcurrent protection 3I0 address 2311 or 2312 for pickup value 3I0 address 2313 for delay time T 3I0 address 23...

Page 176: ...er addresses and message numbers of the first second and third time overcurrent protection are illus trated in the following table The positions marked by x are identical Note If the time overcurrent protection is assigned to a side of the main protected object the current values are set referred to the rated current of that side II INS 2 4 3 2 Settings Addresses which have an appended A can only ...

Page 177: ...remely Inv Long Inverse Normal Inverse IEC Curve 2227 ANSI CURVE Very Inverse Inverse Short Inverse Long Inverse Moderately Inv Extremely Inv Definite Inv Very Inverse ANSI Curve 2231 I I0p PU T TI0p 1 00 20 00 I Ip 0 01 999 00 TD Pickup Curve 3I0 3I0p T3I0 T3I0p 2232 MofPU ResT TI0p 0 05 0 95 I Ip 0 01 999 00 TD Multiple of Pickup T3I0 T3I0p 2241 2 HARM 3I0 10 45 15 2nd harmonic O C 3I0 in of fun...

Page 178: ... object 191 2501 BLK 3I0O C Inr SP BLOCK time overcurrent 3I0 InRush 191 2502 BLOCK 3I0 SP BLOCK 3I0 time overcurrent 191 2503 BLOCK 3I0 SP BLOCK 3I0 time overcurrent 191 2504 BLOCK 3I0p SP BLOCK 3I0p time overcurrent 191 2514 3I0 BLOCKED OUT 3I0 BLOCKED 191 2515 3I0 BLOCKED OUT 3I0 BLOCKED 191 2516 3I0p BLOCKED OUT 3I0p BLOCKED 191 2521 3I0 picked up OUT 3I0 picked up 191 2522 3I0 picked up OUT 3...

Page 179: ...otection for earth faults outside the protected zone which are not cleared there The time overcurrent protection for earth current provides two definite time stages O and one inverse time stage C The latter may operate according to an IEC or an ANSI or a user defined characteristic Figure 2 77 Time overcurrent protection as backup protection for restricted earth fault pro tection 7UT613 63x is pro...

Page 180: ...or earth current simplified The current detected at the assigned one phase current measuring input is addition ally compared with setting value IE An annunciation is generated if the value is ex ceeded If inrush restraint is used a frequency analysis is performed first If an inrush condition is detected pickup annunciation is suppressed and an inrush message is output instead If there is no inrush...

Page 181: ... the set value the stage picks up and an annunciation is made If inrush restraint is used a frequency analysis is performed first If an inrush condition is detected pickup annunciation is suppressed and an inrush message is output instead The RMS value of the fundamental is used for the pickup During the pickup of an IEp stage the tripping time is calculated from the flowing fault current by means...

Page 182: ...sk explaining its denomination disk emulation In case several faults occur suc cessively it is ensured that due to the inertia of the Ferraris disk the history is taken into consideration and the time behaviour is adapted Reset begins as soon as 90 of the setting value is undershot in accordance with the dropout curve of the selected characteristic In the range between the dropout value 95 of the ...

Page 183: ...e executed for each measuring loca tion or side Manual close signal is also generated when an internal control command is given to a breaker which is assigned to the same protection function as the time earth overcurrent protection in the Power System Data 1 subsection 2 1 4 Strict attention must be paid that the manual close condition is derived from that circuit breaker which feeds the object th...

Page 184: ... Earth2 and must be configured accordingly The overcurrent protection for earth current is assigned to a 1 phase current measur ing input section 2 1 4 under margin heading Additional 1 phase Protection Func tions Consider also the assignment of the 1 phase current input of the device against the current transformer of the power plant section 2 1 4 under margin heading Assignment of Auxiliary 1 ph...

Page 185: ...urrents Since the starpoint current originates from one single current transformer it is not affected by summation effects evoked by different current transformer errors like for example the zero sequence current derived from phase currents Therefore this address can be set to very sensitive Consider that the inrush restraint function cannot operate below 10 nominal current lower limit of harmonic...

Page 186: ...IEp stage is not required select address 124 DMT IDMT Earth Definite Time when configuring the protection functions If under address 2424 TOC DROP OUT the Disk Emulation are set dropout is pro duced in accordance with the dropout characteristic as set out in the functional de scription of the inverse time overcurrent protection under margin heading Dropout Be haviour Overcurrent Stage IEp with ANS...

Page 187: ... time overcurrent protection IE acc to IEC characteristics address 2521 for pickup value IEp address 2522 for time multiplier T IEp for inverse time overcurrent protection IE acc to ANSI characteristics address 2521 for pickup value IEp address 2523 for time multiplier D IEp User Defined Curves For inverse time overcurrent protection the user may define his own tripping and dropout characteristic ...

Page 188: ...es of the dynamic parameters Message no 1 Overcurrent protection for earth current 24xx 25xx 024 xxxx 01 2 Overcurrent protection for earth current 38xx 39xx 325 xxxx 01 Addr Parameter C Setting Options Default Setting Comments 2401 EARTH O C ON OFF Block relay OFF Earth Time Overcurrent 2402 InRushRestEarth ON OFF OFF InRush Restrained O C Earth 2408A IE MAN CLOSE IE instant IE instant IEp instan...

Page 189: ...E 0 00 60 00 sec 2 00 sec T IE Time Delay 2521 IEp 1A 0 05 4 00 A 1 00 A IEp Pickup 5A 0 25 20 00 A 5 00 A 2522 T IEp 0 05 3 20 sec 0 50 sec T IEp Time Dial 2523 D IEp 0 50 15 00 5 00 D IEp Time Dial No Information Type of In formation Comments 024 2404 BLK Earth O C SP BLOCK Earth time overcurrent 024 2411 O C Earth OFF OUT Time Overcurrent Earth is OFF 024 2412 O C Earth BLK OUT Time Overcurrent...

Page 190: ... InRush picked up 024 2525 IEp InRush PU OUT IEp InRush picked up 024 2529 Earth InRush PU OUT Earth InRush picked up 024 2541 IE Time Out OUT IE Time Out 024 2542 IE Time Out OUT IE Time Out 024 2543 IEp TimeOut OUT IEp Time Out 024 2551 IE TRIP OUT IE TRIP 024 2552 IE TRIP OUT IE TRIP 024 2553 IEp TRIP OUT IEp TRIP No Information Type of In formation Comments ...

Page 191: ...se criteria for the time overcurrent protection for phase cur rents and for that for residual current The device assigns automatically the correct side or measuring location for current detection or the breaker auxiliary contact in ac cordance with the assignment of the associated protection functions The time over current protection for earth current allows the breaker criterion only if it is ass...

Page 192: ...ion is blocked via the binary input all triggered timers will be immediately reset and all normal settings will be restored If blocking occurs during an on going fault with dynamic cold load pickup functions enabled the timers of all overcurrent stages will be stopped and then restarted based on their nor mal duration Figure 2 82 Cold Load Pickup Timing Sequence During power up of the protective r...

Page 193: ...abled is to be set In address 1701 COLDLOAD PICKUP the function can be set to ON or OFF Cold Load Criteria You can determine the criteria for dynamic switchover to the cold load pickup values for all protective functions which allow this switchover Select the current criterion or the breaker position criterion breaker position address 1702 Start CLP Phasefor the phase current stages address 1703 S...

Page 194: ...nt stages are set in the related addresses of the stages themselves 2 6 3 Settings Addr Parameter Setting Options Default Setting Comments 1701 COLDLOAD PICKUP OFF ON OFF Cold Load Pickup Function 1702 Start CLP Phase No Current Breaker Contact No Current Start Condition CLP for O C Phase 1703 Start CLP 3I0 No Current Breaker Contact No Current Start Condition CLP for O C 3I0 1704 Start CLP Earth ...

Page 195: ... switched OFF 049 2412 CLP BLOCKED OUT Cold Load Pickup is BLOCKED 049 2413 CLP running OUT Cold Load Pickup is RUNNING 049 2505 BLK CLP stpTim SP BLOCK Cold Load Pickup stop timer 192 2413 3I0 Dyn set ACT OUT Dynamic settings O C 3I0 are ACTIVE 208 2413 I 2 Dyn set ACT OUT Dynamic settings O C Phase 2 are ACTIVE 210 2413 I 3 Dyn set ACT OUT Dynamic settings O C Phase 3 are ACTIVE 322 2413 3I0 2 D...

Page 196: ...alue 1Phase I Current above the pickup value is de tected and annunciated When the delay time T I has expired tripping command is issued The reset value is approximately 95 of the pickup value for currents above IN For lower values the dropout ratio is reduced in order to avoid intermittent pickup on currents near the setting value e g 90 at 0 2 IN When high fault current occurs the current filter...

Page 197: ...7UT613 63x Manual C53000 G1176 C160 2 Figure 2 84 Two stage tripping characteristic of the single phase time overcurrent protec tion Figure 2 85 Logic diagram of the single phase overcurrent protection example for detection of the current at input II8 ...

Page 198: ...g or an earthed motor generator The example on the right side shows a non earthed transformer winding or an non earthed motor generator where the earthing of the system is assumed to be somewhere else Figure 2 86 Earth fault protection according to the high impedance principle High impedance Principle The high impedance principle is explained on the basis of an earthed transformer winding No zero ...

Page 199: ...mensioned such that even with the very lowest earth fault current to be detected it generates a secondary voltage which is equal to half the saturation voltage of current transformers see also notes on Dimensioning in subsection 2 7 4 High Impedance Protection with 7UT613 63x With 7UT613 63x a high sensitivity single phase measuring input is used for high im pedance protection As this is a current...

Page 200: ...transformer The tank must be isolated from earth A conductor links the tank to earth and the current through this conductor is fed to a current input of the relay When a tank leakage occurs a fault current tank leakage current will flow through the earthing conductor to earth This tank leakage current is detected by the single phase overcurrent protection as an overcurrent an instantaneous or dela...

Page 201: ...ption for the use as high impedance protection and tank leakage pro tection is set out below Use as High Imped ance Differential Protection When used as high impedance protection only the pickup value of the single phase overcurrent protection is set on the 7UT613 63x to detect overcurrent at the assigned highly sensitive 1 phase current input However the entire function of the high impedance unit...

Page 202: ...The other ones will continue transmitting their partial currents In theory this is the most unfavour able case Since in practice it is also the saturated transformer which supplies cur rent a safety margin is automatically guaranteed Figure 2 90 illustrates a simplified equivalent circuit CT1 and CT2 are assumed as ideal transformers with their inner resistance Ri1 and Ri2 Ra is the resistance of ...

Page 203: ...m2 cross section results in Ra 0 75 Ω that is 27 rated current or 21 6 kA primary Sensitivity Consid erations for High Impedance Protection As before mentioned high impedance protection is to pick up with approximately half the knee point voltage of the current transformers Resistance R can be calculated from it Since the device measures the current flowing through the resistor resistor and mea su...

Page 204: ... number of current transformers is connected in parallel e g when using as busbar protection with several feeders the magnetising currents of the transformers connected in parallel cannot be neglected anymore In this case the sum total of the magnetising currents at half knee point voltage corresponding to the setting value has to be established These magnetising currents reduce the current throug...

Page 205: ... 0 100 A 1Phase O C I Pickup 2707 T 1Phase I 0 00 60 00 sec 0 50 sec T 1Phase O C I Time Delay No Information Type of In formation Comments 200 2404 BLK 1Ph O C SP BLOCK Time Overcurrent 1Phase 200 2411 O C 1Ph OFF OUT Time Overcurrent 1Phase is OFF 200 2412 O C 1Ph BLK OUT Time Overcurrent 1Phase is BLOCKED 200 2413 O C 1Ph ACT OUT Time Overcurrent 1Phase is ACTIVE 200 2421 O C 1Ph PU OUT Time Ov...

Page 206: ...me tries lead to negative sequence currents The negative sequence protection always refers to the three phase currents of the configured side or measuring location see Assigning the Functional Scope in Sub section 2 1 4 The unbalanced load protection consists of two definite time stages and one inverse time stage The latter may operate according to an IEC or an ANSI characteristic A stage with a p...

Page 207: ...al Data The definite time elements I2 and I2 are superim posed on the inverse time curve Pickup Trip The negative sequence current I2 is compared to the set value I2p When the nega tive sequence current exceeds 1 1 times the setting value a pickup annunciation is generated The tripping time is calculated from the negative sequence current accord ing to the characteristic selected After expiration ...

Page 208: ...rature rise of the protected object even for extremely fluctuating unbal anced load values Reset begins as soon as 90 of the setting value is undershot in accordance with the dropout curve of the selected characteristic In the range between the dropout value 95 of the pickup value and 90 of the setting value the incre menting and the decrementing process is in idle state If 5 of the setting value ...

Page 209: ...balanced load protection can be well adapted to the thermal loading of the electrical motor rotor during asymmetric load Pickup Warning The permissible continuous load imbalance is determined with the setting I2 Permis sible If this value is exceeded it applies as Pickup for the negative sequence pro tection At the same time this sets the alarm stage After a set time T WARN has ex pired a warning ...

Page 210: ...p Out The pickup of the unbalanced load protection falls back when the allowable unbal anced load I2 adm is undershot The thermal image maintains its state and an ad justable cool down time T COOL DOWN is started In this context this cool down time is defined as the time required by the thermal replica to cool down from 100 to 0 In synchronous machines this depends on the construction especially t...

Page 211: ... is available in this operating mode but is generally not required because an own warning level is available The protection may be blocked via a binary input That way pickups and time stages are reset The content of the thermal replica can be emptied via the binary input SLS RES th repl and ULP Block When leaving the work area of the negative sequence protection all phase currents under the minimu...

Page 212: ...ion only makes sense with three phase protected objects For PROT OBJECT 1ph Busbar or 1 phase transf address 105 the following settings are not available The characteristic type has been determined during configuration of the functional scope under address 140 UNBALANCE LOAD see section 2 1 3 1 Only the settings for the characteristic selected can be performed here The inverse time curves I2 and I...

Page 213: ...ge In most cases stage I2 is set in such manner that it does not pick up in case of phase failure Setting I2 to a percentage higher than 60 ensures that no tripping is performed with stage I2 in case of phase failure If power supply with current I is provided via just two phases the following applies for the inverse current On the other hand with more than 60 negative sequence current a two phase ...

Page 214: ...ing faults may be detected at the low side If the pickup setting of the device on the high side is set to I2 0 1 A then a phase to earth fault current of for single phase for two pole faults can be detected This corresponds to 36 and 20 of the trans former nominal current respectively To prevent false operation for faults in other zones of protection the delay time T I2 must be coordinated with th...

Page 215: ...iplier is accessible via address 4023 T I2p The time multiplication factor may also be set to If set to infinity the pickup of this function will be indicated but the stage will not trip after pickup If the inverse time stage is not required select 140 UNBALANCE LOAD in address Definite Time when configuring the protection functions If under address 4025 I2p DROP OUT the Disk Emulationis set dropo...

Page 216: ...salient pole rotors this typically amounts to a value in a range from 6 to 8 of the nominal machine current and with salient pole rotors at least 12 For larger machines and in cases of doubt please refer to the instructions of the machine manufacturer Set this value under address 4031 I2 As the relevant measuring location for asymmetrical load is usually assigned to the side of the machine to be p...

Page 217: ... however the asymmetrical load protection must be set in amps secondary during operation also the K factor must be converted as it refers to the machine internal cur rent The following applies Example Machine IN 483 A I2perm 11 salient pole machine K factor 20 s Current transformer 500 A 5 A results in the setting value under address 4034 FACTOR K The setting value 4035 T COOL DOWN is defined as t...

Page 218: ...The current values I INS refer to the rated current of the side to be protected of the main protected object 2 8 3 Settings The table indicates region specific presettings Column C configuration indicates the corresponding secondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 4001 UNBALANCE LOAD OFF ON Block relay OFF UnbalanceLoad Negative ...

Page 219: ...000 sec 1650 sec Time for Cooling Down No Information Type of In formation Comments 5143 BLOCK I2 SP BLOCK I2 Unbalance Load 5146 RM th rep I2 SP Reset memory for thermal replica I2 5151 I2 OFF OUT I2 switched OFF 5152 I2 BLOCKED OUT I2 is BLOCKED 5153 I2 ACTIVE OUT I2 is ACTIVE 5157 I2 th Warn OUT Unbalanced load Thermal warning stage 5158 RM th rep I2 OUT Reset memory of thermal replica I2 5159 ...

Page 220: ...RTD box The third needs some knowledge about the protected object and its thermal charac teristics and the input of the cooling medium temperature 7UT613 63xis equipped with two breaker failure protection functions that can be used independent of each other and for different locations of the protective object One can also work with different starting criteria The assignment of the protective funct...

Page 221: ... winding is decisive The device calculates this rated current from the rated apparent power of the transform er and the rated voltage of the assigned winding For transformers with tap changer the non regulated side must be used For generators motors or reactors the rated object current is calculated by the device from the set rated apparent power and the rated voltage For short lines branchpoints ...

Page 222: ...emergency reasons operating temperature above the maximum permissible operating temperature can be allowed by blocking the tripping signal via a binary input Emer Start O L After startup and dropout of the binary input the thermal replica may still be greater than the trip tem perature rise Therefore the thermal replica features a settable run on time T EMERGENCY which is started when the binary i...

Page 223: ...ad Protection with a thermal Replica To create the relation between current and temperature the device needs the temperature at rated current of the protected object In the event of failure of the temperature input via the thermobox the device works with an accepted temperature of 40 C or 104 F The result shows the same condi tions as with the thermal protection without ambient temperature Section...

Page 224: ...ature drop The hot spot temperature consists of two parts the temperature at the hottest spot of the coolant included via RTD box the temperature rise of the winding turn caused by the transformer load RTD box 7XV5662 xAD can be used to acquire the temperature of the hottest spot It captures the temperature value and transmits these to the respective interface of de vice7UT613 63x The RTD box 7XV5...

Page 225: ...esults The hot spot temperature is calculated for the winding which corresponds to the side of the protected object configured for overload protection Subsection 2 1 4 margin heading Further 3 phase Protection Functions address 442 The calculation in cludes the current of that side and the cooling temperature measured at a certain mea suring point The phase information is taken from the concerned ...

Page 226: ...r to digitally inform the device about the coolant temperature The required data for the RTD box were set under address 191 RTD CONNECTION section 2 1 3 1 Under address 4201 THERM OVERLOAD overload protection ON or OFF can be set If address 142 THERM OVERLOAD has been set to th rep w o sen during con figuration of the functional scope the setting Alarm Only is also possible With that latter settin...

Page 227: ...nt permissible current for application time other than 1 s e g for 0 5 s t6 time this is the time in seconds for which a current of 6 times the rated current of the protected object may flow Calculation examples Cable with permissible continuous current 322 A permissible 1 s current 13 5 kA Setting value TIME CONSTANT 29 4 min Motor with t6 time 12 s Setting value TIME CONSTANT 7 2 min For rotatin...

Page 228: ...ermal warning stage should be set above temperature rise at nominal current 82 6 A sensible setting value would be Θ ALARM 90 The current overload alarm setpoint I ALARM address 4205 is referred to the rated current of the side and should be set equal to or slightly below the permissible contin uous current k IN Obj It can also be used instead of the thermal alarm stage In this case the thermal al...

Page 229: ...e ageing i e L 1 is reached at 98 C or 208 F at the hot spot L 1 refers to an accelerated ageing L 1 to delayed ageing Cooling Method and Insulation Data Set in address 4231 METH COOLING which cooling method is used ON Oil Natural for natural cooling OF Oil Forced for oil forced cooling or OD Oil Directed for oil di rected cooling The definitions under margin heading Cooling Methods in the func ti...

Page 230: ...SENSOR RTD 1 6 1 Temperature sensor connected to RTD 4211 TEMPSENSOR RTD 1 12 1 Temperature sensor connected to RTD 4212 TEMP RISE I 40 200 C 100 C Temperature Rise at Rated Sec Curr 4213 TEMP RISE I 104 392 F 212 F Temperature Rise at Rated Sec Curr 4220 OIL DET RTD 1 6 1 Oil Detector conected at RTD 4221 OIL Sensor RTD 1 12 1 Oil sensor connected to RTD 4222 HOT SPOT ST 1 98 140 C 98 C Hot Spot ...

Page 231: ...ThOverload TRIP OUT Thermal Overload TRIP 044 2491 O L Not avail OUT Th Overload Not available for this obj 044 2494 O L Adap fact OUT Th Overload err adverse Adap factor CT 044 2601 Emer Start O L SP Emergency start Th Overload Protection 044 2602 O L I Alarm OUT Th Overload Current Alarm I alarm 044 2603 O L Θ Alarm OUT Thermal Overload Alarm 044 2604 O L ht spot Al OUT Thermal Overload hot spot...

Page 232: ...acteristic data as well as alarm stage 1 and trip stage 2 can be set The RTD box also acquires thresholds of each single measuring point The informa tion is then passed on via an output relay For further information refer to the instruc tion manual of the RTD box 2 10 2 Setting Notes General Set the type of temperature detector for RTD 1 temperature sensor for measuring point 1 at address 9011 RTD...

Page 233: ... 120 C RTD 1 Temperature Stage 2 Pickup 9016 RTD 1 STAGE 2 58 482 F 248 F RTD 1 Temperature Stage 2 Pickup 9021A RTD 2 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 2 Type 9022A RTD 2 LOCATION Oil Ambient Winding Bearing Other Other RTD 2 Location 9023 RTD 2 STAGE 1 50 250 C 100 C RTD 2 Temperature Stage 1 Pickup 9024 RTD 2 STAGE 1 58 482 F 212 F RTD 2 Temperature Stage 1 Pickup ...

Page 234: ...AGE 2 50 250 C 120 C RTD 4 Temperature Stage 2 Pickup 9046 RTD 4 STAGE 2 58 482 F 248 F RTD 4 Temperature Stage 2 Pickup 9051A RTD 5 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 5 Type 9052A RTD 5 LOCATION Oil Ambient Winding Bearing Other Other RTD 5 Location 9053 RTD 5 STAGE 1 50 250 C 100 C RTD 5 Temperature Stage 1 Pickup 9054 RTD 5 STAGE 1 58 482 F 212 F RTD 5 Temperature S...

