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[lo-i-gr-stufe-gerichtet-20101108, 1, en_US]

Figure 2-30

Logic diagram of the 67-1 element

Definite Time High-set Element 67-2

The directional overcurrent element basically works in the same way as the non-directional element. Pickup,
however, depends on the result of the direction determination. The direction determination is accomplished
using the measured quantities and the corresponding directional characteristics.

67-B1 PICKUP

is used as setting values for the phase current;

67N-B1 PICKUP

is used for the ground

current. A trip command is issued after pickup of an element and expiration of the associated time delays

67-

Functions

2.4 Backup overcurrent

SIPROTEC 4, 7SD80, Manual

79

E50417-G1100-C474-A2, Edition 02.2018

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Summary of Contents for SIPROTEC 4 7SD80

Page 1: ... of Contents Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Ordering Information and Accessories A Terminal Assignments B Connection Examples C Current Transformer Requirements D Default Settings and Protocol dependent Functions E Functions Settings Information F Literature Glossary Index ...

Page 2: ...ess relations nor does it change these All obligations of Siemens AG are stated in the relevant contractual agree ments Siemens AG reserves the right to revise this document from time to time Document version E50417 G1100 C474 A2 01 Edition 02 2018 Version of the product described V4 7 Copyright Copyright Siemens AG 2018 All rights reserved The disclosure duplication distribution and editing of th...

Page 3: ...Scope This manual applies to SIPROTEC 4 Line Differential Protection 7SD80 Firmware Version V4 7 Indication of Conformity This product complies with the directive of the Council of the European Communities on the approximation of the laws of the Member States relating to electromagnetic compatibility EMC Council Directive 2004 108 EC and concerning electrical equipment for use within specified vol...

Page 4: ... equipment module or device However it comprises important information that must be followed for personal safety as well as to avoid material damage Information is highlighted and illustrated as follows according to the degree of danger DANGER DANGER means that death or severe injury will result if the measures specified are not taken Comply with all instructions in order to avoid death or severe ...

Page 5: ...ng terminal before any connections are made All circuit components connected to the power supply may be subject to dangerous voltage Hazardous voltages may be present in equipment even after the supply voltage has been disconnected capacitors can still be charged Operation of equipment with exposed current transformer circuits is prohibited Before disconnecting the equipment ensure that the curren...

Page 6: ...l Example of a parameter switch designated FUNCTION with address 1234 and the possible settings ON and OFF Besides these graphical symbols are used in accordance with IEC 60617 12 and IEC 60617 13 or similar Some of the most frequently used are listed below Analog input variable AND gate operation of input values OR gate operation of input values Exclusive OR gate antivalence output is active if o...

Page 7: ...ry SR flipflop with setting input S resetting input R output Q and inverted output Q setting input dominant Static memory RS flipflop with setting input S resetting input R output Q and inverted output Q resetting input dominant Preface SIPROTEC 4 7SD80 Manual 7 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 8: ...8 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 9: ...en Source Software is licensed royalty free Insofar as the applicable Open Source Software License Conditions provide for it you can order the source code of the Open Source Software from your Siemens sales contact against payment of the shipping and handling charges for a period of at least 3 years since purchase of the Product We are liable for the Product including the Open Source Software cont...

Page 10: ...10 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 11: ... 3 2 Settings 38 2 1 4 Oscillographic Fault Records 39 2 1 4 1 Functional Description 40 2 1 4 2 Setting Notes 40 2 1 4 3 Settings 40 2 1 4 4 Information List 40 2 1 5 Change Group 40 2 1 5 1 Functional Description 41 2 1 5 2 Setting Notes 41 2 1 5 3 Settings 41 2 1 5 4 Information List 41 2 1 6 General Protection Data Power System Data 2 42 2 1 6 1 Setting Notes 42 2 1 6 2 Settings 43 2 1 6 3 Inf...

Page 12: ...d Commissioning 65 2 2 7 1 Differential Protection Test 65 2 2 7 2 Differential Protection Commissioning 66 2 3 Breaker Intertrip and Remote Tripping 69 2 3 1 Functional Description 69 2 3 2 Setting Notes 70 2 3 3 Settings 71 2 3 4 Information List 71 2 4 Backup overcurrent 72 2 4 1 Operating Modes 72 2 4 2 Non directional Overcurrent Protection 72 2 4 3 Directional Overcurrent Protection 76 2 4 4...