Page 235: ...ckup 9074 RTD 7 STAGE 1 58 482 F 212 F RTD 7 Temperature Stage 1 Pickup 9075 RTD 7 STAGE 2 50 250 C 120 C RTD 7 Temperature Stage 2 Pickup 9076 RTD 7 STAGE 2 58 482 F 248 F RTD 7 Temperature Stage 2 Pickup 9081A RTD 8 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 8 Type 9082A RTD 8 LOCATION Oil Ambient Winding Bearing Other Other RTD 8 Location 9083 RTD 8 STAGE 1 50 250 C 100 C R...

Page 236: ...ion 9103 RTD10 STAGE 1 50 250 C 100 C RTD10 Temperature Stage 1 Pickup 9104 RTD10 STAGE 1 58 482 F 212 F RTD10 Temperature Stage 1 Pickup 9105 RTD10 STAGE 2 50 250 C 120 C RTD10 Temperature Stage 2 Pickup 9106 RTD10 STAGE 2 58 482 F 248 F RTD10 Temperature Stage 2 Pickup 9111A RTD11 TYPE Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD11 Type 9112A RTD11 LOCATION Oil Ambient Winding Bear...

Page 237: ...p 14123 RTD 2 St 2 p up OUT RTD 2 Temperature stage 2 picked up 14131 Fail RTD 3 OUT Fail RTD 3 broken wire shorted 14132 RTD 3 St 1 p up OUT RTD 3 Temperature stage 1 picked up 14133 RTD 3 St 2 p up OUT RTD 3 Temperature stage 2 picked up 14141 Fail RTD 4 OUT Fail RTD 4 broken wire shorted 14142 RTD 4 St 1 p up OUT RTD 4 Temperature stage 1 picked up 14143 RTD 4 St 2 p up OUT RTD 4 Temperature st...

Page 238: ...wire shorted 14202 RTD10 St 1 p up OUT RTD10 Temperature stage 1 picked up 14203 RTD10 St 2 p up OUT RTD10 Temperature stage 2 picked up 14211 Fail RTD11 OUT Fail RTD11 broken wire shorted 14212 RTD11 St 1 p up OUT RTD11 Temperature stage 1 picked up 14213 RTD11 St 2 p up OUT RTD11 Temperature stage 2 picked up 14221 Fail RTD12 OUT Fail RTD12 broken wire shorted 14222 RTD12 St 1 p up OUT RTD12 Tem...

Page 239: ...s no sense on 1 phase busbar protection and is therefore not available for this application The overexcitation protection measures the ration voltage frequency U f which is pro portional to the induction B in the iron core with invariable dimensions If the quotient UU f is set in relation to the voltage and frequency under nominal con ditions of the protected object UNObj fN a direct measure of th...

Page 240: ...ed as soon as the value falls below the pickup threshold and the counter is decremented according to the set cooldown rate The thermal characteristic is specified by 8 value pairs concerning the U f value re ferred to nominal value and the associated trip time T In most cases the default char acteristic for standard transformers provides for sufficient protection If this character istic does not c...

Page 241: ... object to be protected This setting determines the pickup of the warning stage as well as the minimum value for the thermal stage see below After the time 4303 address T U f has expired approx 10 s alarm is output Strong overexcitation endangers the protected object after short time The high set stage 4304 address U f should therefore be only shortly delayed approx 1 s by the time 4305 addressT U...

Page 242: ...his corresponds to a standard Siemens transformer figure 2 100 Figure 2 101 Tripping time characteristic of the overexcitation protection Otherwise any tripping characteristic can be specified by point wise entering the delay times for the 8 predefined U f values Address 4306 t U f 1 05 Address 4307 t U f 1 10 Address 4308 t U f 1 15 Address 4309 t U f 1 20 ...

Page 243: ...duction of the pro tected object under nominal conditions i e UNObj fN 2 11 3 Settings Address 4310 t U f 1 25 Address 4311 t U f 1 30 Address 4312 t U f 1 35 Address 4313 t U f 1 40 Addr Parameter Setting Options Default Setting Comments 4301 OVEREXC PROT OFF ON Block relay OFF Overexcitation Protection U f 4302 U f 1 00 1 20 1 10 U f Pickup 4303 T U f 0 00 60 00 sec 10 00 sec T U f Time Delay 43...

Page 244: ... Overexcitation protection is BLOCKED 5363 U f ACTIVE OUT Overexcitation protection is ACTIVE 5367 U f warn OUT Overexc prot U f warning stage 5369 RM th rep U f OUT Reset memory of thermal replica U f 5370 U f picked up OUT Overexc prot U f picked up 5371 U f TRIP OUT Overexc prot TRIP of U f stage 5372 U f th TRIP OUT Overexc prot TRIP of th stage 5373 U f pick up OUT Overexc prot U f picked up ...

Page 245: ...s as in this case a very low active power is calculated from a very high apparent power for small cos ϕ The positive sequence systems from voltag es and currents are used to obtain a very high accuracy of the last 16 cycles The evaluation of the positive phase sequence systems makes the reverse power de termination independent of current and voltage asymmetries and corresponds to actual loading of...

Page 246: ...ferent trip delays Figure 2 102 Logic diagram of reverse power protection 2 12 2 Setting Notes General The application of reverse power protection is only possible in 3 phase protected ob jects It can only be assigned to a side of the main protected object or another mea suring location Furthermore it is a prerequisite that the device is connected to a three phase voltage transformer set The rever...

Page 247: ...ergy see sections 2 1 4 and Commissioning Verification of the Voltage Connections and Directional Check If the reverse power protection has been assigned to one side of the machine to be protected the pickup value of the reverse power can be set as relative value relevant to machine rated power under address 5012 Pr pick up As the reverse power is a negative active power it is set as a negative va...

Page 248: ...n oil pressure switch or a position switch at the emergency trip valve Before tripping it must be ensured that the reverse power is only caused by the missing drive power at the turbine side A time delay is necessary to bridge the active power swing in case of sudden valve closing until a steady state active power value is achieved A time delay 5014 T SV CLOSED of about 1 to 3 s is sufficient for ...

Page 249: ...5 W 5012 Pr pick up 17 00 0 01 P SnS 0 05 P SnS Pick up threshold reverse power 5013 T SV OPEN 0 00 60 00 sec 10 00 sec Time Delay Long without Stop Valve 5014 T SV CLOSED 0 00 60 00 sec 1 00 sec Time Delay Short with Stop Valve 5015A T HOLD 0 00 60 00 sec 0 00 sec Pickup Holding Time 5016A Type of meas accurate fast accurate Type of measurement No Information Type of In formation Comments 5083 Pr...

Page 250: ...signed corresponding current transformer allow for a logical calculation of the active power This is therefore only possible for 7UT613 and 7UT633 When the circuit breakers are deactivated the P stage should be blocked via exter nal signals 2 13 1 Function Description Determining Real Power The forward power supervision in 7UT6 calculates the active power from the symmet rical components of the fu...

Page 251: ... three phase voltage transformer set that permits a sensible calculation of the active power with the respective current transformer connection The forward power monitoring can only be effective and is only accessible if it has been set during configuration under address 151 FORWARD POWER Enabled sec tion 2 1 3 Under address 5101 FORWARD POWER the forward power monitoring can be switched ON or OFF...

Page 252: ...ain protected object The following applies to the conversion where Psec secondary power UNprim primary rated voltage of the voltage transformer inter linked UNsec secondary rated current of the voltage transformer in terlinked INprim primary rated current of the current transformer INsec secondary rated current of the current transformer Pprim primary power Example Transformer 16 MVA winding 20 kV...

Page 253: ...small active power from great apparent power must be calculated precisely e g in generator range or in protected objects with high reactive power Please also note that the operating time in this option is higher due to averaging over 16 periods A precise measurement requires that the angle errors of the current and voltage transformers are compensated by means of a respective setting of the fault ...

Page 254: ...vis is switched OFF 5122 Pf BLOCKED OUT Forward power supervision is BLOCKED 5123 Pf ACTIVE OUT Forward power supervision is ACTIVE 5126 Pf picked up OUT Forward power Pf stage picked up 5127 Pf picked up OUT Forward power Pf stage picked up 5128 Pf TRIP OUT Forward power Pf stage TRIP 5129 Pf TRIP OUT Forward power Pf stage TRIP 5130 Pf CT fact OUT Forward pwr err CT fact too large small 5131 Pf ...

Page 255: ...undervoltage protection in 7UT613 63x uses the positive sequence system from the fundamental harmonic of the connected phase to earth voltages Compared to three single phase measuring systems the detection of the positive phase sequence system is not influenced by 2 pole faults or earth faults Overvoltage protection includes two stages A pickup is signalled as soon as select able voltage threshold...

Page 256: ...ally the command can be blocked if the protection function is enabled Block relay Pickup Values Times The undervoltage protection consists of two phases The equivalent of the phase phase voltage is detected therefore 3 U1 The setting is thus effected in interlinked values The U stage is set slightly below the minimum operational expected voltage under address 5212 U if the reference values are rel...

Page 257: ... not result in a trip however the pickup will be indicated Dropout Ratio The drop out ratio can be adjusted to the operating conditions at address 5217 DOUT RATIO This parameter can only be altered in DIGSI at Additional Settings 2 14 3 Settings Addresses which have an appended A can only be changed with DIGSI under Ad ditional Settings 2 14 4 Information List Addr Parameter Setting Options Defaul...

Page 258: ...ge protection U 033 2503 BLOCK U SP BLOCK undervoltage protection U 033 2521 U picked up OUT Undervoltage U picked up 033 2522 U picked up OUT Undervoltage U picked up 033 2551 U TRIP OUT Undervoltage U TRIP 033 2552 U TRIP OUT Undervoltage U TRIP No Information Type of In formation Comments ...

Page 259: ...he overvoltage protection only gets its measur ing information from the connected voltage measurement it leaves the assignment of currents to one side or a measuring location for the function without coating Setting causes the same differences as in other protection functions If the overvoltage pro tection is assigned to one side of the main protective object or the three phase busbar the voltage ...

Page 260: ...tities used by the pro tection feature Setting U ph ph evaluates the phase phase voltages This is not in fluenced by displacement voltages that occur during ground connections or earth faults at a certain distance from the grounding point The setting U ph e of the phase earth voltage reflects the actual insulation damage against earth and can also be used in an earthed starpoint This parameter can...

Page 261: ... voltage regulator regulates voltage variations The protection must not intervene in the regulation process of the faultlessly functioning voltage reg ulator The two stage characteristic must therefore always be above the voltage time characteristic of the regulation procedure All setting times are additional time delays which do not include the operating times measuring time dropout time of the p...

Page 262: ...age protection is BLOCKED 034 2413 Overvolt ACT OUT Overvoltage protection is ACTIVE 034 2491 U err Obj OUT Overvoltage Not avail for this obj 034 2492 U err VT OUT Overvoltage error VT assignment 034 2502 BLOCK U SP BLOCK overvoltage protection U 034 2503 BLOCK U SP BLOCK overvoltage protection U 034 2521 U picked up OUT Overvoltage U picked up 034 2522 U picked up OUT Overvoltage U picked up 034...

Page 263: ... the fourth is an overfrequency stage f It can also be used for three phase protective objects This implies that the device is connected to a voltage transformer This is therefore only possible for 7UT613 and 7UT633 As the frequency protection only gets its measuring information from the con nected voltage measurement it leaves the assignment of currents to one side or a measuring location for the...

Page 264: ...r the frequency protection is blocked via the indication FQS Each frequency stage has a set delay time Each of the four frequency elements can be blocked individually by binary inputs The entire frequency protection can be blocked via a binary input A corresponding command is signalled after the delay time Figure 2 106 Logic diagram of frequency protection ...

Page 265: ...h rated frequency Generally turbine driven generators can be continuously operated down to 95 of nominal frequency provided that the apparent power is reduced proportionally How ever for inductive consumers the frequency reduction not only means greater current consumption but also endangers stable operation Therefore a short term frequency reduction down to approx 48 Hz at fN 50 Hz or 58 Hz at fN...

Page 266: ... 16 3 Settings Level Changes to CPU modules Setting at fN Delay 50 Hz 60 Hz 16 7 Hz f Warning 49 50 Hz 59 50 Hz 16 60 Hz 20 00 s f Disconnection from the network 48 00 Hz 58 00 Hz 16 00 Hz 1 00 s f Shutdown 47 00 Hz 57 00 Hz 15 70 Hz 6 00 s f Warning and trip 52 00 Hz 62 00 Hz 17 40 Hz 10 00 s Addr Parameter Setting Options Default Setting Comments 5601 O U FREQUENCY OFF ON Block relay OFF Over Un...

Page 267: ... 5254 Freq error VT OUT Frequency protection error VT assign 5255 Freq err Obj OUT Frequency prot Not avail for this obj 12006 Freq f blk SP Frequency prot Block Stage f 12007 Freq f blk SP Frequency prot Block Stage f 12008 Freq f blk SP Frequency prot Block Stage f 12009 Freq f blk SP Frequency prot Block Stage f 12032 Freq f P up OUT Frequency prot Pick up Stage f 12033 Freq f P up OUT Frequenc...

Page 268: ...ive function to the sides or measuring locations and breakers were done according to Section 2 1 4 2 17 1 Function Description General The following information refers to the first breaker failure protection if not stated oth erwise Whenever the differential protection or any internal or external fault protection function of a feeder issues a trip command to the circuit breaker for example this is...

Page 269: ... determine the correct response of the circuit breaker In such cases the circuit breaker position can be derived from the auxiliary contacts of the breaker or from the feed back information of the integrated control function Therefore instead of monitoring the current the condition of the circuit breaker auxiliary contacts are mon itored Figure 2 108 Figure 2 108 Simplified function diagram of cir...

Page 270: ...ly when no current flow is detected at the instant of initiation i e the trip command of a protection function in ternal or external which is to start the breaker failure protection In this case the breaker is assumed to be open as soon as the auxiliary contact criterion indicates open breaker Once the current flow criterion has picked up before the trip signal from the initiating protection the c...

Page 271: ...the feeder circuit breaker usually on a second trip coil This is achieved via the output indication BF T1 TRIP loc Fno 047 2654 A second time stage T2 monitors the response to this repeated trip command and is used to trip the adjacent breakers of the busbar or busbar section if the fault has not yet been cleared after the repeated trip command The output indication BF T2 TRIP bus Fno 047 2655 is ...

Page 272: ... allows to operate the protection but the trip output relay is blocked The second breaker failure protection is switched at address 7101 BREAKER FAILURE ON or OFF Initiation Three statements are essential for the correct initiation of the circuit breaker failure protection The Current flow MonitoringCurrent flow monitoring ensures that the current flow stops after the trip command has been issued ...

Page 273: ...y a different circuit breaker failure protection This cascad ing does not cause initiation If the circuit breaker does not respond to the repeated trip command the protection trips after a second delay time T2 address 7116 the adjacent circuit breakers i e those of the busbar or the affected busbar section and if necessary also the circuit breaker at the remote end if the fault is not yet eliminat...

Page 274: ...r single stage breaker failure protection Additional Circuit Breaker Failure Protection Func tions In the aforementioned description the first circuit breaker failure protection is de scribed respectively The differences in the parameter addresses and message numbers of the first and second circuit breaker failure protection are illustrated in the following table The positions marked by x are iden...

Page 275: ...47 2412 BkrFail BLOCK OUT Breaker failure is BLOCKED 047 2413 BkrFail ACTIVE OUT Breaker failure is ACTIVE 047 2491 BkrFail Not av OUT Breaker failure Not avail for this obj 047 2651 BrkFail extSRC SP Breaker failure initiated externally 047 2652 BkrFail int PU OUT Breaker failure internal PICKUP 047 2653 BkrFail ext PU OUT Breaker failure external PICKUP 047 2654 BF T1 TRIP loc OUT BF TRIP T1 loc...

Page 276: ... 851 The logic diagram illustrates these direct couplings Two of these functions are avail able The message numbers are illustrated for external trip command 1 Figure 2 112 Logic Diagram of External Trip Feature illustrated for external trip 1 simpli fied Transformer Mes sages In addition to the external trip commands as described above some typical messages from power transformers can be incorpor...

Page 277: ...ult 2 18 2 Setting Notes General The direct external trip functions are only enabled if addresses 186 EXT TRIP 1 and or 187 EXT TRIP 2 have been set to Enabled during the configuration of the functional scope Addresses 8601 EXTERN TRIP 1 and 8701 EXTERN TRIP 2 are used to switch the functions individually ON or OFF or to block only the trip command Block relay Signals included from outside can be ...

Page 278: ...ED 4533 Ext 1 ACTIVE OUT External trip 1 is ACTIVE 4536 Ext 1 picked up OUT External trip 1 General picked up 4537 Ext 1 Gen TRIP OUT External trip 1 General TRIP 4543 BLOCK Ext 2 SP BLOCK external trip 2 4546 Ext trip 2 SP Trigger external trip 2 4551 Ext 2 OFF OUT External trip 2 is switched OFF 4552 Ext 2 BLOCKED OUT External trip 2 is BLOCKED 4553 Ext 2 ACTIVE OUT External trip 2 is ACTIVE 455...

Page 279: ...he reference voltage of the AD analogue to digital converter The protection is blocked in case of inadmissible deviations Contin uous malfunctioning is indicated by the alarm Error MeasurSys No 181 Back up Battery The back up battery guarantees that the internal clock continues to work and that metered values and alarms are stored if the auxiliary voltage fails The charge level of the battery is c...

Page 280: ...e transformers an important commissioning aid The measured quantities are periodically checked in the back ground for this purpose as long as no system fault is present Current Symmetry In a healthy three phase system symmetry amongst the currents is assumed The monitoring of the measured values in the device checks this balance for each 3 phase measuring location The lowest phase current is thus ...

Page 281: ...e to earth voltage is set in relation to the highest An imbalance is detected when Umin Umax BAL FACTOR U as long as Umax BALANCE U LIMIT TherebyUmax is the largest of the three phase to phase voltages and Umin the smallest The symmetry factor BAL FACTOR U is the measure for the asymmetry of the con ductor voltages the limit value BALANCE U LIMIT is the lower limit of the operating range of this m...

Page 282: ...must be considered during the configuration of the general power system data Subsection 2 1 4 under Phase rotation Phase rotation is checked by supervising the phase sequence of the currents i e for clockwise rotation IL1 before IL2 before IL3 The supervision of current rotation requires a minimum current of IL1 I L2 I L3 0 5 IN If the rotation measured differs from the rotation set the annunciati...

Page 283: ...cb with con nected auxiliary contacts then the fuse failure monitoring can detect problems in the voltage transformer secondary circuit Of course the miniature circuit breaker and the fuse failure monitor can be used at the same time The asymmetrical measured voltage failure is characterised by its voltage asymmet rical with simultaneous current symmetry Figure 2 116 depicts the logic diagram of t...

Page 284: ... Monitor A three phase failure of the secondary measured voltage can be distinguished from an actual system fault by the fact that the currents have no significant change in the event of a failure in the secondary measured voltage For this reason the sampled current values are routed to a buffer so that the difference between the present and stored current values can be analysed to recognise the m...

Page 285: ... I th M1 This parameter can only be set with DIGSI at Additional Settings The time delay usually amounts to a few seconds The same considerations apply for the further measuring locations as far as they are available and allocated Address 8121 BAL I LIMIT M2 8122 BAL FACT I M2 and 8123 T Sym I th M2 for measuring location 2 address 8131 BAL I LIMIT M3 8132 BAL FACT I M3 and 8133 T Sym I th M3 for ...

Page 286: ...e table indicates region specific presettings Column C configuration indicates the corresponding secondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 8101 BALANCE I ON OFF OFF Current Balance Supervi sion 8102 BALANCE U ON OFF OFF Voltage Balance Supervi sion 8104 SUMMATION U ON OFF OFF Voltage Summation Su pervision 8105 PHASE ROTAT I ON O...

Page 287: ...161 Fail I Superv OUT Failure General Current Supervision 163 Fail I balance OUT Failure Current Balance 164 Fail U Superv OUT Failure General Voltage Supervision 165 Fail Σ U Ph E OUT Failure Voltage Summation Phase Earth 167 Fail U balance OUT Failure Voltage Balance 171 Fail Ph Seq OUT Failure Phase Sequence 175 Fail Ph Seq I OUT Failure Phase Sequence Current 176 Fail Ph Seq U OUT Failure Phas...

Page 288: ...auxiliary contact A precondition for the use of the trip circuit supervision is that the control voltage for the circuit breaker is higher than the total of the minimum voltages drops at the two binary inputs UCtrl 2 UBImin Since at least 19 V are needed for each binary input the supervision function can only be used with a system control voltage of more than 38 V Figure 2 117 Principle of trip ci...

Page 289: ...at an alarm is output during short transition periods After the fault in the trip circuit is removed the alarm is reset automatically after the same time Figure 2 118 Logic Diagram of the Trip Circuit Supervision with Two Binary Inputs simplified Supervision Using One Binary Input The binary input is connected in parallel to the respective command relay contact of the protection device according t...

Page 290: ...t breaker auxiliary contact if the circuit breaker is closed or through the equivalent resistor R Only as long as the trip contact of the command relay is closed the binary input is short circuited and thereby deactivated logical con dition 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 T...

Page 291: ...rvice and indicate this condition by drop off of the Device OK relay thus indicating the device failure 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 aux iliary voltage supply fails all LEDs are dark The following table shows a summary of the most important monitoring functions and the fault react...

Page 292: ...0 1 A wrong Alarms Protection out of opera tion Error1A 5Awrong LED ERROR DOK2 drops out Calibration data internal device not calibrated Alarm Using default values Alarm adjustm as allocated Backup battery Internal backup battery Alarm Fail Battery as allocated Clock Time synchronization Alarm Clock SyncError as allocated P C B modules Module does not comply with ordering number Alarms Protection ...

Page 293: ...r secondary circuit All respective protec tion functions are blocked brk wire IL1M1 brk wire IL2M1 brk wire IL3M1 brk wire IL1M5 brk wire IL3M5 brk wire IL3M5 as allocated Circuit Breaker Circuit breaker tripping Alarm with identifica tion of the measuring location side Incons CBaux M1 Incons CBaux M5 or Incons CBaux S1 Incons CBaux S5 as allocated EN100 Module external wiring EN100 Module Message...

Page 294: ...wave forms can additionally be made subject to the presence of a trip command Creation of spontaneous displays Certain fault messages can be displayed as so called spontaneous displays This display can be made dependent on occurrence of a trip command External functions can be controlled via an output contact Examples are starting of additional devices or similar Spontaneous Dis plays Spontaneous ...

Page 295: ...cking After tripping the circuit breaker by a protection function the manual reclosure must often be blocked until the cause for the protection operation is found Using the user configurable logic functions CFC an automatic reclosure interlocking function can be created The default setting of 7UT613 63x offers a pre defined CFC logic which stores the trip command of the device until the command is...

Page 296: ...on the protected line so called no trip no flag feature Figure 2 122 Logic diagram of the no trip no flag feature trip dependent alarms Statistical Counters The number of trips initiated by the device 7UT613 63x are counted Furthermore the current interrupted for each pole and each measuring location is ac quired provided as an information and accumulated in a memory The criterion for the acquisit...

Page 297: ...affecting any operating function of the sides for example the differential protection Figure 2 123 Arrangement with 11 2 circuit breakers 3 breakers for 2 transformer feeders Any measuring location can be disconnected by means of an appropriate binary input In 1 phase busbar protection such a binary input can be used for each feeder The disconnection works only in the specified frequency range of ...

Page 298: ...ation are not effective here The currents from 1 phase auxiliary measuring inputs allocated to the isolated mea suring input stay valid Currents remain valid for those protection functions which are not assigned to a side No protection functions are blocked The differential protection continues to work with the remaining available measured values In the above example the transformer can still oper...

Page 299: ...End 8 is disconnected 30093 I9 disconnected OUT End 9 is disconnected 30094 I10disconnected OUT End 10 is disconnected 30095 I11disconnected OUT End 11 is disconnected 30096 I12disconnected OUT End 12 is disconnected 30361 disconn I 0 SP disconnect without test current 0 30362 disconnect M1 SP disconnect measurment location 1 30363 disconnect M2 SP disconnect measurment location 2 30364 disconnect...

Page 300: ...are reset On site by pressing the LED key on the relay Remotely using a binary input configured for that purpose Using one of the serial interfaces Automatically at the beginning of a new pickup Status messages should not be latched Also they cannot be reset until the condition to be reported has been cancelled This applies to e g indications from monitoring functions or the like A green LED displ...

Page 301: ...fluenced during opera tion or tests The IEC 60870 5 103 protocol allows to identify all indications and mea sured values transferred to the central control system with an added indication test mode while the device is being tested on site test mode This identification prevents the indications from being incorrectly interpreted as resulting from an actual power system disturbance or event Alternati...

Page 302: ...protection function so that the duration of a fault until tripping and up to reset of the trip command can be ascertained The tripping of the time entry is about 1 ms A system fault starts with the recognition of the fault by the fault detection i e first pickup of any protection function and ends with the reset of the fault detection i e dropout of the last protection function Where fault causes ...

Page 303: ...be reset back to zero or to any value within the setting range They can be called up at the front of the device read out via the operating interface using a PC with DIGSI or transferred to a central master station via the system inter face A password is not required to read switching statistics however a password is re quired to change or delete the statistics 2 22 2 Measurement 2 22 2 1 Display a...

Page 304: ...ductive reactive components in the direction of the protective object are positive The same applies for the power factor cos ϕ It is occasionally desired to define the power draw from the protected object e g as seen from the user side of the transformer positively Using parameter address 1107 P Q sign the signs for these components can be inverted For devices without voltage measuring inputs a vo...

Page 305: ... 5 A kA R IZ1 IZ2 IZ3 Currents at the 1 phase further measur ing locations X1 to X3 A kA R if allocated to side see measured value ILxSy if allocated to measuring lo cation see measured value ILxMz if not allocated then IN PRI WDL IZ1 4 IX4 5 Current at the further measuring loca tion X4 5 A kA R I1 to I9 3 Currents at the measuring inputs 3 A kA R Rated operational current I10 to I12 3 5 Currents...

Page 306: ...s 3 only for 7UT635 The phase angles are listed separately in Table 2 14 The reference value for 3 phase objects is the current IL1M1 current in phase L1 at measuring location M1 which has thus a phase angle 0 With 1 phase busbar protection the current I1 has the phase angle 0 i e it is the reference value Depending on the device s order number connection type topology and protection functions con...

Page 307: ...loca tions Z1 to Z3 referred to IL1M13 0 0 360 100 ϕIZ4 5 Currents at the 1 phase auxiliary measuring loca tion Z4 referred to IL1M1 5 0 0 360 100 ϕI1 to ϕI9 3 Phase angle of the currents at the current inputs referred to I13 0 0 360 100 ϕI10 to ϕI12 3 5 Phase angle of the currents at the current inputs referred to I13 5 0 0 360 100 ϕUL1E ϕUL2E ϕUL3E 1 4 Phase angle of the voltages at the 3 phase ...

Page 308: ...9 ϕI7 MV Phase angle of current I7 30640 3I0S1 MV 3I0 zero sequence of side 1 30641 I1S1 MV I1 positive sequence of side 1 30642 I2S1 MV I2 negative sequence of side 1 30643 3I0S2 MV 3I0 zero sequence of side 2 30644 I1S2 MV I1 positive sequence of side 2 30645 I2S2 MV I2 negative sequence of side 2 30646 I1 MV Operat meas current I1 30647 I2 MV Operat meas current I2 30648 I3 MV Operat meas curre...

Page 309: ... sequence of meas loc 5 30689 I1M5 MV I1 positive sequence of meas loc 5 30690 I2M5 MV I2 negative sequence of meas loc 5 30713 3I0S3 MV 3I0 zero sequence of side 3 30714 I1S3 MV I1 positive sequence of side 3 30715 I2S3 MV I2 negative sequence of side 3 30716 IL1S4 MV Operat meas current IL1 side 4 30717 IL2S4 MV Operat meas current IL2 side 4 30718 IL3S4 MV Operat meas current IL3 side 4 30719 3...

Page 310: ...3 ϕIL2M3 MV Phase angle in phase IL2 meas loc 3 30744 ϕIL3M3 MV Phase angle in phase IL3 meas loc 3 30745 ϕIL1M4 MV Phase angle in phase IL1 meas loc 4 30746 ϕIL2M4 MV Phase angle in phase IL2 meas loc 4 30747 ϕIL3M4 MV Phase angle in phase IL3 meas loc 4 30748 ϕIL1M5 MV Phase angle in phase IL1 meas loc 5 30749 ϕIL2M5 MV Phase angle in phase IL2 meas loc 5 30750 ϕIL3M5 MV Phase angle in phase IL3...

Page 311: ...to the tripping value θ θTrip 1 Thermal resultant value referred to the tripping value Ag rate 2 3 Relative ageing rate L p u Res Warn 2 3 Load reserve to hot spot ageing alarm stage 1 Res Alarm 2 3 Load reserve to hot spot tripping stage 1 θ leg L1 θ leg L2 θ leg L3 2 3 Hot spot temperature for each phase Y winding or Z winding C or F 0 C 0 500 C 100 0 F 0 1000 F 100 θ leg L12 θ leg L23 θ leg L31...

Page 312: ...2 MV Th O L 2 Temperature rise for phase L2 204 2614 2Θ ΘtrpL3 MV Th O L 2 Temperature rise for phase L3 204 2615 2Θ leg L1 MV Th O L 2 Hot spot temperature of leg L1 204 2616 2Θ leg L2 MV Th O L 2 Hot spot temperature of leg L2 204 2617 2Θ leg L3 MV Th O L 2 Hot spot temperature of leg L3 204 2618 2Θ legL12 MV Th O L2 Hot spot temperature of leg L12 204 2619 2Θ legL23 MV Th O L2 Hot spot temperat...

Page 313: ...et if their measured and metered values have been configured correspondingly in CFC see SIPROTEC 4 System Description 1 Measured Values referred to IDiffL1 IDiffL2 IDiffL3 Calculated differential currents of the three phases Operational rated current of the protected object IRESTL1 IRESTL2 IRESTL3 Calculated restraining currents of the three phases Operational rated current of the protected object...

Page 314: ...ease be aware that 7UT613 63x is above all a protection device The precision of the metered values depends on the transformer normally protection core and the device tolerance The metering is therefore not suited for tariff purposes The counters can be reset to zero or any initial value see SIPROTEC 4 System De scription Table 2 17 Operational metered values Operating Hours Meter The main protecti...

Page 315: ...stem of the currents or current and voltage power The measured values can be monitored for overshooting or undershooting of a con figurable threshold value Delays blocking and logical configuration possibilities are possible via user definable logic functions CFC A flexible function can signal the state that needs to be monitored be used as control function or initiate tripping of one or more circ...

Page 316: ...n approximate dropout relay This should be considered when a dropout delay has been specified see also the setting values in this section A trip command once transmitted is retained until the pickup is terminated if applica ble also via the dropout delay The command is retained for all together set minimum tripping times of the tripping functions address 851 TMin TRIP CMD see section 2 1 4 under C...

Page 317: ...as described below In DIGSI the tabs set ting sheets should be edited from left to right Configuration Set tings The configuration settings can be executed for each desired flexible function These settings are fixed and are not influenced by the setting group change over In contrast to this the group of the function settings as described in the following next subsection can be executed for each se...

Page 318: ...ctive power must be evaluated This is only possible for 7UT613 or 7UT633 with voltage measuring inputs Please ensure to use the correct assignment of voltages to the currents from which the power is to be calculated as well as polarity Power factor if the power factor must be evaluated This is only possible for 7UT613 or 7UT633 with voltage measuring inputs Please ensure to use the correct assignm...

Page 319: ...additional measuring input is evaluated Only 3 additional measuring inputs are possible for 7UT613 and 7UT633 Only 1 single phase additional measuring input is possible for 7UT635 if 5 three phase inputs have been configured If you have chosen voltages from the pre selection voltage this determines exactly which of the measured or calculated voltages must be used for the evaluation of the flexible...

Page 320: ...iance with the limit value condition this period must first expire before a pickup can be indicated and result in further actions Delay of the drop off means that after activated pickup same can be maintained and delayed by such time period after non compliance of the limit value has stopped The trip command if desired is thus delayed by means of the trip command delay The time starts on activatio...

Page 321: ...vercurrent functions is usually not required Additional Steps If an additional flexible function has been created configured and set the correspond ing indications are entered in the DIGSI configuration matrix These indications are kept general and assign the ld number to the flexible functions e g Flx01 Pickup L1 You can now change their names to texts in accordance with your application Thereaft...

Page 322: ...eshold I10 0 Pick up thresh 1A 5A 0 1A 0 05 35 00 A 0 25 175 00 A 0 005 3 500 A 2 00 A 10 00 A 0 200 A Pick up threshold I11 0 Pick up thresh 1A 5A 0 1A 0 05 35 00 A 0 25 175 00 A 0 005 3 500 A 2 00 A 10 00 A 0 200 A Pick up threshold I12 0 Pick up thresh 1A 5A 0 05 35 00 A 0 25 175 00 A 2 00 A 10 00 A Pick up threshold IZ1 0 Pick up thresh 1A 5A 0 05 35 00 A 0 25 175 00 A 2 00 A 10 00 A Pick up t...

Page 323: ...me Delay 0A BLOCKED BY FFM YES NO YES Block in case of Meas Voltage Loss 0A Blk I brkn cond YES NO YES Block for broken conductor in CT path 0A DROPOUT RATIO 0 70 0 99 0 95 Dropout Ratio 0A DROPOUT RATIO 1 01 3 00 1 05 Dropout Ratio 0 MEAS QUANTITY I Meas Loc side Curr I1 I12 Curr IZ1 IZ4 Voltage P forward P reverse Q forward Q reverse Power factor Frequency I Meas Loc side Selection of Measured Q...

Page 324: ... Information Type of In formation Comments 235 2110 BLOCK 00 SP BLOCK Function 00 235 2111 00 instant SP Function 00 instantaneous TRIP 235 2113 00 BLK TDly SP Function 00 BLOCK TRIP Time Delay 235 2114 00 BLK TRIP SP Function 00 BLOCK TRIP 235 2115 00 BL TrpL1 SP Function 00 BLOCK TRIP Phase L1 235 2116 00 BL TrpL2 SP Function 00 BLOCK TRIP Phase L2 235 2117 00 BL TrpL3 SP Function 00 BLOCK TRIP ...

Page 325: ...omputer and evaluated with the operating software DIGSI and the graphic analysis software SIGRA 4 The latter graphically represents the data recorded during the system fault and calculates additional information such as power or rms values from the measured values A selection may be made as to whether the measured quantities are repre sented as primary or secondary values Binary signal traces mark...

Page 326: ...ss 905 after the storage criterion has reset The maximum recording duration to each fault MAX LENGTH is entered in address 903 Recording to each fault may take max 5 seconds A total of 8 records can be saved However the total length of time of all fault records in the buffer may not exceed 5 seconds An oscillographic record can be triggered and saved by a change in status of a binary input or via ...

Page 327: ...thus allowing to operate the device from the PC The actual operation of the device can be simulated with the mouse pointer Measured values and the values derived from them are graphically dis played as phasor diagrams You can also view tripping diagrams scalar values are shown in numerical form Most of the measured values discussed in Subsection 2 22 2 can also be displayed in the Web Monitor For ...

Page 328: ...2 Functions 328 7UT613 63x Manual C53000 G1176 C160 2 Figure 2 125 Phasor Diagram of the Secondary Measured Values Example ...

Page 329: ...differential protection values Selection of the input value varies depending on the protection device 7UT613 63x and the settings of the configuration parameters With the parameter Scope of the Extended Measured Values it can be determined whether calculation units are to calculate average values minimum and maximum values or minimum and maximum values of long term average values or a combina tion...

Page 330: ... Hour or 45 After Hour If the settings for averaging are changed then the measured values stored in the buffer are deleted and new results for the average calculation are only available after the set time period has passed 2 23 1 2 Settings 2 23 2 Min Max Measurement Setup 2 23 2 1 Setting Notes Resetting of the minimum and maximum values can also be done cyclically com mencing with the preselecte...

Page 331: ...7621 MinMax cycRESET NO YES YES Automatic Cyclic Reset Function 7622 MiMa RESET TIME 0 1439 min 0 min MinMax Reset Timer 7623 MiMa RESETCYCLE 1 365 Days 7 Days MinMax Reset Cycle Period 7624 MinMaxRES START 1 365 Days 1 Days MinMax Start Reset Cycle in No Information Type of In formation Comments ResMinMax IntSP_Ev Reset Minimum and Maximum counter 11001 Reset MinMax SP Reset MinMaxValues ...

Page 332: ... 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 transformer taps Setpoint commands with configurable time settings e g to control Petersen coils Device internal Commands These commands do not directl...

Page 333: ...Protection blocking blocking of switching operations by protection functions Circuit breaker synchronization check synchronism check before a close com mand 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 con tact Configuration in process if setting modification is in proc...

Page 334: ...ogramming the settings with password check For automatic commands via command processing by CFC and Deactivated Inter locking Recognition For local remote commands using an additional interlocking disable command via PROFIBUS Interlocked non in terlocked Switch ing The configurable command checks in the SIPROTEC 4 devices are also called stan dard interlocking These checks can be activated via DIG...

Page 335: ...it breaker The check of interlocking can be programmed separately for all switching devices and tags that were set with a tagging command Other internal commands such as over riding or abort are not tested i e are executed independently of the interlockings Figure 2 126 Example of an operational indication for switching circuit breaker 52 Standard Interlock ing The standard interlocking includes t...

Page 336: ...ured interlocking reasons The are marked by letters as explained in Table 2 19 Table 2 19 Interlocking Commands Figure 2 128 shows all interlocking conditions which usually appear in the display of the device for three switchgear items with the relevant abbreviations explained in Table 2 19 All parameterised interlocking conditions are indicated Interlocking Commands Command Display Switching Auth...

Page 337: ...n on the serial digital interface The acknowledgement of commands is therefore not executed by a response indica tion as it is done with the local command but by ordinary command and feedback in formation recording Feedback Monitor ing Command processing time monitors all commands with feedback Parallel to the com mand a monitoring time period command runtime monitoring is started which checks whe...

Page 338: ...1 5 Information List No Information Type of In formation Comments Cntrl Auth IntSP Control Authority Cntrl Auth DP Control Authority ModeREMOTE IntSP Controlmode REMOTE ModeLOCAL IntSP Controlmode LOCAL ModeLOCAL DP Controlmode LOCAL CntrlDIGSI LV Control DIGSI ...

Page 339: ...on 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 protect ed object line transformer etc to carry load 3 1 Mounting and Connections 340 3 2 Checking Connections 374 3 3 Commissioning 379 3 4 Final Prep...

Page 340: ...rovided in Appendix A 3 It must be checked that the settings for configuration Subsection 2 1 3 and the Power System Data Subsec tion 2 1 4 match the connections to the device Protected Object The setting of the protected object address 105 must correspond to the object to be protected An incorrect setting may cause unforeseeable reactions by the device Please note that for auto transformers PROT ...

Page 341: ...sions 7UT613 and 7UT633 This paragraph only applies when measured circuit voltage is connected to the device and this has been stated in the configuration according to 2 1 4 margin heading Assignment of Voltage Measuring Inputs In the Appendix A 3 you will find possible examples of the voltage transformer connec tion options The voltage transformer connections must comply with the settings in para...

Page 342: ...sion Please note that two binary inputs or one binary input and one bypass resistor R must be connected in series The pickup threshold of the binary inputs must therefore be substantially below half the rated control DC voltage If two binary inputs are used for the trip circuit supervision these binary inputs must be isolated i o w not be communed with each other or with another binary input If on...

Page 343: ... Bypass resistor This results in an upper limit for the resistance dimension Rmax and a lower limit Rmin from which the optimal value of the arithmetic mean R should be selected In order that the minimum voltage for controlling the binary input is ensured Rmax is derived as So the circuit breaker trip coil does not remain energized in the above case Rmin is derived as IBI HIGH Constant Current wit...

Page 344: ...es Example IBI HIGH 1 7 mA SIPROTEC 4 device 7UT613 63x UBI min 19 V for delivery setting for nominal voltages of 24 48 60 V SIPROTEC 4 device 7UT613 63x 73 V for delivery setting for nominal voltages of 110 125 220 250 V SIPROTEC 4 device 7UT613 63x UCTR 110 V from system trip circuit RTC 500 Ω system trip circuit UCBTC LOW 2 V from system trip circuit Rmax 53 kΩ Rmin 27 kΩ The closest standard v...

Page 345: ...the rated currents are usually 100 mA The physical arrangements of these jumpers that correspond to the different current ratings are described below under margin heading Input Output Board C I O 2 In put Output Board C I O 9 all versions and Input Output Board C I O 9 only 7UT635 When performing changes please make sure that the device is always informed about them Using three phase applications ...

Page 346: ...l interface modules can be replaced For details please refer to the section Interface Modules Terminating Serial Interfaces If the device is equipped with a serial RS485 port the RS485 bus must be terminated with resistors at the last device on the bus to ensure reliable data transmission For this purpose terminating resistors are provided on the interface board and on the in terface modules which...

Page 347: ... 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 and C This activity does not apply if the device is for surface mount ing If the device has additional communication interfaces to A and C at the loca tions B and or D on the rear the screws located diagonally to the interfaces must be remove...

Page 348: ...PU 2 1 board and the I O boards 2 to 4 depending on version Remove the boards and set them on the grounded mat to protect them from ESD damage In the case of the device variant for panel surface mounting please be aware of the fact that a certain amount of force is required in order to remove the C CPU 2 module due to the existing plug connectors Check the jumpers in accordance with the figures an...

Page 349: ...3 1 Mounting and Connections 349 7UT613 63x Manual C53000 G1176 C160 2 Figure 3 4 Front view with housing size 1 1 after removal of the front panel simplified and scaled down ...

Page 350: ... power supply the selected control voltages of binary inputs BI1 to BI5 the quiescent state of the life contact and the type of the integrated RS232 RS485 in terface using the the tables below Before checking the integrated RS232 RS485 in terface it may be necessary to remove the interface modules mounted on top of it Figure 3 5 Processor board C CPU 2 without interface modules with representation...

Page 351: ...5 to X110 must be set to the same position Table 3 5 Jumper settings of the integrated RS232 RS485 Interface on the C CPU 2 pro cessor board The jumpers are preset at the factory according to the configuration ordered With interface RS232 jumper X111 is needed to activate CTS which enables the com munication with the modem Jumper Nominal voltage 24 to 48 VDC 60 to 125 VDC 110 to 250 VDC 115 to 230...

Page 352: ...ection cable converter 9 pin to 25 pin Note For a direct connection to DIGSI with interface RS232 jumper X111 must be plugged in position 2 3 If there are no external terminating resistors in the system the last devices on a RS485 bus must be configured via jumpers X103 and X104 Table 3 7 Jumper settings of the Terminating Resistors of the RS485 interface on the C CPU 2 processor board Note Both j...

Page 353: ... 6 and the in put output group C I O 10 as from release 7UT6 EE in Figure 3 7 The input output board C I O 1 is only available in the versions 7UT633 and 7UT635 Figure 3 6 C I O 1 input output boards with representation of jumper settings required for checking configuration settings For 7UT633 and 7UT635 as from release EE a further C I O 1 or C I O 10 can be available at slot 33 depending on the ...

Page 354: ...ation settings Some of the output contacts can be changed from NO normally open operation to NC normally closed operation refer also to the Appendix Section A 2 For 7UT633 versions this applies for the binary outputs BO9 and BO17 Figure 3 4 slot 33 left side and slot 19 left side For 7UT635 this applies for the binary outputs BO1 BO 9 and BO17 Figure 3 4 slot 5 right side slot 33 left side and slo...

Page 355: ...d The following tables list the jumper presettings Table 3 10 Jumper settings of the module addresses of the input output boards C I O 1 and C I O 10 Device Module For Jumper Quiescent State open close Quiescent State closed open Default Posi tion 7UT633 Slot 33 left side BO9 X40 1 2 2 3 1 2 Slot 19 left side BO17 X40 1 2 2 3 1 2 7UT635 Slot 5 right side BO1 X40 1 2 2 3 1 2 Slot 33 left side BO9 X...

Page 356: ...and 7UT633 Mounting lo cation for 7UT613 slot 19 for 7UT633 slot 19 right side Figure 3 8 C I O 2 input output board release 7UT613 63x EE or higher with represen tation of jumper settings required for checking configuration settings The relay contacts of the binary outputs BO6 to BO8 can be changed from NO nor mally open to NC normally closed operation refer also to Appendix A 2 ...