Page 13: ...n 142 2 12 2 Circuit Breaker Position Detection 144 2 12 3 Circuit Breaker Test 146 2 12 4 Information List 146 2 13 Direct Remote Trip and Transmission of Binary Information 147 2 13 1 Functional Description 147 2 13 2 Information List 147 2 14 Monitoring Functions 149 2 14 1 Measurement Supervision 149 2 14 1 1 Hardware Monitoring 149 2 14 1 2 Software Monitoring 150 2 14 1 3 External Transforme...

Page 14: ...ional Description 187 2 17 6 2 Setting Notes 187 2 17 6 3 Settings 187 2 17 6 4 Information List 188 2 17 7 Demand Measurement Setup 189 2 17 7 1 Functional Description 189 2 17 7 2 Setting Notes 190 2 17 7 3 Settings 190 2 17 7 4 Information List 190 2 17 8 Set Points Measured Values 190 2 17 8 1 Setting Notes 190 2 17 8 2 Information List 191 2 17 9 Energy 191 2 17 9 1 Energy Metering 191 2 17 9...

Page 15: ...ts 233 3 3 6 Checking the Protection Data Communication 236 3 3 7 Checking Circuit Breaker Failure Protection 238 3 3 8 Checking the Instrument Transformer Connections of One Line End 239 3 3 9 Checking the Instrument Transformer Connections of Two Line Ends 244 3 3 10 Checking the Pilot Protection for Internal and External Remote Tripping 244 3 3 11 Checking User defined Functions 244 3 3 12 Trip...

Page 16: ...tions 293 4 19 Dimensions 296 4 19 1 Panel Flush Mounting and Cabinet Flush Mounting Housing Size 1 6 296 4 19 2 Panel Surface Mounting Housing Size 1 6 297 4 19 3 Bottom View 297 A Ordering Information and Accessories 299 A 1 Ordering Information 7SD80 V4 7 300 A 2 Accessories 303 B Terminal Assignments 305 B 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounti...

Page 17: ... F 1 Functional Scope 334 F 2 Settings 336 F 3 Information List 352 F 4 Group Indications 392 F 5 Measured Values 393 Literature 401 Glossary 403 Index 413 Table of Contents SIPROTEC 4 7SD80 Manual 17 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 18: ...18 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 19: ...s the SIPROTEC 4 7SD80 and gives an overview of the device s application properties and functions 1 1 Overall Operation 20 1 2 Application Scope 23 1 3 Characteristics 25 1 SIPROTEC 4 7SD80 Manual 19 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 20: ...for sensitive ground fault detection ΙNs and directional determination of ground faults depending on the model hw struktur 7sd80 100801 1 en_US Figure 1 1 Hardware structure of the 7SD80 differential protection There is one voltage input available for each phase to ground voltage The differential protection does not need measuring voltages due to its functional principle Directional overcurrent pr...

Page 21: ...or remote signaling of important events and statuses Front Elements Information such as messages related to events states measured values and the functional status of the device are visualized by light emitting diodes LEDs and a display screen LCD on the front panel Integrated control and numeric keys in conjunction with the LCD enable communication with the remote device These elements enable the...

Page 22: ...ransient voltage dips may occur if the auxiliary voltage supply system becomes short circuited Usually they are bridged by a capacitor storage see also the Section 4 Technical Data A buffer battery is located behind the lower front cover Introduction 1 1 Overall Operation 22 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 23: ... is restored The overcurrent protection comprises two definite time overcurrent protection elements and one inverse time overcurrent protection element Both elements operate directional or non directional Additionally the device features a third definite time overcur rent protection element that always operates non directionally For inverse time overcurrent protection several characteristic curves...

Page 24: ...and evaluation tasks can be executed using this operator interface for instance specifying and editing configuration parameters and settings configuring user specific logic func tions retrieving operational messages and measured values inquiring device conditions and measured values issuing control commands Port A is located on the bottom side of the device This protection data interface connects ...

Page 25: ...rotection for all types of short circuits in systems with any starpoint conditioning Reliable distinction between load and short circuit conditions using adaptive measurement methods also for high resistance faults with small fault currents High sensitivity in light load operation highest stability against load steps and power fluctuations Due to phase segregated measurement the pickup sensitivity...