Page 357: ... the input output board C I O 2 serve for setting the bus address Their position may not be changed The following table shows the preset jumper positions Table 3 13 Jumper Position of the Module Addresses of the input output board C I O 2 The rated currents of the measured current inputs can be determined for each ana logue input via jumpers With default settings all jumpers are set to the same ra...

Page 358: ...ferent measuring locations i e the feeders 7 to 9 I7 I8 I9 Each input can be set individually X61 X62 X63 to 1A 5A or 0 1A Only if the measuring inputs I7 to I9 have the same rated current the common jumpers X60 are plugged to this rated current If different rated currents X51 and X60 are reigning within the input group the po sition of the common jumpers X51 and X60 is irrelevant For the addition...

Page 359: ...e 3 9 Input output boards with representation of the jumpers required for checking the settings Jumpers X71 through X73 serve for module identification and must not be changed The following table shows the preset jumper positions Table 3 15 Jumper settings of the module addresses of input output boards C I O 9 slot 33 in 7UT613 or slot 33 right in 7UT633 and 7UT635 Jumper 7UT613 7UT633 and 7UT635 ...

Page 360: ...n 1 2 For 1 phase busbar protection There are 6 measuring inputs for 6 different measuring locations i e the feeders 1 to 6 I1 I2 I3 I4 I5 I6 Each input can be set individually X61 X62 X63 X65 X66 X67 1A or 5A or 0 1A Only if the measuring inputs I1 to I3 have the same rated current is X81 plugged to this rated current Only if the measuring inputs I4 to I6 have the same rated current is X82 plugge...

Page 361: ... Table 3 16 Assignment of the jumpers for the rated currents to the measured current inputs 1 IN 01 in 7UT635 applicable for measuring location M5 Application Jumpers 3 phase 1 phase individual common IL1M1 I1 X61 X82 IL2M1 I2 X62 IL3M1 I3 X63 IL1M2 I4 X65 X81 IL2M2 I5 X66 IL3M2 I6 X67 IX1 IL1M5 1 X64 X83 IZ1 IL2M5 1 X68 X84 X85 X86 IZ3 sensitive ...

Page 362: ...ds with representation of the jumpers required for checking the settings Jumpers X71 through X73 on the input output board C I O 9 serve for setting the bus address Their position may not be changed The following table shows the preset jumper positions Table 3 17 Jumper position of module addresses of input output boards C I O 9 slot 19 right in 7UT635 Jumper 7UT635 Slot 19 right side X71 1 2 H X7...

Page 363: ...puts for 6 different measuring locations i e the feeders 7 to 12 I7 I8 I9 I10 I11 I12 Each input can be set individually to 1A or 5A or 0 1A X61 X62 X63 X65 X66 X67 Only if measuring inputs I7 to I9 have the same rated current will the common jumper X82 be plugged to this current Only if measuring inputs I10 to I12 have the same rated current will the common jumper X81 be plugged to this current I...

Page 364: ...devices with fibre optics connection have their fibre optics module fitted in the inclined housing on the case bottom The CPU module has there instead an RS232 interface module which communicates electrically with the FO module in the inclined housing Application Jumpers 3 phase 1 phase individual common IL1M3 I7 X61 X82 IL2M3 I8 X62 IL3M3 I9 X63 IL1M4 I10 X65 X81 IL2M4 I11 X66 IL3M4 I12 X67 IX2 I...

Page 365: ...11 C CPU 2 board with interface modules Note Please note the following Only interface modules of devices with flush mounting housing can be replaced Interface modules of devices with surface mounting housing must be replaced in our manufacturing centre Use only interface modules that can be ordered as an option of the device see also Appendix A 1 Termination of the serial interfaces in case of RS4...

Page 366: ...for configuration of RS232 Terminating resistors are not required They are disconnected Please observe that in surface mounted devices with fibre optics connection the CPU module is equipped with an RS232 interface module In this application the jumpers X12 and X13 on the RS232 module are set to position 2 3 unlike the arrangement shown in Figure 3 12 Interface Mounting location port Exchange modu...

Page 367: ... optionally We recommend to use a standard RS232 modem connection cable converter 9 pin to 25 pin Note For a direct connection to DIGSI with interface RS232 jumper X11 must be plugged in position 2 3 RS485 Interface Interface RS485 can be modified to interface RS232 and vice versa see Figures 3 12 and 3 13 For bus capable interfaces a termination is necessary at the bus for each last device i e te...

Page 368: ...osition of the plug in jumpers for the configuration of the terminating resistors at the Profibus FMS and DP DNP 3 0 and Modbus interfaces Terminating resistors can also be implemented outside the device e g in the plug con nectors In this case the terminating resistors located on the RS485 or PROFIBUS interface module must be switched off Figure 3 15 Termination of the RS485 interface external ...

Page 369: ...housing size 1 2 7UT613 there are 4 covers and 4 holes For housing size 1 1 7UT633 or 7UT635 there are 6 covers and 6 holes Remove the 4 or 6 caps on the corners of the front cover to reveal the 4 or 6 elon gated holes in the mounting bracket Insert the device into the panel cut out and fasten it with four or six screws For di mensions refer to Section 4 23 Mount the four or six covers Connect the...

Page 370: ...ng size 1 2 example Figure 3 17 Panel flush mounting of a 7UT633 or 7UT635 housing size 1 1 example 3 1 3 2 Rack and Cubicle Mounting Depending on the version the device housing can be 1 2 or 1 1 For housing size 1 2 7UT613 there are 4 covers and 4 holes For housing size 1 1 7UT633 or 7UT635 there are 6 covers and 6 holes ...

Page 371: ...th to the rear of the device using at least an M4 screw The cross sectional area of the earth wire must be equal to the cross sectional area of any other conductor connected to the device The cross section of the earth wire must be at least 2 5 mm2 Connections use the plug terminals or screw terminals on the rear side of the device in accordance the wiring diagram For screw connections with forked...

Page 372: ... screw the device and the transport protection onto the mounting panel using the 4 nuts and washers provided with the 4 bolts of the protection In all other cases remove the transport protection when you install a device with housing size 1 1 see below Removing the Transport Protection Secure the device to the panel with four screws For dimension drawings see Section 4 23 Connect the low resistanc...

Page 373: ...ntil the device has arrived at its final place of use Figure 3 20 View of a housing with transport protection without front cover nor boards Remove the 4 covers at the corners and the 2 covers in the centre above and below on the front cover to reveal 6 elongated holes Loosen the 6 screws 2 in the elongated holes Remove all other screws on the rails 1 and remove the top and bottom rails Loosen the...

Page 374: ...ly ensured See the Appendix for an ordering description of the cable Service Interface Check the data connection if the service interface Interface C for communicating with the device is via fix wiring or a modem If the service port is used as input for one or two RTD boxes verify the interconnection according to one of the connection exam ples given in the Appendix A 3 System Interface When a ser...

Page 375: ...C C GND It must be checked that the terminat ing resistors are connected only for the respectively last device of the bus but not for all other devices of the bus The jumpers for the terminating resistors are located on the interface module RS485 see figure 3 13 or PROFIBUS RS485 see figure 3 14 It is also possible that the terminating resistors are arranged externally figure 3 15 If the bus is ex...

Page 376: ...heir con nection at the service interface Port C or the auxiliary interface Port D Also verify the termination The terminating resistors must be connected to the device see margin heading Termination For further information refer to the operating manual of 7XV5662 xAD Check the transmission settings at the temperature meter Besides the baud rate and the parity the bus number is also important For ...

Page 377: ...ues can be found in the technical data Connection examples for current transformer circuits are provided in the Appendix A 3 Please observe the terminal assignments see Appendix A 2 Proceed as follows in order to check the system connections Protective switches for the power supply and the measured voltages must be switched off Check the continuity of all current and voltage transformer connection...

Page 378: ...ty for each pair of terminals Repeat the above continuity tests for the other boards that receive current from the CTs 7UT613 C I O 2 slot 19 7UT633 C I O 2 slot 19 right 7UT635 C I O 9 slot 19 right side Carefully plug in the ribbon cable Be careful not to bend any connector pins Do not apply force Attach the front panel and tighten the screws Connect an ammeter in the supply circuit of the power...

Page 379: ... can still be charged After removing voltage from the power supply wait a minimum of 10 seconds before re energizing the power supply This wait allows the initial conditions to be firmly es tablished before the device is re energized The limit values given in Technical Data must not be exceeded neither during testing nor during commissioning For tests with a secondary test equipment ensure that no...

Page 380: ...ecognised as result ing from testing and not actual fault or power system event Furthermore it can be de termined by activating the Transmission block that no indications at all are transmit ted via the system interface during test mode The SIPROTEC 4 System Description 1 describes how to activate and deactivate test mode and transmission block Note that when DIGSI is being used the program must b...

Page 381: ...tances check them by means of the testing mode during real operation performing transmission and re ception 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 DIGSI in the Online operating...

Page 382: ...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 Send in the function to be tested and check whether the corresponding infor mation reaches the control center and possibly shows the expected effect Data which are normally linked via binary inputs first character are li...

Page 383: ...nation 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 function selection appears in the right hal...

Page 384: ...s initiated all output relays are separated from the internal device functions and can only be operated by the hardware test function This means that e g a TRIP command coming from a protection function or a control command from the operator panel to an output relay cannot be executed Proceed as follows in order to check the output relay Make sure that the switching operations caused by the output...

Page 385: ...is opened the present conditions of the hard ware components at that moment are read in and displayed An update is made For the particular hardware component if a command for change to another state was successful For all hardware components if the Update button is clicked For all hardware components with cyclical updating cycle time is 20 sec if the Au tomatic Update 20 sec field is marked Exitin...

Page 386: ...the indicated address number Diff Adap fact 5620 The matching factor of the current transformers for the differential protection is too great or too small 2 1 4 2 2 Diff err Set 5623 Differential protection setting not plausible 2 2 REF not avail 5835 Restricted earth fault protection is not available for the configured protected object 2 1 4 REF Adap fact 5836 The matching factor of the current t...

Page 387: ...ssignment possible for single phase time overcurrent protection 2 1 4 O C 1Ph err Set 200 2493 Settings for single phase time overcurrent protection is not plausible 2 7 I2 Not avail 5172 Unbalanced load protection is not available for the configured pro tected object 2 1 4 I2 Adap fact 5168 The matching factor of the current transformers for unbalanced load protection is too great or too small 2 ...

Page 388: ...lable without voltage connection 2 15 U err Set 034 2493 Overvoltage protection setting not plausible 2 15 Freq err Obj 5255 Frequency protection is not available for the configured protected object 2 16 Freq error VT 5254 Frequency protection is not available without voltage connection 2 16 Freq err Set 5256 Frequency protection setting not plausible 2 16 Pr obj error 5101 Reverse power protectio...

Page 389: ...breakers are interrupted The tests should be done with the current setting values of the device If these are not yet available the test should be done with the preset values Message No Description see section Gen CT M1 to Gen CT M5 30060 to 30064 General Magnitude matching factor at the indicated measuring location 2 1 4 Gen VT U1 30065 General Magnitude matching factor of 3 phase voltage input 2 ...

Page 390: ...y only be performed for a short time See Technical Data Afterwards the device has to cool off Set pickup values refer to symmetrical three phase currents for three phase protected objects For single phase transformers the currents are presumed at phase opposi tion With single phase busbar protection the summation transformers are to be con sidered if applicable The rated currents of the measured c...

Page 391: ...gh voltage winding In this case the rated current of the winding is practically equal to the current trans former rated current Thus the pickup value referred to the rated relay current com plies with the setting value I DIFF of the device kVG 1 for reference winding For single phase testing with zero sequence current elimination a pickup value 1 5 times higher must be expected The following appli...

Page 392: ...t test currents are fed into the current input i e one after the other those that are relevant to the tested flexible functions For functions working on exceeding currents a slowly increased test current is applied until the func tion trips Value undershooting above a pickup value it is decreased Keep in mind that the corresponding message can be delayed if a time delay is set Caution Tests with c...

Page 393: ...iderations are applicable which will still be given For functions working on exceeding voltages slowly increased test voltage is applied until the function trips Value undershooting above a pickup value it is de creased Keep in mind that the corresponding message can be delayed if a time delay is set Caution Tests with voltages that exceed more than 170 V at the voltage input terminals cause an ov...

Page 394: ...and the currents fed into those current measuring inputs that the voltages are assigned according to Section 2 1 4 under Assignment of Voltage Measuring Inputs Important for the load direction and signs the polarity of the test quantities setting of the polarity for the current measuring location side in the test according to polarity setting e g Address 511 STRPNT OBJ M1 for measuring location 1 ...

Page 395: ...rcuit breaker of the feeder to be tested at both ends i e line disconnectors and busbar disconnectors should be open so that the breaker can be operated without risk Caution Also for tests on the local circuit breaker of the feeder a trip command to the surround ing circuit breakers can be issued for the busbar Non observance of the following measure can result in minor personal injury or prop ert...

Page 396: ... both sides are open Start by trip command of the external protection Binary input CBF Start No 1431 in the spontaneous or fault annunciations Following initiation the annunciation CBF Pup external No 1457 must appear in the fault annunciations trip log or in the spontaneous annunciations With two stage breaker failure protection the trip repetition command to the local circuit breaker is issued a...

Page 397: ...d is 115 kBaud The following descriptions refer to read out of measured values with DIGSI All mea sured values can be read out from the device Preparation of Sym metrical Current Tests At first commissioning current checks must be performed before the protected object is energised for the first time This ensures that the differential protection is operative as a short circuit protection during the...

Page 398: ...es are on the lower voltage side Figure 3 25 Test installation with low voltage source example for transformer and motor On power station unit transformers and synchronous machines the checks are per formed during the current tests with the generator itself supplying the test current The current is produced by a short circuit bridge which is installed outside the protected zone and is capable of c...

Page 399: ...ing or the measuring loca tion example IL1 S1 current in phase L1 on side S1 IL1 M1 current in phase L1 at the measuring location M1 The following procedure applies to a three phase protected object for measuring loca tion M1 against measuring location M2 For transformers it is assumed that measuring location 1 is assigned to side 1 and this is the high voltage side of the transformer The other po...

Page 400: ...rce and the protected object shut down the generator and earth it Re check the assignment or the tested measuring location Section 2 1 4 under margin heading Assignment of 3 phase measuring locations Re check the settings for the magnitude matching Subsection 2 1 4 under margin heading Current Transformer Data for 3 phase Measuring Locations Re check the plant connections to the device and the tes...

Page 401: ...ways the currents flowing into the protected object are defined as positive That means that with through flowing in phase currents the currents leaving the protected object at measuring location M2 have reversed polarity 180 phase displacement against the corresponding in flowing currents at measuring lo cation M1 Exception With transverse differential protection the currents of the corresponding ...

Page 402: ...errors are assumed Switch off the test source and the protected object shut down the generator and earth it Re check the plant connections to the device and the test arrangement and correct them Check also the corresponding setting for the CT data Repeat test and re check the current angles All pre described test must be repeated until every measuring location of the main pro tected object has bee...

Page 403: ...n s under test For generators motors reactors addresses 361 and 362 under Object Data with Generators Motors or Reactors and addresses 512 and 513 for measur ing location 1 under Current Transformer Data for 3 phase Measuring Loca tions and accordingly the parameters for the other measuring location s under test For mini busbars 3 phase address 372 under Object Data with Mini Busbars or Short Line...

Page 404: ...t is not avail able then the zero sequence current tests serve for verification of the correct process ing of the zero sequence currents in the differential protection Note It must be taken into consideration that tripping may occur if connections were made wrong Preparation of Zero Sequence Current Tests Zero sequence current measurements are always performed from that side or three phase measuri...

Page 405: ...s voltage free and earthed Perilous voltages may occur even on voltage free plant sections due to capacitive influence caused by other live sections Figure 3 29 Zero sequence current measurement on a star delta transformer without in clusion of the starpoint current Figure 3 30 Zero sequence current measurement on a star delta transformer ...

Page 406: ...60 2 Figure 3 31 Zero sequence current measurement on a star star transformer with compen sation winding Figure 3 32 Zero sequence current measurement on an auto transformer with compensa tion winding Figure 3 33 Zero sequence current measurement on a zig zag winding ...

Page 407: ...ence current measurement on a delta winding with neutral earthing reactor within the protected zone Figure 3 35 Zero sequence current measurement on an earthed series reactor reactor generator motor Figure 3 36 Zero sequence current measurement on an earthed single phase transformer ...

Page 408: ... test source and the protected object shut down the generator and earth it Re check the assignment or the tested 1 phase input subsection 2 1 4 under margin heading Assignment of Auxiliary 1 phase Measuring Locations Re check the settings for the magnitude matching Subsection 2 1 4 under margin heading Current Transformer Data for 1 phase Auxiliary Current In puts Check the plant connections to th...

Page 409: ...ifferential currents occur re check the settings for the starpoints Starpoint conditioning of a transformer addresses 313 STARPNT SIDE 1 323 STARPNT SIDE 2 etc depending on the tested winding Section 2 1 4 margin heading Object Data with Transformers as well as the assignment of the starpoint current transformer to the 1 phase current input under test address 251 252 etc depending on the input und...

Page 410: ... L3 are shown in the following figures Single phase primary tests are to be preferred since they evoke clearer differences in the measured currents They also detect connecting errors in the earth current path The measured current to be read out in the operational measured values only corre sponds to the testing current if three phase symmetrical check is performed In other cases there are deviatio...

Page 411: ...ransformers before disconnecting any current supply leads to the device Figure 3 39 Asymmetrical test with summation transformer connection L1 L3 E The measured current is now 2 65 times the current of the symmetrical test This test must be carried out for each summation CT 3 3 11 Testing of the Non Assigned 1 Phase Current Inputs As far as single phase current inputs belong to the main protected ...

Page 412: ...n checks Each current transformer must be in cluded into a measurement The measured current must not exceed for each through current test half of the pickup value of the single phase time overcurrent protection 3 3 12 Checking the Voltage Connections and Polarity Check Voltage and Phase Sequence Check If the device is connected to voltage transformers these connections are checked using primary va...

Page 413: ...after switching off the measuring location If the phase difference angle between two voltages is 60 instead of 120 one voltage must be polarity reversed The same applies if there are phase to phase voltages which almost equal the phase to earth voltages instead of having a value that is 3 greater The measurements are to be repeated after setting the connections right In general the phase rotation ...

Page 414: ...imary tests are preferred as secondary tests cannot prove the correct polarity A load current of at least 5 of the rated operational current is required Any direction is possible but must be known In a first step check whether power measurement is carried out at the desired mea suring location i e that the assignment of the 3 phase voltage transformer set is made correct The powers are always calc...

Page 415: ...in network applications e g during network coupling or load shedding Errors may not be ignored during the determination of active and reactive power or electrical active and reactive energy Especially where reverse power protection with highly accurate active power measurement is used a correction of the angle error of the involved current and voltage transformer is inevitable Here in case of low ...

Page 416: ...olarity negative sign in the operational mea sured values under and write it down see figure below Read out the reactive power Q1 with polarity positive sign and write it down see table in the figure below If possible reduce excitation to approximately 0 3 times rated apparent power of generator underexcited Caution Under excitation may cause the generator fall out of step Read the motoring power ...

Page 417: ...in address 5011 in Watt or 5012 referred to the nominal current of the generator to a quarter of the sum of the read out measured values P1 and P2 also with negative sign Because of possible leakages in the valves the reverse power test should be per formed with emergency tripping Start up generator and synchronise with network if not yet done Close stop valve From the operational measured value f...

Page 418: ...r example via the binary input when the protection object is energized An oscillographic recording that is externally triggered that is without a protective element pickup or device trip is processed by the device as a normal oscillographic recording and has a number for establishing a sequence However these recordings are not displayed in the fault indication buffer as they are not fault events S...

Page 419: ...ions as to the effectiveness of the inrush restraint can be drawn from the re cording of the differential currents and the harmonic contents If necessary the inrush current restraint effect can be increased smaller value of the 2nd harmonic in address 1271 2 HARMONIC when trip occurs or when the recorded data show that the second harmonic content does not safely exceed the restraining threshold ad...

Page 420: ...tem Description 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 reset under Main Menu Measureme...

Page 421: ...urrents 442 4 5 Time Overcurrent Protection for Earth Current Starpoint Current 453 4 6 Dynamic Cold Load Pickup for Time Overcurrent Protection 455 4 7 Single Phase Time Overcurrent Protection 456 4 8 Unbalanced Load Protection 457 4 9 Thermal Overload 465 4 10 RTD Boxes for Overload Detection 468 4 11 Overload Protection 469 4 12 Reverse Power Protection 471 4 13 Forward active power supervision...

Page 422: ... 1 s 30 IN for 10 s 4 IN continuous dynamic pulse current 250 IN half cycle Current overload capability for high sensitivity input thermal rms 300 A for 1 s 100 A for 10 s 15 A continuous dynamic pulse current 750 A half cycle Secondary Nominal Voltage 80 V to 125 V Measuring Range 0 V to 200 V Power Consumption At 100 V Approx 0 3 VA Voltage path overload capacity thermal RMS 230 V continuous Vol...

Page 423: ...Power consumption energized 7UT613 7UT633 7UT635 Approx 19 VA Approx 28 VA Bridging time for failure short circuit of the power supply 50 ms Device 7UT613 7UT633 7UT635 Number 5 allocatable 21 allocatable 29 allocatable Rated Voltage 24 to 250 VDC in 2 ranges bipolar Current consumption picked up independent of the operating voltage approx 1 8 mA per binary input Switching thresholds Adjustable wi...

Page 424: ... A for 0 5 s NO contact Permissible total current on common paths 5 A continuous 30 A for 0 5 s NO contact Pick up times Make contact high speed 5 ms Changeover contact 8 ms High speed only make contact 2 1 ms 2 for order option 7UT633 7UT635 1 UL listed with the following rated data 120 VAC Pilot duty B300 240 VAC Pilot duty B300 240 VAC 5 A General Purpose 24 VDC 5 A General Purpose 48 VDC 0 8 A...

Page 425: ... connection of a RTD box RS232 Connection for flush mounted housing rear panel mounting location C 9 pole DSUB port shielded data cable Connector for surface mounted housing in inclined housing on the case bottom shielded data cable Test Voltage 500 V 50 Hz Transmission speed min 4 800 Bd max 115 200 Bd Factory 38 400 Baud Maximum bridgeable distance 15 m RS485 Connection for flush mounted housing...

Page 426: ...5 103 RS232 RS485 FOC Profibus RS485 Profibus FOC acc to ordered version Isolated interface for data transfer to a master terminal IEC 60870 5 103 different isolated neutral versions available RS232 rear panel mounting loca tion B 9 pole DSUB miniature socket Connection for flush mounted housing Connection for surface mounted case in the inclined housing on the case bottom Test voltage 500 V 50 Hz...

Page 427: ...7 5 kBd 200 m 660 ft at 1 5 MBd PROFIBUS FOC FMS and DP ST connector with FMS Single or double ring according to order with DP only double ring available FOC connector type Connection for flush mounted case only with external OLM rear panel mounting location B Connection for surface mounted case only with external OLM in the inclined housing on the case bottom Transmission speed recommended up to ...

Page 428: ...case bottom Test Voltage 500 V 50 Hz Transmission speed Up to 19 200 Baud Maximum bridgeable distance 1 km MODBUS FO ST connector transmit ter receiver FOC connector type Connection for flush mounted housing Rear panel mounting location B Connector for surface mounted housing only with external converter in the inclined housing on the case bottom Transmission speed Up to 19 200 Baud optical wavele...

Page 429: ...panel mounting location C 9 pole DSUB port Connection for surface mounted case in the inclined housing on the case bottom Test voltage 500 V 50 Hz Transmission speed 9 600 Bd Maximum bridgeable distance 1 000 m 3300 ft Optical fibre FO FO connector type ST connector Connection for flush mounted case Rear panel mounting location B Connection for surface mounted case in the inclined housing on the c...

Page 430: ...EC 60870 2 1 High voltage test routine test all circuits except power supply binary inputs and communication time sync interfaces 2 5 kV rms 50 Hz High voltage test routine test auxiliary voltage and binary inputs 3 5 kV High voltage test routine test only isolated communication and time syn chronisation interfaces and time synchronisation interfaces 500 V rms 50 Hz Impulse voltage test type test ...

Page 431: ...on mode 2 kV 42Ω 0 5 µF diff mode 1 kV 42Ω 0 5 µF Line conducted HF amplitude modulated IEC 61000 4 6 Class III 10 V 150 kHz to 80 MHz 80 AM 1 kHz Power system frequency magnetic field IEC 61000 4 8 Class IV IEC 60255 6 30 A m continuous 300 A m for 3 s 50 Hz 0 5 mT 50 Hz Oscillatory surge withstand capability IEEE Std C37 90 1 2 5 kV peak value 1 MHz τ 15 µs 400 pulses per s test duration 2 s Ri ...

Page 432: ...to 8 Hz 1 5 mm amplitude vertical axis 8 Hz to 35 Hz 1 g acceleration horizontal axis 8 Hz to 35 Hz 0 5 g acceleration vertical axis frequency sweep rate 1 octave min 1 cycle in 3 orthogonal axes Standards IEC 60255 21 and IEC 60068 Oscillation IEC 60255 21 1 Class 2 IEC 60068 2 6 sinusoidal 5 Hz to 8 Hz 7 5 mm amplitude 8 Hz to 150 Hz 2 g acceleration frequency sweep rate 1 octave min 20 cycles i...

Page 433: ...se condensation to occur The device is designed for use in an industrial environment or an electrical utility environment for installation in standard relay rooms and compartments so that proper installation and elec tromagnetic compatibility EMC is ensured In addition the following is recommended All contacts and relays that operate in the same cubicle cabinet or relay panel as the nu merical pro...

Page 434: ...face mounted housing size 1 1 1 In flush mounted housing size 1 1 22 0 kg 48 5 lb 25 3 kg 55 8 lb 13 8 kg 30 4 lb 7UT635 In surface mounted housing size 1 1 In surface mounted housing size 1 1 1 In flush mounted housing size 1 1 22 7 kg 50 lb 26 0 kg 57 3 lb 14 5 kg 32 lb Degree of protection acc to IEC 60529 For the device in surface mounted housing IP 51 For the device in flush mounted housing F...

Page 435: ...p value when connect ing as a factor of IDiff 1 0 to 2 0 Steps 0 1 Add on restraint on external fault Istab setting value Action time IAdd on INObj 2 00 to 15 00 2 to 250 cycles or active until dropout Steps 0 01 Increments 1 cycle Trip characteristic see Figure 4 1 Tolerances with preset characteristic parameters for 2 sides with 1 measuring location each IDiff stage and characteristic 5 of set v...

Page 436: ...i vated Max action time for crossblock 2 to 1000 AC cycles or 0 crossblock deactivat ed or active until dropout Steps 1 cycle Pickup time dropout time with single side infeed Pickup time at frequency 50 Hz 60 Hz 16 7 Hz IDiff min high speed relays 30 ms 27 ms 78 ms high speed relays 25 ms 22 ms 73 ms IDiff min high speed relays 11 ms 11 ms 20 ms high speed relays 6 ms 6 ms 15 ms Dropout time appro...

Page 437: ...ual C53000 G1176 C160 2 Figure 4 2 Restraining influence of 2nd harmonic in transformer differential protection Idiff differential current I1 I2 INObj Rated current of protected object IfN Current at rated frequency I2f Current at double frequency ...

Page 438: ...iff differential current I1 I2 INObj Nominal current of protected object IfN Current at nominal frequency Inf Current at n times the frequency n 3 or 4 Figure 4 4 Frequency influence in transformer differential protection Idiff Differential current I1 I2 INObj Nominal current of the protected object IXf Current at any frequency within specified range ...

Page 439: ...gle side infeed Pickup time at frequency 50 Hz 60 Hz 16 7 Hz IDiff min high speed relays 30 ms 27 ms 78 ms high speed relays 25 ms 22 ms 73 ms IDiff min high speed relays 11 ms 11 ms 20 ms high speed relays 6 ms 6 ms 15 ms Dropout time approx 54 ms 46 ms 150 ms Dropout ratio approx 0 7 Frequency influence within the frequency tagging range see Figure 4 5 Note Higher tolerances must be expected if ...

Page 440: ... feeder current guard I Guard INObj 0 20 to 2 00 or 0 always released Steps 0 01 Pickup time dropout time with single side infeed Pickup time at frequency 50 Hz 60 Hz 16 7 Hz IDiff min high speed relays 11 ms 11 ms 18 ms high speed relays 6 ms 6 ms 13 ms IDiff min high speed relays 11 ms 11 ms 18 ms high speed relays 6 ms 6 ms 13 ms Dropout time approx 54 ms 46 ms 150 ms Dropout ratio approx 0 7 F...

Page 441: ... fixed Trip characteristic see Figure 4 6 Pickup tolerance with preset characteristic parameters and one 3 phase measuring location 5 at I 5 IN Time delay TREF 0 00 s to 60 00 s or no trip Steps 0 01 s Time tolerance 1 of set value or 10 ms The set times are pure delay times Pickup time at frequency 50 Hz 60 Hz 16 7 Hz at 1 5 set value IREF approx high speed relays 35 ms 30 ms 110 ms high speed re...

Page 442: ...ctive Steps 0 01 A T3I0 0 00 s to 60 00 s or no trip Steps 0 01 s Definite time current elements 50Ns 2 50Ns 1 IPh 0 10 A to 35 00 A1 or ineffective Steps 0 01 A TIPh 0 00 s to 60 00 s or no trip Steps 0 01 s 3I0 0 10 A to 35 00 A1 or ineffective Steps 0 01 A T3I0 0 00 s to 60 00 s or no trip Steps 0 01 s Inverse current elements 51Ns IEC IP 0 10 A to 4 00 A1 Steps 0 01 A TIP 0 05 s to 3 20 s or n...

Page 443: ...e at frequency 50 Hz 60 Hz 16 7 Hz without inrush restraint min 11 ms 11 ms 16 ms with inrush restraint min 33 ms 29 ms 76 ms Dropout time approx 35 ms 35 ms 60 ms Pickup time dropout time residual current stages Pickup time at frequency 50 Hz 60 Hz 16 7 Hz without inrush restraint min 1 21 ms 19 ms 46 ms with inrush restraint min 1 31 ms 29 ms 56 ms Dropout time approx 45 ms 43 ms 90 ms 1 for hig...

Page 444: ...o those for I Ip 20 For residual current read 3I0p instead of Ip and T3I0p instead of Tp for earth faults read IEp instead of Ip and TIEp instead of Tp Pickup Threshold approx 1 10 Ip Acc to IEC 60255 3 or BS 142 Section 3 5 2 see also Figure and 4 8 The reset time characteristics apply to I Ip 0 90 For residual current read 3I0p instead of Ip and T3I0p instead of Tp for earth faults read IEp inst...

Page 445: ... 4 Time Overcurrent Protection for Phase and Residual Currents 445 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 7 Dropout time and trip time curves of the inverse time overcurrent protection as per IEC ...

Page 446: ...4 Technical Data 446 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 8 Dropout time and trip time curves of the inverse time overcurrent protection acc to IEC ...

Page 447: ...2 Trip Time Curves acc to ANSI Acc to ANSI IEEE see also Figures 4 9 to 4 12 The tripping times for I Ip 20 are identical to those for I Ip 20 For residual current read 3I0p instead of Ip and T3I0p instead of Tp for earth faults read IEp instead of Ip and TIEp instead of Tp Pickup Threshold approx 1 10 Ip ...

Page 448: ...opout Time Curves as per ANSI IEEE Acc to ANSI IEEE see also Figures 4 9 to 4 12 The reset time characteristics apply to I Ip 0 90 For residual current read 3I0p instead of Ip and T3I0p instead of Tp for earth faults read IEp instead of Ip and TIEp instead of Tp ...

Page 449: ...Time Overcurrent Protection for Phase and Residual Currents 449 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 9 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE ...

Page 450: ...4 Technical Data 450 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 10 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE ...

Page 451: ...ime Overcurrent Protection for Phase and Residual Currents 451 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 11 Dropout time and trip time curves of the inverse time overcurrent protection acc to ANSI IEEE ...

Page 452: ...4 Technical Data 452 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 12 Dropout time and trip time curve of the inverse time overcurrent protection acc to ANSI IEEE ...

Page 453: ...0 s to 60 00 s or no trip Steps 0 01 s Definite time current element 50Ns 2 50Ns 1 IE 0 05 A to 35 00 A1 or ineffective Steps 0 01 A TIE 0 00 s to 60 00 s or no trip Steps 0 01 s Inverse current element 51Ns IEC IEP 0 05 A to 4 00 A1 Steps 0 01 A TIEP 0 05 s to 3 20 s or no trip Steps 0 01 s Inverse current element 51Ns ANSI IEP 0 05 A to 4 00 A1 Steps 0 01 A DIEP 0 50 s to 15 0 s or no trip Steps...

Page 454: ...ms with inrush restraint min 1 33 ms 29 ms 76 ms Dropout time approx 35 ms 35 ms 60 ms 1 for high speed relays the pick up times decrease by 4 5 ms Current stages approx 0 95 for I IN 0 5 Inrush restraint ratio 2nd harmonic I2fN IfN 10 to 45 Steps 1 Lower operation limit I 0 2 A 1 Max current for restraint 0 30 A to 25 00 A1 Steps 0 01 A 1 Secondary values for IN 1 A for IN 5 A the currents must b...

Page 455: ...ry input from circuit breaker auxiliary contact or current criterion of the assigned side CB open time TCB open 0 s to 21600 s 6 h Steps 1 s Action time TAction time 1 s to 21600 s 6 h Steps 1 s Accelerated dropout time TStop Time 1 s to 600 s 10 min or no accelerated dropout Steps 1 s Dynamic parameters of pickup currents and delay times or time multipliers Setting ranges and steps are the same a...

Page 456: ...Steps 0 01 s Tolerances currents 3 of setting value or 1 rated current for IN 1 A or 5 A 5 of setting value or 3 rated current for IN 0 1 A times 1 of set value or 10 ms The set times are pure delay times 1 Secondary values for IN 1 A for IN 5 A the currents must be multiplied by 5 2 Secondary values for sensitive measurement input irrespective of nominal current Pickup time dropout time for frequ...

Page 457: ...A1 Steps 0 01 A TI2 0 00 s to 60 00 s or no trip Steps 0 01 s Inverse current element 51Ns IEC I2P 0 10 A to 2 00 A1 Steps 0 01 A TI2P 0 05 s to 3 20 s or no trip Steps 0 01 s Inverse current element 51Ns ANSI I2P 0 10 A to 2 00 A1 Steps 0 01 A DI2P 0 50 s to 15 00 s or no trip Steps 0 01 s Tolerances with inverse time 2 currents 3 of setting value or 1 nominal current times 1 of setting value or ...

Page 458: ...igure 4 13 Trip times of the Thermal Characteristic for Unbalanced Load Protection Pickup time dropout time Pickup time at frequency 50 Hz 60 Hz 16 7 Hz minimum 1 41 ms 34 ms 106 ms Dropout time approx 23 ms 20 ms 60 ms 1 for high speed relays the pick up times decrease by 4 5 ms Current stages approx 0 95 for I2 IN 0 5 Frequency influence within the frequency tagging range ...

Page 459: ...ping characteristics displayed on the right hand side of Figures 4 14 and 4 15 can be selected The trip times for I2 I2p 20 are identical to those for I2 I2p 20 Pickup Threshold approx 1 10 I2p For illustrations of possible reset time characteristics see figures 4 14 and 4 15 on the left hand side The dropout time characteristics apply to the range 0 05 I2 I2p 0 90 ...

Page 460: ...4 Technical Data 460 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 14 Dropout time and trip time characteristics of the inverse time unbalanced load stage as per IEC ...

Page 461: ...time characteristics of the inverse time unbalanced load stage as per IEC Trip Time Curves acc to ANSI One of the tripping curves depicted in the figures 4 16 and 4 17 on the right hand side may be selected The tripping times for I2 I2p 20 are identical to those for I2 I2p 20 Pickup Threshold Approx 1 10 I2p ...

Page 462: ... Manual C53000 G1176 C160 2 Reset Curves with Disk Emulation according to ANSI For illustrations of possible reset time characteristics see figures 4 16 and 4 17 on the left hand side The dropout times constants apply to I2 I2p 0 90 ...

Page 463: ...4 8 Unbalanced Load Protection 463 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 16 Dropout time and trip time characteristics of the inverse time unbalanced load stage acc to ANSI ...

Page 464: ...4 Technical Data 464 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 17 Dropout time and trip time characteristics of the inverse time unbalanced load stage acc to ANSI ...

Page 465: ...arm stage IAlarm 0 10 to 4 00 A 1 Steps 0 01 A Start up recognition Imotor startup 0 60 to 10 00 A 1 or no start up recogni tion Steps 0 01 A Emergency start run on time TRun on 10 s to 15000 s Steps 1 s 1 Secondary values based on IN 1 A for IN 5 A the currents must be multiplied by 5 Θ ΘOFF Dropout with ΘAlarm Θ ΘAlarm approx 0 99 I IAlarm approx 0 97 For one 3 phase measuring location relating ...

Page 466: ...teristic Figure 4 18 Trip time characteristic of thermal overload protection τ Tripping time τ Thermal time constant I Load current Ipre Previous load current k Setting factor according to IEC 60255 8 INom Rated current of protected object Frequency in range 0 9 f fN 1 1 1 at fN 50 60 Hz 3 at fN 16 7 Hz ...

Page 467: ...ion one temperature detector must be connected Cooling method ON oil natural OF oil forced OD oil directed Oil exponent Y 1 6 to 2 0 Steps 0 1 Hot spot to top oil gradient Hgr 22 to 29 Steps 1 Warning temperature hot spot or 98 C to 140 C 208 F to 284 F Steps 1 C Increments 1 F Alarm temperature hot spot or 98 C to 140 C 208 F to 284 F Steps 1 C Steps 1 F Warning ageing rate 0 125 to 128 000 Steps...

Page 468: ...or Stator or Bearing or Other Number of measuring points Max 12 temperature measuring points Temperature unit C or F settable Measuring range For Pt 100 For Ni 100 For Ni 120 199 C to 800 C 326 F to 1472 F 54 C to 278 C 65 F to 532 F 52 C to 263 C 62 F to 505 F Resolution 1 C or 1 F Tolerance 0 5 of measured value 1 digit For each measuring point Stage 1 58 F to 482 F or 50 C to 250 C or no indica...

Page 469: ...haracteristic t U f 1 s to 20 000 s Steps 1 s Time for cool down TCOOL DOWN 1 s to 20 000 s Steps 1 s Pickup dropout times of warning stage and stepped characteristic Pickup time at frequency 50 Hz 60 Hz 16 7 Hz Minimum 36 ms 31 ms 91 ms Dropout time approx 36 ms 23 ms 70 ms Dropout Pickup approx 0 95 Thermal replica and stepped characteristic For default settings see Figure 4 19 U f pickup 3 of s...

Page 470: ...4 Technical Data 470 7UT613 63x Manual C53000 G1176 C160 2 Figure 4 19 Resulting tripping characteristic from thermal replica and stepped characteristic of the overexcitation protection default settings ...

Page 471: ...7 Hz with high speed measurement approx 30 ms at f 50 Hz approx 30 ms at f 60 Hz approx 70 ms at f 16 7 Hz Dropout Times Reverse Power Prev with high accuracy measurement approx 330 ms at f 50 Hz approx 310 ms at f 60 Hz approx 970 ms at f 16 7 Hz with high speed measurement approx 30 ms at f 50 Hz approx 30 ms at f 60 Hz approx 70 ms at f 16 7 Hz Reverse power Preverse approx 0 6 Reverse power Pr...

Page 472: ...nt approx 330 ms at f 50 Hz approx 310 ms at f 60 Hz approx 970 ms at f 16 7 Hz with high speed measurement approx 30 ms at f 50 Hz approx 30 ms at f 60 Hz approx 70 ms at f 16 7 Hz Dropout times active power P P with high accuracy measurement approx 330 ms at f 50 Hz approx 310 ms at f 60 Hz approx 970 ms at f 16 7 Hz with high speed measurement approx 30 ms at f 50 Hz approx 30 ms at f 60 Hz app...

Page 473: ...ual C53000 G1176 C160 2 Influencing Variables for Pickup Values Power supply direct voltage in range 0 8 UH UHN 1 15 1 Temperature in range 5 C Θ amb 55 C 0 5 10 K Frequency in range 0 95 f fN 1 05 1 Harmonics up to 10 3rd harmonic up to 10 5th harmonic 1 1 ...

Page 474: ...01 to 1 20 Increments 0 01 Time Delays T U T U 0 00 s to 60 0 s or disabled Increments 0 01 s The set times are pure delay times with definite time protection Pick up times 50 60 Hz approx 30 ms 16 7 Hz approx 70 ms Dropout times 50 60 Hz approx 30 ms 16 7 Hz approx 70 ms Pickup VoltagesU U 1 of setting value or 0 5 V Delay Times T 1 of setting values or 10 ms Power supply direct voltage in range ...

Page 475: ...ys T U T U 0 00 s to 60 00 s or disabled Increments 0 01 s The set times are pure delay times with definite time protection Pick up times U U 50 60 Hz approx 30 ms 16 7 Hz approx 70 ms Dropout TimesU U 50 60 Hz approx 30 ms 16 7 Hz approx 70 ms Voltage Limits 1 of setting value or 0 5 V Delay Times T 1 of setting values or 10 ms Power supply direct voltage in range 0 8 UH UHN 1 15 1 Temperature in...

Page 476: ... can be set to f f f or f Pickup values f f f Nominal frequency 50 Hz 40 00 to 49 99 Hz or 0 disabled Nominal frequency 60 Hz 50 00 to 59 99 Hz or 0 disabled Nominal frequency 16 7 Hz 10 00 to 16 69 Hz or 0 disabled Pickup value f Nominal frequency 50 Hz 50 01 to 66 00 Hz or disabled Nominal frequency 60 Hz 50 00 to 59 99 Hz or disabled Nominal frequency 16 7 Hz 10 00 to 16 69 Hz or disabled Delay...

Page 477: ...io for Undervoltage Blocking approx 1 10 Frequencies f f Undervoltage blocking Delay times T f f 10 mHz at U UN f fN 1 of the setting value or 0 5 V 1 of the setting value or 10 ms Power supply direct voltage in range 0 8 UH UHN 1 15 1 Temperature in range 5 C Θ amb 55 C 0 5 10 K Harmonics up to 10 3rd harmonic up to 10 5th harmonic 1 1 ...

Page 478: ...t breaker auxiliary contacts and binary input 1 Secondary values based on IN 1 A for IN 5 A the currents must be multiplied by 5 For breaker failure protection internal trip external trip via binary input Pickup time for fN 50 60 Hz approx 3 ms with measured quantities approx 20 ms after switch on of measured quantities Pickup time for fN 16 7 Hz approx 60 ms after switch on of measured quantities...

Page 479: ...irect Tripping Transformer Annunciations Number 2 Operating Time approx 12 5 ms min approx 25 ms typical Dropout time approx 25 ms Delay time 0 00 s to 60 00 s Steps 0 01 s Time tolerance 1 of set value or 10 ms The set times are pure delay times External annunciations Buchholz warning Buchholz tank Buchholz tripping ...

Page 480: ...U 0 58 to 0 90 Increments 0 01 BALANCE I LIMIT 10 V to 100 V Increments 1 V Voltage sum if voltages applied UL1 UL2 UL3 kU Uen 25 V Current phase sequence IL1 leads IL2 leads IL3 if clockwise IL1 leads IL3 leads IL2 if counter clockwise if IL1 IL2 IL3 0 5 IN Voltage phase sequence if voltages applied UL1 leads UL2 leads UL3 if clockwise UL1 leads UL3 leads UL2 if counter clockwise if UL1 UL2 UL3 4...

Page 481: ...EL Cancel command X X X X CMD_CHAIN Switching Sequence X X CMD_INF Command Information X COMPARE Measured value compari son 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_STA...

Page 482: ...r restart X X X X ST_AND AND gate with status X X X X ST_NOT Negator with status X X X X ST_OR OR gate with status X X X X SUB Substraction X X X X TIMER Timer X X TIMER_SHORT Simple timer X X UINT_TO_REAL U Int to real adapter X X X X UPPER_SETPOINT Upper Limit X X_OR XOR Gate X X X X ZERO_POINT Zero Supression X Designation Limit Comments Maximum number of all CFC charts considering all task lev...

Page 483: ...number of unequal information items of the left border per task level 400 Only fault annunciation record in device fault log here the number of elements of the left border per task level is counted Since the same information is indicated at the border several times only unequal infor mation is to be counted Maximum number of reset resistant flipflops D_FF_MEMO 350 When the limit is exceeded an err...