Page 26: ...nts Monitoring time element for tripping Initiation by the trip command of each integrated protection function Initiation by external trip functions possible Single element or two element No dropout and seal in times Thermal Overload Protection Thermal replica of the current heat losses of the protected object RMS measurement for all three phase currents Adjustable thermal and current dependent wa...

Page 27: ...atistics showing the availability of transmission telegrams Check of the consistency of protection settings at both line ends no processor system start up with inconsistent settings which could lead to a malfunction of the differential protection system Trip circuit monitoring possible Check of local and remote measured values and comparison of both Broken wire supervision for the secondary CT cir...

Page 28: ...DCF77 IRIGB via satellite receiver binary input or system interface Continuous calculation and indication of operational measured values on the front display indication of measured values of the far end or all ends for devices with active interfaces Fault event memory trip log for the last eight network faults faults in the power system with real time stamps Fault recording and data transfer for f...

Page 29: ...Intertrip and Remote Tripping 69 2 4 Backup overcurrent 72 2 5 InRush Restraint 91 2 6 Circuit Breaker Failure Protection 50BF 94 2 7 Thermal Overload Protection 49 104 2 8 Undervoltage and Overvoltage Protection optional 27 59 108 2 9 Frequency Protection optional 81 123 2 10 Direct Local Trip 129 2 11 Automatic Reclosure Function optional 79 131 2 12 Circuit Breaker Test 142 2 13 Direct Remote T...

Page 30: ...ing the DIGSI software Connect your personal computer either to the USB port on the device front or to port B on the bottom side of the device depending on the device version ordering code The operation via DIGSI is explained in the SIPROTEC 4 System Description The Device Configuration dialog box allows you to adjust your device to the prevailing system conditions Password no 7 is required for pa...

Page 31: ... specify different dead times for each automatic reclose cycle The setting Pickup with pickup allows you to enter different dead times for the automatic reclose cycles for 1 phase 2 phase and 3 phase short circuits The pickup status of the protection functions at the instant the trip command disappears is decisive here This operating mode enables making the dead times dependent on the type of faul...

Page 32: ...tionTime PU w o ActionT Trip w ActionT Trip w oActionT Trip w ActionT Auto Reclose control mode 136 81 O U Disabled Enabled Disabled 81 Over Underfrequency Protec tion 137 27 59 Disabled Enabled Disabled 27 59 Under Overvoltage Protec tion 139 50BF Disabled Enabled enabled w 3I0 Disabled 50BF Breaker Failure Protection 140 74 Trip Ct Supv Disabled 1 trip circuit Disabled 74TC Trip Circuit Supervis...

Page 33: ...ndent Messages No Trip No Flag The indication of messages masked to local LEDs and the generation of additional messages can be made dependent on whether the device has issued a trip signal This information is then not output if during a system disturbance one or more protection functions have picked up but no tripping by the 7SD80 resulted because the fault was cleared by a different device e g o...

Page 34: ... device can be selected in the device data via parameter640 Start image DD The pages available for each device version are listed in the Appendix E Default Settings and Protocol dependent Functions Protection Interface Test Mode To check the communication quality of the two 7SD80 devices during commissioning set parameter 650 PDI Test Mode to ON The availability of the communication link via the p...

Page 35: ...s Operational and Protecting 52 ProtActive IntSP At Least 1 Protection Funct is Active 55 Reset Device OUT Reset Device 56 Initial Start OUT Initial Start of Device 60 Reset LED OUT_Ev Reset LED 67 Resume OUT Resume 68 Clock SyncError OUT Clock Synchronization Error 69 DayLightSavTime OUT Daylight Saving Time 70 Settings Calc OUT Setting calculation is running 71 Settings Check OUT Settings Check ...

Page 36: ...a 1 The device requires certain data regarding the network and substation so that it can adapt its functions to this data depending on the application The data required include for instance rated data of the substation and the measuring transformers polarity and connection of the measured quantities if necessary features of the circuit breakers and others Furthermore there are several function par...

Page 37: ...es with primary magnitude If the settings of the device are performed with primary values using DIGSI these primary data are an indispensable requirement for the correct function of the device Current Connection The device features four current measurement inputs three of which are connected to the set of current transformers Various possibilities exist for the fourth current input Ι4 Connection o...

Page 38: ...t This applies to all close commands issued by the device It also determines the length of the close command pulse when a circuit breaker test cycle is issued via the device It must be long enough to ensure that the circuit breaker has securely closed An excessive duration causes no problem since the closing command is interrupted in the event that another trip is initiated by a protection functio...