Page 484: ...rom the 3rd additional input for generic blocks 1 Connection to an input signal 6 Connection to an output signal 7 Additional for each chart 1 Switching Sequence CM_CHAIN 34 Status Memory for Restart D_OFF_MEMO 6 Feedback Loop LOOP 8 Decode Double Point DM_DECODE 8 Dynamic OR D_OR 6 Addition ADD 26 Substraction SUB 26 Multiplication MU 26 Division IV 54 Root Extractor SQUARE_ROOT 83 ...

Page 485: ... 500 A Increment 0 001 A Current IZ1 IZ4 for IN 1 A 0 05 to 35 00 A Increment 0 01 A for IN 5 A 0 25 to 175 00 A Current IZ3 IZ4 for sensitive CT 0 001 to 1 500 A Increment 0 001 A Voltage U U4 1 0 to 170 0 V Increment 0 1 V Power P for IN meas pt 1 A 1 7 to 3000 0 W Increment 0 1 W for IN meas pt 5 A 8 5 to 15 000 0 W for side 0 01 to 17 00 P SnS Increment 0 01 P SnS Power Q for IN meas pt 1 A 1 ...

Page 486: ...wer Measuring procedure high accuracy Measuring procedure high speed 120 ms 100 ms 330 ms 300 ms Power Factor Measuring procedure high accuracy Measuring procedure high speed 120 ms 100 ms 400 ms 250 ms Frequency 150 ms 500 ms Pickup thresholds Current 3 of setting value or 1 nominal current Voltage 1 of setting value or 0 5 V Power 0 25 SN 3 of setting value with high accuracy measurement 0 5 SN ...

Page 487: ... sensitive current inputs in A primary and mA secondary Tolerance 1 of measured value or 2 mA Phase angle currents 3 phase for each measuring loca tion ϕ IL1 ϕ IL2 ϕ IL3 in referred to ϕ IL1 Tolerance 1 at rated current Phase angle currents 1 phase ϕ I1 to ϕ I12 or ϕ IZ1 to ϕ IZ4 in referred to ϕ I1 Tolerance 1 at rated current Operational values for volt ages 3 phase if voltage connected UL1 E UL...

Page 488: ... tolerances are to be expected for calculated values dependent on the matching factors for currents and voltages Measured values of differ ential protection IdiffL1 IdiffL2 IdiffL3 IrestL1 IrestL2 IrestL3 in of the operational nominal current Tolerance with preset values for 2 sides with 1 measuring location each 2 of measured value or 2 IN 50 60 Hz 3 of measured value or 3 IN 16 7 Hz Measured val...

Page 489: ...ow 5 15 30 or 60 minutes Frequency of Updates adjustable Long Term Averages currents active power reactive power apparent power IL1dmd IL2dmd IL3dmd I1dmd in A kA Pdmd in W kW MW Qdmd in VAr kVAr MVAr Sdmd in VAr kVAr MVAr Storage of Measured Values With date and time Reset automatic Time of day adjustable in minutes 0 to 1439 min time frame and starting time adjustable in days 1 to 365 days and i...

Page 490: ...C 60870 5 103 External using system interface IEC 61850 External synchronisation via the system inter face IEC 61850 Time signal IRIG B External via IRIG B telegram format IRIG B800 Time signal DCF 77 External via time signal DCF 77 Time signal synchro box External using time signal SIMEAS Sync box Pulse via binary input External with impulse via binary input Operational measured values Circuit br...

Page 491: ...23 1 Panel Surface Mounting Enclosure Size 1 2 Figure 4 20 Dimensional drawing of a 7UT613 for panel flush mounting housing size 1 2 4 23 2 Panel Surface Mounting Enclosure Size 1 1 Figure 4 21 Dimensional drawing of a 7UT633 or 7UT635 for panel flush mounting housing size 1 1 ...

Page 492: ...ical Data 492 7UT613 63x Manual C53000 G1176 C160 2 4 23 3 Panel Surface and Cabinet Mounting Enclosure Size 1 2 Figure 4 22 Dimensions of a 7UT613 for panel flush mounting or cubicle mounting housing size 1 2 ...

Page 493: ...3 7UT613 63x Manual C53000 G1176 C160 2 4 23 4 Panel Surface and Cabinet Mounting Enclosure Size 1 1 Figure 4 23 Dimensions of a 7UT6 maximum functional scope for panel flush mounting or cubicle mounting housing size 1 1 ...

Page 494: ...4 Technical Data 494 7UT613 63x Manual C53000 G1176 C160 2 4 23 5 RTD box Figure 4 24 Dimensions of the Remote Temperature Detection Unit 7XV5662 AD10 0000 ...

Page 495: ...er connections of the devices to primary equipment in many typical power system configurations Tables with all set tings and all information available in this device equipped with all options are provided Default settings are also given A 1 Ordering Information and Accessories 496 A 2 Terminal Assignments 505 A 3 Connection Examples 523 A 4 Current Transformer Requirements 539 A 5 Default Settings...

Page 496: ...10 to 250 VDC 1 115 to 230 VAC binary input threshold 73 V 2 5 220 to 250 VDC 1 115 to 230 VAC Binary Input Threshold 154 V 1 2 6 Construction Housing Number of Binary Inputs and Outputs BI Binary Inputs BO Output Relays Pos 9 Surface mounting housing with two tier terminals 1 2 x 19 5 BI 8 BO 1 live status contact B Flush mounting housing 1 2 x 19 with plug in terminals 5 BI 8 BO 1 live status co...

Page 497: ... electrical RS485 4 Profibus FMS slave optical single ring ST connector 1 5 Profibus FMS slave optical double ring ST connector 1 6 For more interface options see Additional Specification L 9 Additional Specification L for Further System Interfaces device rear port B only if Pos 11 9 Pos 21 Pos 22 PROFIBUS DP Slave RS485 0 A Profibus DP Slave optical 820 nm double ring ST connector 1 0 B Modbus RS...

Page 498: ... overcurrent protection phases I I Ip inrush restraint overcurrent protection 3I0 3I0 3I0 3I0p inrush restraint overcurrent protection earth IE IE IEp inrush restraint A Differential protection Basic elements Ancillary functions Restricted earth fault protection Definite time single phase e g high impedance earth fault protection 87G without resistor or varistor 3 or tank leakage protection Unbala...

Page 499: ...urrent IN 1 A 1 Nominal current IN 5 A 5 Auxiliary voltage power supply pickup threshold of binary inputs Pos 8 DC 24 V to 48 V binary input threshold 17 V 2 2 60 to 125 VDC 1 binary input threshold 17 V 2 4 110 to 250 VDC 1 115 to 230 VAC binary input threshold 73 V 2 5 220 to 250 VDC 1 115 to 230 VAC binary input threshold 154 V 2 6 Construction Pos 9 Surface mounting housing with two tier termi...

Page 500: ...s FMS slave optical single ring ST connector 1 5 Profibus FMS slave optical double ring ST connector 1 6 For more interface options see Additional Specification L 9 Additional Specification L for Further System Interfaces device rear port B only if Pos 11 9 Pos 21 Pos 22 PROFIBUS DP Slave RS485 0 A Profibus DP slave optical 820 nm double ring ST connector 1 0 B Modbus RS485 0 D Modbus 820 nm optic...

Page 501: ...rotection phases I I Ip inrush restraint overcurrent protection 3I0 3I0 3I0 3I0p inrush restraint overcurrent protection earth IE IE IEp inrush restraint A Differential Protection Basic Functions Additional Functions1 Restricted earth fault protection Definite time single phase e g high impedance earth fault protection 87G without resistor or varistor 3 or tank leakage protection Unbalanced load p...

Page 502: ...0 0AN2 Matching summation current transformer IN 5 A 4AM5120 4DA00 0AN2 External Convert ers Profibus Modbus and DNP 3 0 are not possible with surface mounting housings Please order in this case a device with the appropriate electrical RS485 interface and the additional converters listed below Desired interface order device with Additional accessories Profibus FMS single ring Profibus FMS RS485 6G...

Page 503: ...20 nm C53207 A351 D633 1 Ethernet electrical EN100 C53207 A351 D675 1 Ethernet optical EN100 C53207 A322 B150 1 Terminal Block Covering Caps Block type Order Number 18 terminal voltage or 12 terminal current block C73334 A1 C31 1 12 terminal voltage or 8 terminal current block C73334 A1 C32 1 Short circuit links Short circuit links as jumper kit Order Number 3 pcs for current terminals 6 pcs for v...

Page 504: ...computers 7XS5410 0AA00 Graphic Tools Graphical software to aid in the setting of characteristic curves option package of the complete version of DIGSI 4 Name Order Number Graphic Tools 4 Full version with license for 10 computers7XS5430 0AA00 DIGSI REMOTE 4 Name Order Number Software for remotely operating protective devices via a modem and possibly a star coupler using DIGSI 4 option package of ...

Page 505: ...Terminal Assignments 505 7UT613 63x Manual C53000 G1176 C160 2 A 2 Terminal Assignments A 2 1 Panel Flush and Cubicle Mounting 7UT613 D E Figure A 1 Overview diagram 7UT613 panel flush and cubicle mounting ...

Page 506: ...A Appendix 506 7UT613 63x Manual C53000 G1176 C160 2 7UT633 D E ...

Page 507: ...A 2 Terminal Assignments 507 7UT613 63x Manual C53000 G1176 C160 2 7UT633 D E Figure A 2 General diagram 7UT633 panel flush and cubicle mounting ...

Page 508: ...A Appendix 508 7UT613 63x Manual C53000 G1176 C160 2 7UT633 P Q ...

Page 509: ...A 2 Terminal Assignments 509 7UT613 63x Manual C53000 G1176 C160 2 7UT633 P Q Figure A 3 General diagram 7UT633 panel flush and cubicle mounting ...

Page 510: ...A Appendix 510 7UT613 63x Manual C53000 G1176 C160 2 7UT635 D E ...

Page 511: ...A 2 Terminal Assignments 511 7UT613 63x Manual C53000 G1176 C160 2 7UT635 D E Figure A 4 General diagram 7UT635 panel flush and cubicle mounting ...

Page 512: ...A Appendix 512 7UT613 63x Manual C53000 G1176 C160 2 7UT635 P Q ...

Page 513: ...A 2 Terminal Assignments 513 7UT613 63x Manual C53000 G1176 C160 2 7UT635 P Q Figure A 5 General diagram 7UT635 panel flush and cubicle mounting ...

Page 514: ...A Appendix 514 7UT613 63x Manual C53000 G1176 C160 2 A 2 2 Panel Surface Mounting 7UT613 B Figure A 6 General diagram 7UT613 panel surface mounting ...

Page 515: ...A 2 Terminal Assignments 515 7UT613 63x Manual C53000 G1176 C160 2 7UT633 B ...

Page 516: ...A Appendix 516 7UT613 63x Manual C53000 G1176 C160 2 7UT633 B Figure A 7 General diagram 7UT633 panel surface mounting ...

Page 517: ...A 2 Terminal Assignments 517 7UT613 63x Manual C53000 G1176 C160 2 7UT633 N ...

Page 518: ...A Appendix 518 7UT613 63x Manual C53000 G1176 C160 2 7UT633 N Figure A 8 General diagram 7UT633 panel surface mounting ...

Page 519: ...A 2 Terminal Assignments 519 7UT613 63x Manual C53000 G1176 C160 2 7UT635 B ...

Page 520: ...A Appendix 520 7UT613 63x Manual C53000 G1176 C160 2 7UT635 B Figure A 9 General diagram 7UT635 panel surface mounting ...

Page 521: ...A 2 Terminal Assignments 521 7UT613 63x Manual C53000 G1176 C160 2 7UT635 N ...

Page 522: ...A Appendix 522 7UT613 63x Manual C53000 G1176 C160 2 7UT635 N Figure A 10 General diagram 7UT635 panel surface mounting ...

Page 523: ...Current Transformer Connection Examples Figure A 11 Connection example 7UT613 for a three phase power transformer without earthed starpoint Figure A 12 Connection example 7UT613 for a three phase power transformer with earthed starpoint and current transformer between starpoint and earthing point ...

Page 524: ...pendix 524 7UT613 63x Manual C53000 G1176 C160 2 Figure A 13 Connection example 7UT613 for a three phase power transformer with star point former and current transformer between starpoint and earthing point ...

Page 525: ...A 3 Connection Examples 525 7UT613 63x Manual C53000 G1176 C160 2 Figure A 14 Connection example 7UT613 for a three phase power transformer ...

Page 526: ...A Appendix 526 7UT613 63x Manual C53000 G1176 C160 2 Figure A 15 Connection example 7UT613 for an earthed auto transformer with current transformer between starpoint and earthing point ...

Page 527: ... 63x Manual C53000 G1176 C160 2 Figure A 16 Connection example 7UT613 for an earthed auto transformer with brought out delta winding capable of car rying load tertiary winding and current transformer between starpoint and earthing point ...

Page 528: ...branch points with individually accessible earthing electrodes equipped with CTs M3 The CTs on the earthing side constitute a separate side for current comparison for each transformer of the bank The starpoint of the CTs at M3 is routed via an auxiliary input IZ1 which allows realisation of restricted earth fault protection and or earth overcurrent protection ...

Page 529: ...160 2 Figure A 18 Connection example 7UT613 for a single phase power transformer with current transformer between starpoint and earthing point Figure A 19 Connection example 7UT613 for a single phase power transformer with only one current transformer right side ...

Page 530: ...T613 63x Manual C53000 G1176 C160 2 Figure A 20 Connection example 7UT613 for a generator or motor Figure A 21 Connection example 7UT613 as transversal differential protection for a generator with two windings per phase ...

Page 531: ...A 3 Connection Examples 531 7UT613 63x Manual C53000 G1176 C160 2 Figure A 22 Connection example 7UT613 for an earthed shunt reactor with current trans former between starpoint and earthing point ...

Page 532: ...C160 2 Figure A 23 Connection example 7UT613 as high impedance protection on a transformer winding with earthed starpoint the illustration shows the partial connection of the high impedance protection IZ3 is connected to the high sensitivity input ...

Page 533: ...000 G1176 C160 2 Figure A 24 Connection example 7UT613 for a three phase power transformer with current transformers between star point and earthing point additional connection for high impedance protection IZ3 connected to the high sensitivity input ...

Page 534: ...A Appendix 534 7UT613 63x Manual C53000 G1176 C160 2 Figure A 25 Connection example 7UT613 as single phase busbar protection for 7 feeders illustrated for phase L1 ...

Page 535: ...Examples 535 7UT613 63x Manual C53000 G1176 C160 2 Figure A 26 Connection example 7UT613 as busbar protection for 6 feeders connected via external summation trans formers SCT partial illustration for feeders 1 2 and 6 ...

Page 536: ...A Appendix 536 7UT613 63x Manual C53000 G1176 C160 2 A 3 2 Voltage Transformer Connection Examples Figure A 27 Voltage connections to three wye connected voltage transformers only in 7UT613 and 7UT633 ...

Page 537: ...ection Examples 537 7UT613 63x Manual C53000 G1176 C160 2 Figure A 28 Voltage connections to three wye connected voltage transformers with addition al open delta windings e n windings only in 7UT613 and 7UT633 ...

Page 538: ...i ble for every conceivable protected object The following table shows which protection functions are possible for which protected objects Once a protected object has been configured as described in subsection 2 1 3 only those protection functions are allowed and settable that are valid according to the table below Figure A 29 Utilisation of the protective functions in different protected objects ...

Page 539: ...ed K ssc can be calculated by the formula Condition K ssc required K ssc r m s Kssc rated symmetrical short circuit current factor example CT 5P20 KSSC 20 K ssc effective symmetrical short circuit current factor Ktd rated transient dimensioning factor Iscc max ext fault maximum symmetrical through flowing fault current Ipn CT rated primary current Isn CT rated secondary current Rct secondary windi...

Page 540: ...C800 for 5A rated secondary current The approximate terminal voltage can be derived from the IEC values as follows ANSI transformer definition Us t max 20 5A Rb Kssc 20 with Rb Pb Isn 2 and Isn 5A one derives at Us t max Pb Kssc 5A Example IEC 60044 600 5 5P20 25VA ANSI C57 13 Us t max 25VA 20 5A 100V in accordance with class C100 The calculations listed above are simplified in order to facilitate...

Page 541: ...erification for Devices 7UT613 63x The CB layout within the power station unit is not specified where InO rated current of the protected object in relation to the parameterised rated current UnO parameterised rated current of the protected object INrelay nominal device current SNmax maximum rated power of the protected object for transformers side with the largest rated load x d sub transient dire...

Page 542: ...3000 G1176 C160 2 with c voltage factor for generators 1 1 SNO M nominal power of the transformer in kVA UNO M nominal voltage of the transformer in kV SNG nominal power of the generator in kVA UNG nominal voltage of the generator in kV ...

Page 543: ... Trip 392 Tripp stage from Buchholz protec tion LED4 no default setting LED5 no default setting LED6 no default setting LED7 no default setting LED8 no default setting LED9 no default setting LED10 no default setting LED11 no default setting LED12 no default setting LED13 Error Sum Alarm 140 Error with a summary alarm Alarm Sum Event 160 Alarm Summary Event LED14 FaultConfig Set 311 Fault in confi...

Page 544: ...devices and ordered variants Function Keys Allocated Func tion Function No Description F1 Display of opera tional instructions F2 Display of primary operational mea sured values F3 An overview of the last 8 network faults F4 QuitG TRP Quitt Lock Out General Trip Resetting the reclo sure interlocking ...

Page 545: ... shown are examples The device will display only those values that make sense for the current application For instance voltages will only be shown if the device is provided with voltage inputs and these inputs have been config ured with single phase transformers there will be no phase L2 Figure A 31 Default display for 4 line display depending on the phase connected address 396 PHASE SELECTION ...

Page 546: ...ay only those values that make sense for the current application For instance voltages and powers will only be shown if the device is provided with voltage inputs and these inputs have been configured with single phase transformers there will be no phase L2 Figure A 32 Basic graphic displays depending on the phase connected address 396 PHASE SELECTION ...

Page 547: ...on Block and Reclosure Interlocking The first chart converts the binary input DataStop from a single point indication SP into an internal single point indication IM The second chart implements a reclosure interlocking feature which prevents a reclo sure of the circuit breaker following a device trip until the trip has been acknowledged manually Note G TRP QUITTIE must be allocated in addition to a...

Page 548: ...7 IRIG B Interface Binary input Via protocol NTP DCF77 IRIG B Interface Binary input Via protocol DCF77 IRIG B inter face binary input Via protocol DCF77 IRIG B Interface Binary input Via protocol DCF77 IRIG B Interface Binary input Via DCF77 IRIG B Interface Binary input Annunciations with time stamp Yes Yes Yes Yes Yes No Yes Commissioning tools Indication mea sured value blocking Yes Yes Yes No...

Page 549: ...bled Restricted earth fault protection 2 117 COLDLOAD PICKUP Disabled Enabled Disabled Cold Load Pickup 120 DMT IDMT Phase Disabled Definite Time TOC IEC TOC ANSI User Defined PU User def Reset Disabled DMT IDMT Phase 122 DMT IDMT 3I0 Disabled Definite Time TOC IEC TOC ANSI User Defined PU User def Reset Disabled DMT IDMT 3I0 124 DMT IDMT Earth Disabled Definite Time TOC IEC TOC ANSI User Defined ...

Page 550: ...44 THERM OVERLOAD2 Disabled th rep w o sen th repl w sens IEC354 Disabled Thermal Overload Protection 2 150 REVERSE POWER Disabled Enabled Disabled Reverse Power Protection 151 FORWARD POWER Disabled Enabled Disabled Forward Power Supervision 152 UNDERVOLTAGE Disabled Enabled Disabled Undervoltage Protection 153 OVERVOLTAGE Disabled Enabled Disabled Overvoltage Protection 156 FREQUENCY Prot Disabl...

Page 551: ...p Function 1 187 EXT TRIP 2 Disabled Enabled Disabled External Trip Function 2 190 RTD BOX INPUT Disabled Port C Port D Disabled External Temperature Input 191 RTD CONNECTION 6 RTD simplex 6 RTD HDX 12 RTD HDX 6 RTD simplex Ext Temperature Input Connec tion Type Addr Parameter Setting Options Default Setting Comments ...

Page 552: ...asuring loc 2 Measuring loc 3 Measuring loc 4 Measuring loc 5 Side 1 Function is applied to 0 Func per phase Flx IL1 IL3 IL1 IL2 IL3 3I0 Zero seq I1 Pos seq I2 Neg seq IL1 IL3 Function utilises component s 0 Func assigned Flx I CT 1 I CT 2 I CT 3 I CT 4 I CT 5 I CT 6 I CT 7 I CT 8 I CT 9 I CT 10 I CT 11 I CT 12 I CT 1 Function is applied to 0 Func assigned Flx AuxiliaryCT IX1 AuxiliaryCT IX2 Auxil...

Page 553: ...0 A 2 00 A 10 00 A 0 200 A Pick up threshold I8 0 Pick up thresh Flx 1A 5A 0 1A 0 05 35 00 A 0 25 175 00 A 0 005 3 500 A 2 00 A 10 00 A 0 200 A Pick up threshold I9 0 Pick up thresh Flx 1A 5A 0 1A 0 05 35 00 A 0 25 175 00 A 0 005 3 500 A 2 00 A 10 00 A 0 200 A Pick up threshold I10 0 Pick up thresh Flx 1A 5A 0 1A 0 05 35 00 A 0 25 175 00 A 0 005 3 500 A 2 00 A 10 00 A 0 200 A Pick up threshold I11...

Page 554: ... LCD 202 Spont FltDisp Device NO YES NO Spontaneous display of flt an nunciations 204 Start image DD Device image 1 image 2 image 3 image 4 image 5 image 6 image 7 image 1 Start image Default Display 211 No Conn MeasLoc P System Data 1 2 3 4 5 3 Number of connected Measuring Locations 212 No AssigMeasLoc P System Data 1 2 3 4 5 3 Number of assigned Measuring Locations 213 NUMBER OF SIDES P System ...

Page 555: ... compensation earth electrode compensation Side 4 is assigned to 251 AUX CT IX1 P System Data 1 Not connected conn not assig Side 1 earth Side 2 earth Side 3 earth Side 4 earth MeasLoc 1 earth MeasLoc 2 earth MeasLoc 3 earth MeasLoc 4 earth Not connected Auxiliary CT IX1 is used as 252 AUX CT IX2 P System Data 1 Not connected conn not assig Side 1 earth Side 2 earth Side 3 earth Side 4 earth MeasL...

Page 556: ...Setting Group 311 UN PRI SIDE 1 P System Data 1 0 4 800 0 kV 110 0 kV Rated Primary Voltage Side 1 312 SN SIDE 1 P System Data 1 0 20 5000 00 MVA 38 10 MVA Rated Apparent Power of Transf Side 1 313 STARPNT SIDE 1 P System Data 1 Earthed Isolated Earthed Starpoint of Side 1 is 314 CONNECTION S1 P System Data 1 Y D Z Y Transf Winding Connection Side 1 321 UN PRI SIDE 2 P System Data 1 0 4 800 0 kV 1...

Page 557: ...Side 5 353 STARPNT SIDE 5 P System Data 1 Earthed Isolated Earthed Starpoint of Side 5 is 354 CONNECTION S5 P System Data 1 Y D Z Y Transf Winding Connection Side 5 355 VECTOR GRP S5 P System Data 1 0 1 2 3 4 5 6 7 8 9 10 11 0 Vector Group Numeral of Side 5 361 UN GEN MOTOR P System Data 1 0 4 800 0 kV 21 0 kV Rated Primary Voltage Genera tor Motor 362 SN GEN MOTOR P System Data 1 0 20 5000 00 MVA...

Page 558: ...ting Current End 12 396 PHASE SELECTION P System Data 1 Phase 1 Phase 2 Phase 3 Phase 1 Phase selection 403 I PRIMARY OP M3 P System Data 1 1 100000 A 200 A Primary Operating Current Meas Loc 3 404 I PRIMARY OP M4 P System Data 1 1 100000 A 200 A Primary Operating Current Meas Loc 4 405 I PRIMARY OP M5 P System Data 1 1 100000 A 200 A Primary Operating Current Meas Loc 5 408 UN PRI M3 P System Dat...

Page 559: ... Side 2 Side 3 Side 4 Side 5 Measuring loc 1 Measuring loc 2 Measuring loc 3 Measuring loc 4 Measuring loc 5 Side 1 DMT IDMT 3I0 2 assigned to 436 DMT IDMT3I0 3AT P System Data 1 Side 1 Side 2 Side 3 Side 4 Side 5 Measuring loc 1 Measuring loc 2 Measuring loc 3 Measuring loc 4 Measuring loc 5 Side 1 DMT IDMT 3I0 3 assigned to 438 DMT IDMT E2 AT P System Data 1 no assig poss AuxiliaryCT IX1 Auxilia...

Page 560: ...ated Primary Current Meas Loc 3 533 IN SEC CT M3 P System Data 1 1A 5A 1A CT Rated Secondary Current Meas Loc 3 541 STRPNT OBJ M4 P System Data 1 YES NO YES CT Strpnt Meas Loc 4 in Dir of Object 542 IN PRI CT M4 P System Data 1 1 100000 A 2000 A CT Rated Primary Current Meas Loc 4 543 IN SEC CT M4 P System Data 1 1A 5A 1A CT Rated Secondary Current Meas Loc 4 551 STRPNT OBJ M5 P System Data 1 YES ...

Page 561: ...d Secondary Current I8 641 STRPNT BUS I9 P System Data 1 YES NO YES CT Starpoint I9 in Direction of Busbar 642 IN PRI CT I9 P System Data 1 1 100000 A 200 A CT Rated Primary Current I9 643 IN SEC CT I9 P System Data 1 1A 5A 0 1A 1A CT Rated Secondary Current I9 651 STRPNT BUS I10 P System Data 1 YES NO YES CT Starpoint I10 in Direction of Busbar 652 IN PRI CT I10 P System Data 1 1 100000 A 200 A C...

Page 562: ...n configuration None Switchgear CBaux at Side 2 833 SwitchgCBaux S3 P System Data 1 Setting options depend on configuration None Switchgear CBaux at Side 3 834 SwitchgCBaux S4 P System Data 1 Setting options depend on configuration None Switchgear CBaux at Side 4 835 SwitchgCBaux S5 P System Data 1 Setting options depend on configuration None Switchgear CBaux at Side 5 836 SwitchgCBaux M1 P System...

Page 563: ...en Current Threshold End 2 5A 0 20 5 00 A 0 20 A 0 1A 0 004 0 100 A 0 004 A 1133 PoleOpenCurr I3 P System Data 2 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold End 3 5A 0 20 5 00 A 0 20 A 0 1A 0 004 0 100 A 0 004 A 1134 PoleOpenCurr I4 P System Data 2 1A 0 04 1 00 A 0 04 A Pole Open Current Threshold End 4 5A 0 20 5 00 A 0 20 A 0 1A 0 004 0 100 A 0 004 A 1135 PoleOpenCurr I5 P System Data 2 1A ...

Page 564: ...lue of Differential Curr 1226A T I DIFF Diff Prot 0 00 60 00 sec 0 00 sec T I DIFF Time Delay 1231 I DIFF Diff Prot 0 5 35 0 I InO 7 5 I InO Pickup Value of High Set Trip 1236A T I DIFF Diff Prot 0 00 60 00 sec 0 00 sec T I DIFF Time Delay 1241A SLOPE 1 Diff Prot 0 10 0 50 0 25 Slope 1 of Tripping Characteristic 1242A BASE POINT 1 Diff Prot 0 00 2 00 I InO 0 00 I InO Base Point for Slope 1 of Char...

Page 565: ...3 ColdLoadPickup No Current Breaker Contact No Current Start Condition CLP for O C 3I0 3 1709 Start CLP E 2 ColdLoadPickup No Current Breaker Contact No Current Start Condition CLP for O C Earth 2 1711 CB Open Time ColdLoadPickup 0 21600 sec 3600 sec Circuit Breaker OPEN Time 1712 Active Time ColdLoadPickup 1 21600 sec 3600 sec Active Time 1713 Stop Time ColdLoadPickup 1 600 sec 600 sec Stop Time ...

Page 566: ...21 Ip Phase O C 1A 0 10 4 00 A 4 00 A Ip Pickup 5A 0 50 20 00 A 20 00 A 2122 Ip Phase O C 0 10 4 00 I InS 4 00 I InS Ip Pickup 2123 T Ip Phase O C 0 05 3 20 sec 0 50 sec T Ip Time Dial 2124 D Ip Phase O C 0 50 15 00 5 00 D Ip Time Dial 2201 3I0 O C 3I0 O C ON OFF Block relay OFF 3I0 Time Overcurrent 2202 InRushRest 3I0 3I0 O C ON OFF OFF InRush Restrained O C 3I0 2208A 3I0 MAN CLOSE 3I0 O C 3I0 in...

Page 567: ...00 A 5 00 A 2322 3I0p 3I0 O C 0 05 4 00 I InS 1 00 I InS 3I0p Pickup 2323 T 3I0p 3I0 O C 0 05 3 20 sec 0 50 sec T 3I0p Time Dial 2324 D 3I0p 3I0 O C 0 50 15 00 5 00 D 3I0p Time Dial 2401 EARTH O C Earth O C ON OFF Block relay OFF Earth Time Overcurrent 2402 InRushRestEarth Earth O C ON OFF OFF InRush Restrained O C Earth 2408A IE MAN CLOSE Earth O C IE instant IE instant IEp instant Inactive IE in...

Page 568: ...35 00 A 0 20 A 1Phase O C I Pickup 5A 0 25 175 00 A 1 00 A 2706 1Phase I 1Phase O C 0 003 1 500 A 0 100 A 1Phase O C I Pickup 2707 T 1Phase I 1Phase O C 0 00 60 00 sec 0 50 sec T 1Phase O C I Time Delay 2911A FFM U min Supervision 10 100 V 20 V Minimum Voltage Threshold U 3001 PHASE O C Phase O C 2 ON OFF Block relay OFF Phase Time Overcurrent 3002 InRushRest Ph Phase O C 2 ON OFF OFF InRush Restr...

Page 569: ...y 3121 Ip Phase O C 2 1A 0 10 4 00 A 4 00 A Ip Pickup 5A 0 50 20 00 A 20 00 A 3122 Ip Phase O C 2 0 10 4 00 I InS 4 00 I InS Ip Pickup 3123 T Ip Phase O C 2 0 05 3 20 sec 0 50 sec T Ip Time Dial 3124 D Ip Phase O C 2 0 50 15 00 5 00 D Ip Time Dial 3201 PHASE O C Phase O C 3 ON OFF Block relay OFF Phase Time Overcurrent 3202 InRushRest Ph Phase O C 3 ON OFF OFF InRush Restrained O C Phase 3208A MAN...

Page 570: ... Phase O C 3 1A 0 10 4 00 A 4 00 A Ip Pickup 5A 0 50 20 00 A 20 00 A 3322 Ip Phase O C 3 0 10 4 00 I InS 4 00 I InS Ip Pickup 3323 T Ip Phase O C 3 0 05 3 20 sec 0 50 sec T Ip Time Dial 3324 D Ip Phase O C 3 0 50 15 00 5 00 D Ip Time Dial 3401 3I0 O C 3I0 O C 2 ON OFF Block relay OFF 3I0 Time Overcurrent 3402 InRushRest 3I0 3I0 O C 2 ON OFF OFF InRush Restrained O C 3I0 3408A 3I0 MAN CLOSE 3I0 O C...

Page 571: ...22 3I0p 3I0 O C 2 0 05 4 00 I InS 1 00 I InS 3I0p Pickup 3523 T 3I0p 3I0 O C 2 0 05 3 20 sec 0 50 sec T 3I0p Time Dial 3524 D 3I0p 3I0 O C 2 0 50 15 00 5 00 D 3I0p Time Dial 3601 3I0 O C 3I0 O C 3 ON OFF Block relay OFF 3I0 Time Overcurrent 3602 InRushRest 3I0 3I0 O C 3 ON OFF OFF InRush Restrained O C 3I0 3608A 3I0 MAN CLOSE 3I0 O C 3 3I0 instant 3I0 instant 3I0p instant Inactive 3I0 instant O C ...

Page 572: ... 5 00 A 3722 3I0p 3I0 O C 3 0 05 4 00 I InS 1 00 I InS 3I0p Pickup 3723 T 3I0p 3I0 O C 3 0 05 3 20 sec 0 50 sec T 3I0p Time Dial 3724 D 3I0p 3I0 O C 3 0 50 15 00 5 00 D 3I0p Time Dial 3801 EARTH O C Earth O C 2 ON OFF Block relay OFF Earth Time Overcurrent 3802 InRushRestEarth Earth O C 2 ON OFF OFF InRush Restrained O C Earth 3808A IE MAN CLOSE Earth O C 2 IE instant IE instant IEp instant Inacti...

Page 573: ...oad 0 00 60 00 sec 1 50 sec T I2 Time Delay 4021 I2p Unbalance Load 1A 0 10 2 00 A 0 90 A I2p Pickup 5A 0 50 10 00 A 4 50 A 4022 I2p Unbalance Load 0 10 2 00 I InS 0 90 I InS I2p Pickup 4023 T I2p Unbalance Load 0 05 3 20 sec 0 50 sec T I2p Time Dial 4024 D I2p Unbalance Load 0 50 15 00 5 00 D I2p Time Dial 4025 I2p DROP OUT Unbalance Load Instantaneous Disk Emulation Instantaneous I2p Drop out Ch...

Page 574: ... f 4302 U f Overexcit 1 00 1 20 1 10 U f Pickup 4303 T U f Overexcit 0 00 60 00 sec 10 00 sec T U f Time Delay 4304 U f Overexcit 1 00 1 40 1 40 U f Pickup 4305 T U f Overexcit 0 00 60 00 sec 1 00 sec T U f Time Delay 4306 t U f 1 05 Overexcit 0 20000 sec 20000 sec U f 1 05 Time Delay 4307 t U f 1 10 Overexcit 0 20000 sec 6000 sec U f 1 10 Time Delay 4308 t U f 1 15 Overexcit 0 20000 sec 240 sec U...

Page 575: ... Time Delay Long without Stop Valve 5014 T SV CLOSED Reverse Power 0 00 60 00 sec 1 00 sec Time Delay Short with Stop Valve 5015A T HOLD Reverse Power 0 00 60 00 sec 0 00 sec Pickup Holding Time 5016A Type of meas Reverse Power accurate fast accurate Type of measurement 5101 FORWARD POWER Forward Power OFF ON Block relay OFF Forward Power Supervision 5111 Pf Forward Power 1A 1 7 3000 0 W 17 3 W P ...

Page 576: ... 5642 T f Frequency Prot 0 00 600 00 sec 1 00 sec Delay time T f 5643 T f Frequency Prot 0 00 100 00 sec 6 00 sec Delay time T f 5644 T f Frequency Prot 0 00 100 00 sec 10 00 sec Delay time T f 5651 Umin Frequency Prot 10 0 125 0 V 0 65 0 V Minimum Required Voltage for Operation 5652 U MIN Frequency Prot 0 10 1 25 U UnS 0 0 65 U UnS Minimum voltage 7001 BREAKER FAILURE Breaker Failure OFF ON Block...

Page 577: ... 8133A T Sym I th M3 Measurem Superv 5 100 sec 5 sec Symmetry Iph Pick up delay 8141 BAL I LIMIT M4 Measurem Superv 1A 0 10 1 00 A 0 50 A Current Balance Monitor Meas Loc 4 5A 0 50 5 00 A 2 50 A 8142 BAL FACT I M4 Measurem Superv 0 10 0 90 0 50 Bal Factor for Curr Monitor Meas Loc 4 8143A T Sym I th M4 Measurem Superv 5 100 sec 5 sec Symmetry Iph Pick up delay 8151 BAL I LIMIT M5 Measurem Superv 1...

Page 578: ...RTD Box 50 250 C 100 C RTD 2 Temperature Stage 1 Pickup 9024 RTD 2 STAGE 1 RTD Box 58 482 F 212 F RTD 2 Temperature Stage 1 Pickup 9025 RTD 2 STAGE 2 RTD Box 50 250 C 120 C RTD 2 Temperature Stage 2 Pickup 9026 RTD 2 STAGE 2 RTD Box 58 482 F 248 F RTD 2 Temperature Stage 2 Pickup 9031A RTD 3 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 3 Type 9032A RTD 3 LOCATION RTD Box...

Page 579: ...ture Stage 1 Pickup 9064 RTD 6 STAGE 1 RTD Box 58 482 F 212 F RTD 6 Temperature Stage 1 Pickup 9065 RTD 6 STAGE 2 RTD Box 50 250 C 120 C RTD 6 Temperature Stage 2 Pickup 9066 RTD 6 STAGE 2 RTD Box 58 482 F 248 F RTD 6 Temperature Stage 2 Pickup 9071A RTD 7 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD 7 Type 9072A RTD 7 LOCATION RTD Box Oil Ambient Winding Bearing Other O...

Page 580: ...ure Stage 1 Pickup 9104 RTD10 STAGE 1 RTD Box 58 482 F 212 F RTD10 Temperature Stage 1 Pickup 9105 RTD10 STAGE 2 RTD Box 50 250 C 120 C RTD10 Temperature Stage 2 Pickup 9106 RTD10 STAGE 2 RTD Box 58 482 F 248 F RTD10 Temperature Stage 2 Pickup 9111A RTD11 TYPE RTD Box Not connected Pt 100 Ω Ni 120 Ω Ni 100 Ω Not connected RTD11 Type 9112A RTD11 LOCATION RTD Box Oil Ambient Winding Bearing Other Ot...

Page 581: ...C53000 G1176 C160 2 9125 RTD12 STAGE 2 RTD Box 50 250 C 120 C RTD12 Temperature Stage 2 Pickup 9126 RTD12 STAGE 2 RTD Box 58 482 F 248 F RTD12 Temperature Stage 2 Pickup Addr Parameter Function C Setting Options Default Setting Comments ...

Page 582: ...catable blank neither preset nor allocatable No Description Function Type of Information 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 Reset LED Reset LED Device IntSP ON LED BO 176 19 1 No Test m...

Page 583: ...le Non Exis tent Device SP 3 Synchronize Internal Real Time Clock Time Synch Device SP_E v LED BI BO 135 48 1 No 4 Trigger Waveform Capture Trig Wave Cap Osc Fault Rec SP m LED BI BO 135 49 1 Yes 5 Reset LED Reset LED Device SP LED BI BO 135 50 1 Yes 7 Setting Group Select Bit 0 Set Group Bit0 Change Group SP LED BI BO 135 51 1 Yes 8 Setting Group Select Bit 1 Set Group Bit1 Change Group SP LED BI...

Page 584: ...D BO 60 109 1 Yes 023 2521 I picked up I picked up Phase O C OUT ON OFF LED BO 60 75 2 Yes 023 2522 I picked up I picked up Phase O C OUT ON OFF LED BO 60 76 2 Yes 023 2523 Ip picked up Ip picked up Phase O C OUT ON OFF LED BO 60 77 2 Yes 023 2524 I InRush picked up I InRush PU Phase O C OUT ON OFF LED BO 60 80 2 Yes 023 2525 Ip InRush picked up Ip InRush PU Phase O C OUT ON OFF LED BO 60 82 2 Yes...

Page 585: ...ked up Earth O C OUT ON OFF LED BO 60 62 2 Yes 024 2523 IEp picked up IEp picked up Earth O C OUT ON OFF LED BO 60 64 2 Yes 024 2524 IE InRush picked up IE InRush PU Earth O C OUT ON OFF LED BO 60 81 2 Yes 024 2525 IEp InRush picked up IEp InRush PU Earth O C OUT ON OFF LED BO 60 83 2 Yes 024 2529 Earth InRush picked up Earth InRush PU Earth O C OUT ON OFF LED BO 60 88 2 Yes 024 2541 IE Time Out I...

Page 586: ...BLOCK overvoltage protection U BLOCK U Overvoltage SP ON OFF ON OFF LED BI BO 74 21 1 Yes 034 2503 BLOCK overvoltage protection U BLOCK U Overvoltage SP ON OFF ON OFF LED BI BO 74 20 1 Yes 034 2521 Overvoltage U picked up U picked up Overvoltage OUT ON OFF LED BO 74 71 2 Yes 034 2522 Overvoltage U picked up U picked up Overvoltage OUT ON OFF LED BO 74 68 2 Yes 034 2551 Overvoltage U TRIP U TRIP Ov...

Page 587: ...e SP ON OFF LED BI BO 166 104 1 Yes 047 2652 Breaker failure internal PICKUP BkrFail int PU Breaker Failure OUT ON OFF LED BO 166 156 2 Yes 047 2653 Breaker failure external PICKUP BkrFail ext PU Breaker Failure OUT ON OFF LED BO 166 157 2 Yes 047 2654 BF TRIP T1 local trip BF T1 TRIP loc Breaker Failure OUT ON m LED BO 166 192 2 Yes 047 2655 BF TRIP T2 busbar trip BF T2 TRIP bus Breaker Failure O...

Page 588: ...perv OUT ON OFF LED BO 135 184 1 Yes 167 Failure Voltage Balance Fail U balance Measurem Superv OUT ON OFF LED BO 135 186 1 Yes 169 VT Fuse Failure alarm 10s VT FuseFail 10s Supervision OUT ON OFF LED BO 135 188 1 Yes 170 VT Fuse Failure alarm instanta neous VT FuseFail Supervision OUT ON OFF LED BO 171 Failure Phase Sequence Fail Ph Seq Measurem Superv OUT ON OFF LED BO 175 Failure Phase Sequence...

Page 589: ...UT ON OFF ON OFF LED BO 60 155 1 Yes 191 2515 3I0 BLOCKED 3I0 BLOCKED 3I0 O C OUT ON OFF ON OFF LED BO 60 159 1 Yes 191 2516 3I0p BLOCKED 3I0p BLOCKED 3I0 O C OUT ON OFF ON OFF LED BO 60 163 1 Yes 191 2521 3I0 picked up 3I0 picked up 3I0 O C OUT ON OFF LED BO 60 156 2 Yes 191 2522 3I0 picked up 3I0 picked up 3I0 O C OUT ON OFF LED BO 60 160 2 Yes 191 2523 3I0p picked up 3I0p picked up 3I0 O C OUT ...

Page 590: ...tion factor CT REF Adap fact REF OUT ON LED BO 199 2631 Restr earth flt Time delay started REF T start REF OUT ON OFF LED BO 76 16 2 Yes 199 2632 REF Value D at trip without Tdelay REF D REF VI ON OFF 76 26 4 No 199 2633 REF Value S at trip without Tdelay REF S REF VI ON OFF 76 27 4 No 199 2634 REF Adaption factor CT M1 REF CT M1 REF VI ON OFF 199 2635 REF Adaption factor CT M2 REF CT M2 REF VI ON...

Page 591: ...Overload Protection 2 BLOCKED Therm O L2 BLK Therm Overload2 OUT ON OFF ON OFF LED BO 204 2413 Thermal Overload Protection 2 ACTIVE Therm O L2 ACT Therm Overload2 OUT ON OFF LED BO 204 2421 Thermal Overload 2 picked up O L2 Th pickup Therm Overload2 OUT ON OFF LED BO 204 2451 Thermal Overload 2 TRIP Therm O L2 TRIP Therm Overload2 OUT ON OFF m LED BO 204 2491 Th Overload 2 Not avail for this obj O...

Page 592: ...637 REF2 Adaption factor CT M4 REF2 CT M4 REF 2 VI ON OFF 205 2638 REF2 Adaption factor CT M5 REF2 CT M5 REF 2 VI ON OFF 205 2639 REF2 Adaption factor CT starp nt wind REF2 CTstar REF 2 VI ON OFF 206 2404 BLOCK Breaker failure 2 BLOCK BkrFail2 Breaker Fail 2 SP LED BI BO 206 2411 Breaker failure 2 is switched OFF BkrFail2 OFF Breaker Fail 2 OUT ON OFF LED BO 206 2412 Breaker failure 2 is BLOCKED B...

Page 593: ...LED BO 207 2516 Time Overcurrent Phase 2 Ip BLOCKED O C Ph2 Ip BLK Phase O C 2 OUT ON OFF ON OFF LED BO 207 2521 Time Overcurrent Phase 2 I picked up O C Ph2 I PU Phase O C 2 OUT ON OFF LED BO 207 2522 Time Overcurrent Phase 2 I picked up O C Ph2 I PU Phase O C 2 OUT ON OFF LED BO 207 2523 Time Overcurrent Phase 2 Ip picked up O C Ph2 Ip PU Phase O C 2 OUT ON OFF LED BO 207 2524 Time Overcurrent P...