Page 39: ...reshold for Binary Input 4 264 Threshold BI 5 Thresh BI 176V Thresh BI 88V Thresh BI 19V Thresh BI 176V Threshold for Binary Input 5 265 Threshold BI 6 Thresh BI 176V Thresh BI 88V Thresh BI 19V Thresh BI 176V Threshold for Binary Input 6 266 Threshold BI 7 Thresh BI 176V Thresh BI 88V Thresh BI 19V Thresh BI 176V Threshold for Binary Input 7 Oscillographic Fault Records The 7SD80 multifunctional ...

Page 40: ...ddress 412 after the storage criterion has reset The maximum storage time for each fault recording MAX LENGTH is entered in address 410 Recording per fault must not exceed 5 seconds A total of 8 records can be saved However the total length of time of all fault records in the buffer must not exceed 25 seconds Settings Addresses which have an appended A can only be changed with DIGSI under Addition...

Page 41: ...red For the setting of the function parameters each of the required setting groups A to D a maximum of 4 must be configured in sequence The SIPROTEC 4 System Description gives further information on how to copy setting groups or reset them to their status at delivery and also how to change from one setting group to another Section 3 1 Mounting and Connections of this manual tells you how to change...

Page 42: ...responds to the forward direction for the protection functions Circuit Breaker Status Information regarding the circuit breaker position is required by various protection and supplementary func tions to ensure their optimal functionality The device has a circuit breaker status recognition which processes the status of the circuit breaker auxiliary contacts and contains also a detection based on th...

Page 43: ...us of the line address 1134 and to reset the trip command address 1135 Address 1135 is also used by other protection functions e g switching on overcurrent For applications with 2 circuit breakers per feeder 1 5 circuitbreaker systems or ring bus the binary inputs CB1 must be connected to the correct circuit breaker The binary inputs CB then need the correct signals for detecting the circuit break...

Page 44: ...faulty for 50BF 379 52a 3p Closed SP 52a Bkr aux contact 3pole closed 380 52b 3p Open SP 52b Bkr aux contact 3pole open 383 Enable ARzones SP Enable all AR Zones Elements 385 Lockout SET SP Lockout SET 386 Lockout RESET SP Lockout RESET 410 52a Bkr1 3p Cl SP 52a Bkr1 aux 3pClosed for AR CB Test 411 52b Bkr1 3p Op SP 52b Bkr1 aux 3p Open for AR CB Test 501 Relay PICKUP OUT Relay PICKUP 502 Relay Dr...

Page 45: ...erface via optical fiber Prot FO and or a protection inter face via copper connection Prot Cu To connect Prot Cu use the voltage terminals D1 and D2 The input of the protection interface Prot Cu has an insulated design The integrated overvoltage protection reduces the insulation strength Use an external isolating transformer to increase the insulation strength The ordering data can be found in Sec...

Page 46: ...terface Optical Fiber If you use an optical fiber connection switch it ON or OFF at address 4501 PDI FO Address 4502 PDI FO TER allows you to enter the permissible maximum fault rate in percent Address 4503 PDI FO level you can define the minimum receiving level Notes on the settings are given in the Technical Data Protection Interface Copper Cable Cu If you use a copper cable connected to the vol...

Page 47: ...7 PDI FO mirror OUT PDI FO data mirror 3218 PDI Cu mirror OUT PDI Cu data mirror 3227 PDI FO stop SP PDI FO is stopped 3228 PDI Cu stop SP PDI Cu is stopped 3230 PDI FO faulty OUT PDI FO failure 3232 PDI Cu faulty OUT PDI Cu failure 3243 PDI FO con to VI PDI FO connected to relay ID 3244 PDI Cu con to VI PDI Cu connected to relay ID 3258 PDI FO TER OUT PDI FO telegram error rate exceeded 3259 PDI ...

Page 48: ... time synchronization for both devices Setting Notes Protection Data Topology At address 4701 ID OF MASTER and 4702 ID OF SLAVE you can enter the device identification number of the two protection devices at the line ends Use address 4710 LOCAL RELAY to define which of the two devices acts as master and which as slave If you want the master to perform the time synchronization for both devices plea...