Page 594: ... LED BO 209 2491 O C Phase3 Not available for this object O C Ph3 Not av Phase O C 3 OUT ON LED BO 209 2501 BLOCK time overcurrent Phase 3 InRush BLK Ph O C3Inr Phase O C 3 SP ON OFF ON OFF LED BI BO 209 2502 Time Overcurrent Phase 3 BLOCK I O C3 BLOCK I Phase O C 3 SP LED BI BO 209 2503 Time Overcurrent Phase 3 BLOCK I O C3 BLOCK I Phase O C 3 SP LED BI BO 209 2504 Time Overcurrent Phase 3 BLOCK ...

Page 595: ...413 Dynamic settings O C Phase 3 are ACTIVE I 3 Dyn set ACT ColdLoadPickup OUT ON OFF ON OFF LED BO 235 2110 BLOCK Function 00 BLOCK 00 Flx SP LED BI BO 235 2111 Function 00 instantaneous TRIP 00 instant Flx SP ON OFF on off LED BI BO 235 2113 Function 00 BLOCK TRIP Time Delay 00 BLK TDly Flx SP ON OFF on off LED BI BO 235 2114 Function 00 BLOCK TRIP 00 BLK TRIP Flx SP ON OFF on off LED BI BO 235 ...

Page 596: ...2 Yes 302 Fault Event Fault Event P System Data 2 OUT ON 135 232 2 Yes 311 Fault in configuration setting FaultConfig Set P System Data 2 OUT ON OFF LED BO 312 Gen err Inconsistency group connection GenErrGroup Conn P System Data 2 OUT ON LED BO 313 Gen err Sev earth CTs with equal typ GenErrEarthCT P System Data 2 OUT ON LED BO 314 Gen err Number of sides mea surements GenErrSidesMeas P System Da...

Page 597: ... LED BO 321 2542 Time Overcurrent 3I0 2 3I0 Time Out 3I0 2 Time Out 3I0 O C 2 OUT LED BO 321 2543 Time Overcurrent 3I0 2 3I0p Time Out 3I0 2p Time Out 3I0 O C 2 OUT LED BO 321 2551 Time Overcurrent 3I0 2 3I0 TRIP O C 3I0 2 TRIP 3I0 O C 2 OUT ON LED BO 321 2552 Time Overcurrent 3I0 2 3I0 TRIP O C 3I0 2 TRIP 3I0 O C 2 OUT ON LED BO 321 2553 Time Overcurrent 3I0 2 3I0p TRIP O C 3I0 2p TRIP 3I0 O C 2 ...

Page 598: ...rcurrent 3I0 3 3I0 Time Out 3I0 3 Time Out 3I0 O C 3 OUT LED BO 323 2543 Time Overcurrent 3I0 3 3I0p Time Out 3I0 3p Time Out 3I0 O C 3 OUT LED BO 323 2551 Time Overcurrent 3I0 3 3I0 TRIP O C 3I0 3 TRIP 3I0 O C 3 OUT ON LED BO 323 2552 Time Overcurrent 3I0 3 3I0 TRIP O C 3I0 3 TRIP 3I0 O C 3 OUT ON LED BO 323 2553 Time Overcurrent 3I0 3 3I0p TRIP O C 3I0 3p TRIP 3I0 O C 3 OUT ON LED BO 324 2413 Dy...

Page 599: ...325 2551 Time Overcurrent Earth 2 IE TRIP O C E2 IE TRIP Earth O C 2 OUT ON LED BO 325 2552 Time Overcurrent Earth 2 IE TRIP O C E2 IE TRIP Earth O C 2 OUT ON LED BO 325 2553 Time Overcurrent Earth 2 IEp TRIP O C E2 IEp TRIP Earth O C 2 OUT ON LED BO 326 2413 Dynamic settings O C Earth 2 are ACTIVE IE 2 Dyn s ACT ColdLoadPickup OUT ON OFF ON OFF LED BO 361 Failure Feeder VT MCB tripped FAIL Feeder...

Page 600: ...OFF Ext 1 OFF External Trips OUT ON OFF LED BO 51 131 1 Yes 4532 External trip 1 is BLOCKED Ext 1 BLOCKED External Trips OUT ON OFF ON OFF LED BO 51 132 1 Yes 4533 External trip 1 is ACTIVE Ext 1 ACTIVE External Trips OUT ON OFF LED BO 51 133 1 Yes 4536 External trip 1 General picked up Ext 1 picked up External Trips OUT ON OFF LED BO 51 136 2 Yes 4537 External trip 1 General TRIP Ext 1 Gen TRIP E...

Page 601: ...LOCK Forward Power SP ON OFF ON OFF LED BI BO 70 103 1 Yes 5121 Forward power supervis is switched OFF Pf OFF Forward Power OUT ON OFF LED BO 70 106 1 Yes 5122 Forward power supervision is BLOCKED Pf BLOCKED Forward Power OUT ON OFF ON OFF LED BO 70 107 1 Yes 5123 Forward power supervision is ACTIVE Pf ACTIVE Forward Power OUT ON OFF LED BO 70 108 1 Yes 5126 Forward power Pf stage picked up Pf pic...

Page 602: ... 70 149 2 Yes 5172 I2 err Not available for this object I2 Not avail Unbalance Load OUT ON LED BO 5178 I2 TRIP I2 TRIP Unbalance Load OUT ON LED BO 5179 I2p TRIP I2p TRIP Unbalance Load OUT ON LED BO 5203 BLOCK frequency protection BLOCK Freq Frequency Prot SP LED BI BO 70 176 1 Yes 5211 Frequency protection is switched OFF Freq OFF Frequency Prot OUT ON OFF LED BO 70 181 1 Yes 5212 Frequency prot...

Page 603: ...Diff picked up Diff Prot OUT ON OFF m LED BO 75 31 2 Yes 5644 Diff Blocked by 2 Harmon L1 Diff 2 Harm L1 Diff Prot OUT ON OFF LED BO 75 44 2 Yes 5645 Diff Blocked by 2 Harmon L2 Diff 2 Harm L2 Diff Prot OUT ON OFF LED BO 75 45 2 Yes 5646 Diff Blocked by 2 Harmon L3 Diff 2 Harm L3 Diff Prot OUT ON OFF LED BO 75 46 2 Yes 5647 Diff Blocked by n Harmon L1 Diff n Harm L1 Diff Prot OUT ON OFF LED BO 75 ...

Page 604: ...rot OUT ON OFF LED BO 75 84 2 Yes 5685 Diff prot IDIFF L2 without Tdelay Diff L2 Diff Prot OUT ON OFF LED BO 75 85 2 Yes 5686 Diff prot IDIFF L3 without Tdelay Diff L3 Diff Prot OUT ON OFF LED BO 75 86 2 Yes 5691 Differential prot TRIP by IDIFF Diff TRIP Diff Prot OUT ON m LED BO 75 91 2 Yes 5692 Differential prot TRIP by IDIFF Diff TRIP Diff Prot OUT ON m LED BO 75 92 2 Yes 5701 Diff curr in L1 a...

Page 605: ...X3 Diff CT IX3 Diff Prot VI ON OFF 5741 Diff prot Adaption factor aux CT IX4 Diff CT IX4 Diff Prot VI ON OFF 5742 Diff DC L1 Diff DC L1 Diff Prot OUT ON OFF LED BO 5743 Diff DC L2 Diff DC L2 Diff Prot OUT ON OFF LED BO 5744 Diff DC L3 Diff DC L3 Diff Prot OUT ON OFF LED BO 5745 Diff Increase of char phase DC Diff DC InCha Diff Prot OUT ON OFF LED BO 6851 BLOCK Trip circuit supervision BLOCK TripC ...

Page 606: ...cy prot Trip Stage f Freq f TRIP Frequency Prot OUT ON m LED BO 70 250 2 Yes 14101 Fail RTD broken wire shorted Fail RTD RTD Box OUT ON OFF LED BO 14111 Fail RTD 1 broken wire shorted Fail RTD 1 RTD Box OUT ON OFF LED BO 14112 RTD 1 Temperature stage 1 picked up RTD 1 St 1 p up RTD Box OUT ON OFF LED BO 14113 RTD 1 Temperature stage 2 picked up RTD 1 St 2 p up RTD Box OUT ON OFF LED BO 14121 Fail ...

Page 607: ...D BO 14201 Fail RTD10 broken wire short ed Fail RTD10 RTD Box OUT ON OFF LED BO 14202 RTD10 Temperature stage 1 picked up RTD10 St 1 p up RTD Box OUT ON OFF LED BO 14203 RTD10 Temperature stage 2 picked up RTD10 St 2 p up RTD Box OUT ON OFF LED BO 14211 Fail RTD11 broken wire short ed Fail RTD11 RTD Box OUT ON OFF LED BO 14212 RTD11 Temperature stage 1 picked up RTD11 St 1 p up RTD Box OUT ON OFF ...

Page 608: ... Clos Det S4 P System Data 2 OUT ON LED BO 30079 Manual close signal side 5 is de tected Man Clos Det S5 P System Data 2 OUT ON LED BO 30080 Measurment location 1 is discon nected M1 disconnected Discon MeasLoc OUT ON OFF LED BO 30081 Measurment location 2 is discon nected M2 disconnected Discon MeasLoc OUT ON OFF LED BO 30082 Measurment location 3 is discon nected M3 disconnected Discon MeasLoc O...

Page 609: ... OUT ON OFF LED BO 30107 Err inconsist jumper setting CT IX2 Err IN CT IX2 Supervision OUT ON OFF LED BO 30108 Err inconsist jumper setting CT IX3 Err IN CT IX3 Supervision OUT ON OFF LED BO 30109 Err inconsist jumper setting CT IX4 Err IN CT IX4 Supervision OUT ON OFF LED BO 30110 Fail Current Balance meas lo cation 1 Fail balan IM1 Measurem Superv OUT ON OFF LED BO 30111 Fail Current Balance mea...

Page 610: ...ON OFF LED BO 30134 Broken wire IL3 measurement lo cation 5 brk wire IL3M5 Supervision OUT ON OFF LED BO 30135 Incons M1 CBaux open curr persistent Incons CBaux M1 Supervision OUT ON OFF LED BO 30136 Incons M2 CBaux open curr persistent Incons CBaux M2 Supervision OUT ON OFF LED BO 30137 Incons M3 CBaux open curr persistent Incons CBaux M3 Supervision OUT ON OFF LED BO 30138 Incons M4 CBaux open c...

Page 611: ... 30268 Primary fault current IL3 side3 IL3S3 P System Data 2 VI 30269 Primary fault current IL1 side4 IL1S4 P System Data 2 VI 30270 Primary fault current IL2 side4 IL2S4 P System Data 2 VI 30271 Primary fault current IL3 side4 IL3S4 P System Data 2 VI 30272 Primary fault current IL1 side5 IL1S5 P System Data 2 VI 30273 Primary fault current IL2 side5 IL2S5 P System Data 2 VI 30274 Primary fault c...

Page 612: ...disconnect end 1 disconnect I1 Discon MeasLoc SP ON OFF LED BI BO 30368 disconnect end 2 disconnect I2 Discon MeasLoc SP ON OFF LED BI BO 30369 disconnect end 3 disconnect I3 Discon MeasLoc SP ON OFF LED BI BO 30370 disconnect end 4 disconnect I4 Discon MeasLoc SP ON OFF LED BI BO 30371 disconnect end 5 disconnect I5 Discon MeasLoc SP ON OFF LED BI BO 30372 disconnect end 6 disconnect I6 Discon Me...

Page 613: ...urr L2 M2 ΣIL2M2 Statistics VI 30768 Accumulation of interrupted curr L3 M2 ΣIL3M2 Statistics VI 30769 Accumulation of interrupted curr L1 M3 ΣIL1M3 Statistics VI 30770 Accumulation of interrupted curr L2 M3 ΣIL2M3 Statistics VI 30771 Accumulation of interrupted curr L3 M3 ΣIL3M3 Statistics VI 30772 Accumulation of interrupted curr L1 M4 ΣIL1M4 Statistics VI 30773 Accumulation of interrupted curr ...

Page 614: ...0787 Accumulation of interrupted curr I8 ΣI8 Statistics VI 30788 Accumulation of interrupted curr I9 ΣI9 Statistics VI 30789 Accumulation of interrupted curr I10 ΣI10 Statistics VI 30790 Accumulation of interrupted curr I11 ΣI11 Statistics VI 30791 Accumulation of interrupted curr I12 ΣI12 Statistics VI 31000 Q0 operationcounter Q0 OpCnt Control Device VI No Description Function Type of Informatio...

Page 615: ...m Fail Battery Err Module B Err Module C Err Module D Clock SyncError Incons CBaux M1 Incons CBaux M2 Incons CBaux M3 Incons CBaux M4 Incons CBaux M5 Incons CBaux S1 Incons CBaux S2 Incons CBaux S3 Incons CBaux S4 Incons CBaux S5 161 Fail I Superv 163 Fail I balance 163 Fail I balance 30110 30111 30112 30113 30114 Fail balan IM1 Fail balan IM2 Fail balan IM3 Fail balan IM4 Fail balan IM5 171 Fail ...

Page 616: ... Error Board 5 Error Board 6 Error Board 7 Error1A 5Awrong Error Offset 192 Error1A 5Awrong 30097 30098 30099 30100 30101 30102 30103 30104 30105 30106 30107 30108 30109 Err IN CT M1 Err IN CT M2 Err IN CT M3 Err IN CT M4 Err IN CT M5 Err IN CT1 3 Err IN CT4 6 Err IN CT7 9 Err IN CT10 12 Err IN CT IX1 Err IN CT IX2 Err IN CT IX3 Err IN CT IX4 No Description Function No Description ...

Page 617: ...Idiff REF I Inominal object IdiffREF Meas Dif Rest CFC CD DD 199 2641 Irest REF I Inominal object IrestREF Meas Dif Rest CFC CD DD 204 2611 O L2 Temperat rise for warning and trip 2Θ Θtrip Meas Thermal CFC CD DD 204 2612 Th O L 2 Temperature rise for phase L1 2Θ ΘtrpL1 Meas Thermal CFC CD DD 204 2613 Th O L 2 Temperature rise for phase L2 2Θ ΘtrpL2 Meas Thermal CFC CD DD 204 2614 Th O L 2 Temperat...

Page 618: ...culated temperature U f U f th Meas Thermal CFC CD DD 888 Pulsed Energy Wp active Wp puls Energy 133 55 No 205 CD DD 889 Pulsed Energy Wq reactive Wq puls Energy 133 56 No 205 CD DD 901 Power Factor PF Measurement CFC CD DD 910 Calculated rotor temp unbal load Therm Rep Meas Thermal CFC CD DD 924 Wp Forward Wp Energy 133 51 No 205 CD DD 925 Wq Forward Wq Energy 133 52 No 205 CD DD 928 Wp Reverse W...

Page 619: ...CD DD 30650 Operat meas current I5 I5 Measurement CFC CD DD 30651 Operat meas current I6 I6 Measurement CFC CD DD 30652 Operat meas current I7 I7 Measurement CFC CD DD 30653 Operat meas current I8 I8 Measurement CFC CD DD 30656 Operat meas voltage Umeas Umeas Measurement CFC CD DD 30661 Operat meas current IL1 meas loc 1 IL1M1 Measurement 134 149 No 9 2 CFC CD DD 30662 Operat meas current IL2 meas...

Page 620: ...sitive sequence of side 3 I1S3 Measurement CFC CD DD 30715 I2 negative sequence of side 3 I2S3 Measurement CFC CD DD 30716 Operat meas current IL1 side 4 IL1S4 Measurement CFC CD DD 30717 Operat meas current IL2 side 4 IL2S4 Measurement CFC CD DD 30718 Operat meas current IL3 side 4 IL3S4 Measurement CFC CD DD 30719 3I0 zero sequence of side 4 3I0S4 Measurement CFC CD DD 30720 I1 positive sequence...

Page 621: ...in phase IL3 meas loc 5 ϕIL3M5 Measurement CFC CD DD 30751 Phase angle in auxiliary current IX1 ϕIX1 Measurement CFC CD DD 30752 Phase angle in auxiliary current IX2 ϕIX2 Measurement CFC CD DD 30753 Phase angle in auxiliary current IX3 ϕIX3 Measurement CFC CD DD 30754 Phase angle in auxiliary current IX4 ϕIX4 Measurement CFC CD DD 30755 Phase angle of current I8 ϕI8 Measurement CFC CD DD 30756 Pha...

Page 622: ...A Appendix 622 7UT613 63x Manual C53000 G1176 C160 2 ...

Page 623: ... ready made blocks CFC blocks Blocks are parts of the user program delimited by their function their structure or their purpose Chatter blocking A rapidly intermittent input for example due to a relay contact fault is switched off after a configurable monitoring time and can thus not generate any further signal changes The function prevents overloading of the system when a fault arises Combination...

Page 624: ... in Braunschweig The atomic clock station of the PTB transmits this time via the long wave time signal transmitter in Mainflingen near Frank furt Main The emitted time signal can be received within a radius of approx 1 500 km from Frankfurt Main Device container In the Component View all SIPROTEC 4 devices are assigned to an object of type Device container This object is a special object of DIGSI ...

Page 625: ...T connection device specific Double point indication ExDP_I External double point indication via an ETHERNET connection intermediate position 00 device specific Double point indication ExMV External metered value via an ETHERNET connection device specific ExSI External single point indication via an ETHERNET connection device specific Single point indication ExSI_F External single point indication...

Page 626: ...n file by a reference to the file name HV project descrip tion All the data is exported once the configuration and parameterization of PCUs and sub modules using ModPara has been completed This data is split up into several files One file contains details about the fundamental project structure This also includes for example information detailing which fields exist in this project This file is cal...

Page 627: ...he tree view Because they are dis played in the form of a list this area is called the list view LV Limit value LVU Limit value user defined Master Masters may send data to other users and request data from other users DIGSI op erates as a master Metered value Metered values are a processing function with which the total number of discrete similar events counting pulses is determined for a period ...

Page 628: ... information On line When working in online mode there is a physical connection to a SIPROTEC 4 device This connection can be implemented as a direct connection as a modem connection or as a PROFIBUS FMS connection OUT Output indication Parameter set The parameter set is the set of all parameters that can be set for a SIPROTEC 4 device Phone book User addresses for a modem connection are saved in ...

Page 629: ...tting parameters General term for all adjustments made to the device Parameterization jobs are exe cuted by means of DIGSI or in some cases directly on the device SI Single point indication SI_F Single point indication transient Transient information Single point indication SICAM SAS Modularly structured station control system based on the substation controller SICAM SC and the SICAM WinCC operato...

Page 630: ... detected together in parallel and processed further Transient informa tion A transient information is a brief transient single point indication at which only the coming of the process signal is detected and processed immediately Tree view The left pane of the project window displays the names and symbols of all containers of a project in the form of a folder tree This area is called the tree view...

Page 631: ...anual C53000 G1176 C160 2 Literature 1 SIPROTEC 4 System Manual E50417 H1176 C151 A2 2 SIPROTEC DIGSI Start UP E50417 G1176 C152 A2 3 DIGSI CFC Manual E50417 H1176 C098 A4 4 SIPROTEC SIGRA 4 Manual E50417 H1176 C070 A2 ...

Page 632: ...Literature 632 7UT613 63x Manual C53000 G1176 C160 2 ...

Page 633: ...24 124 200 204 Busbars 38 Frequency 440 Operating Time 440 C CFC 481 Change of Operating Stage 384 Changing Setting Groups 37 341 Check Time Synchronisation Interface 375 Circuit Breaker Data 83 Circuit Breaker Failure Protection 27 478 Circuit Breaker Status 83 Climatic Stress Test 432 Clock Time Synchronisation 490 Cold Load Pickup Cold Load Criteria 191 193 Command Duration 84 Command Execution...

Page 634: ...rotection Function 191 Pickup Values 194 Time Stages 194 Timers 191 E Earth Fault 127 142 173 198 199 204 CT Saturation 145 Restraint 144 Restraint Quantity 145 Sensitivity 144 Starpoint Current 144 Through Fault Current 144 Tripping Characteristics 145 Earth Fault Differential Protection Delay Times 148 Measuring Principle 141 Sensitivity 148 Earth fault Sensitivity 127 Electrical Tests 430 EMC T...

Page 635: ...dications 301 301 Information to a Control Centre 301 Input Output Board C I O 2 356 C I O 9 359 362 Input Output Boards C I O 1 353 Input Output Module C I O 1 353 Inrush Current 108 159 180 187 Inrush Currents 108 Inrush Restraint 108 162 163 173 175 185 185 185 Instantaneous Tripping 109 111 Integrated Display LCD 300 Interface Board 375 Interfaces 29 Interlocking 334 Isolation Test 430 K K fac...

Page 636: ...d 185 185 Pickup Value 154 158 204 Pickup Value Changeover 165 183 Short Circuit 163 Single Phase 456 Single phase 200 single phase 196 Startup Current 164 Time Delay 163 185 201 204 Time Multiplier 165 165 186 187 Trip Characteristic 164 165 167 174 Tripping 150 155 Tripping Characteristic 158 186 186 Tripping Time 185 User Characteristics 166 User defined Characteristics 187 User specific Charac...

Page 637: ...point Conditioning 66 76 Starpoint CT 144 Starpoint Current 142 186 Starpoint Earthing Transformer 37 Starpoint Former 122 Start Test Measurement Recording 418 Startup 109 Statistic Values 489 Summation Transformer 125 Connection 126 Symmetrical Fault 127 Winding Arrangement 128 Winding Factors 128 Switching interlocked non interlocked 334 Switching Statistics 28 303 System Frequency Decrease 263 ...

Page 638: ...verse Differential Protection 121 121 Trip Circuit Supervision 288 291 Fault Indication 290 Minimum Voltage Drop 289 Supervision Criterion 289 Trip circuit supervision 490 Trip Command 111 124 Indications 296 Trip Signal 129 Tripping Characteristic 327 Tripping Current 106 Tripping Logic Minimum Trip Command Duration 295 Tripping Zone 107 Two stage Breaker Failure Protection 273 Type of Commands 3...

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