Page 49: ...n The dynamic filter algorithm generates the value idyn t It represents the current change of the filtered value fundamental component over two cycles If the current change exceeds the set threshold 87L Idyn the phase comparison protection is started The polarity of the current change is transmitted to the device at the remote end of the protected object The dynamic element operates very sensitive...

Page 50: ...ocked via binary input 87L block The following figure shows the formation of the phase specific pickup of the elements 87L Isteady and 87L Idyn lo pvl anr 20101117 1 en_US Figure 2 5 Logic diagram of the phase comparison protection phase selective generation of the Ιstat and Ιdyn signal The pickup signals created locally signs of idyn and istat and the blocking information are sent to the device a...

Page 51: ... to the opposite end The received pickup and blocking information is compared with the own differential protection information and element specific pickup indications are created Functions 2 2 Phase Comparison Protection and Ground Differential Protection SIPROTEC 4 7SD80 Manual 51 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 52: ...phase comparison protection Figure 2 lo pvl anr gegenende 20110530 1 en_US Figure 2 8 Logic diagram of phase comparison protection for pickup in a grounded system The following figure shows the pickup behavior of the phase comparison protection in resonant grounded or isolated systems Functions 2 2 Phase Comparison Protection and Ground Differential Protection 52 SIPROTEC 4 7SD80 Manual E50417 G11...

Page 53: ...t address 1202 87L Idyn you can set the dynamic tripping threshold The value for 87L Idyn should be set to at least 0 2 of the largest primary transformer rated current and larger than 2 5 to 3 times the capacitive charging current of the line If inductances can be connected in the protected zone common mode reactor for energized lines 87L Idyn should be greater than the maximum expected inrush cu...

Page 54: ...abled tripping of the element 87L Idyn is generally delayed by one cycle Inrush blocking can thus become effective Ground Current Differential Protection in Grounded Systems The ground current differential protection of the 7SD80 operates as a stabilized restrained differential protection in grounded systems The 2 7SD80 devices exchange the phasors of the ground currents and the associated restrai...

Page 55: ...rent at each end of the protected object fundamental component of the ground current and transmits it to the partner device The received and the locally measured ground current phasor is added to the ground differential current The ground differential current value equals the fault current that the differential protection system sees In the ideal case it equals the short circuit current In healthy...

Page 56: ...urrent 3I0diff and 3I0restr are included in the fault record Blocking Interblocking The ground current differential protection can be blocked via a binary input The blocking at one end of a protected object affects all ends via the communications link interblocking If the overcurrent protection is configured as an emergency function all devices will automatically switch to this emergency operation...

Page 57: ... If a device is switched off or if the ground differential protection is disabled or blocked in a device calculation of measured values becomes impossible The entire ground differential protection system of both ends is blocked in this case Pickup Value Ground Current Differential Protection The current sensitivity is set at address 1222 87N L I DIFF It is determined by the entire current flowing ...

Page 58: ...tion in Resonant grounded Isolated Systems The ground fault differential protection can be applied in power systems whose starpoint is not grounded or grounded through an arc suppression coil Petersen coil It is based on the power values This requires the phase voltages or the 3V0 voltage Appendix C Connection Examples Figure C 5 to be connected to the devices at both ends of the protected object ...

Page 59: ...ultant measured current may be inductive or capacitive Therefore the reactive current is not suited for direction determination of the ground current In this case only the ohmic active residual current which results from the losses of the Petersen coil can be used for direction determination This residual ground fault residual current is only about some per cent of the capacitive ground fault curr...

Page 60: ...effective The threshold checks 87N L Vph g min and 87N L Vph g max parameter 1227 and 1228 are not relevant You will find the logic diagram for the differential protection trip in Section 2 2 5 Differential Protection Pickup Logic and Tripping Logic Functions 2 2 Phase Comparison Protection and Ground Differential Protection 60 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 61: ...ied to the device may vary considerably in its values with regard to magnitude and phase angle The device however must evaluate only the active component of the ground fault current the ground fault residual current that is ΙN cosφ This requires extremely high accuracy particularly with regard to phase angle measurement of all the instrument transformers Furthermore the device must not be set to o...

Page 62: ... This signal however is required to initiate the internal or external supplementary functions e g fault recording automatic reclosing lo diff g anr 20110304 1 en_US Figure 2 15 General pickup Tripping Logic The following figure shows the tripping logic of the differential protection lo esd erd aus 20101117 2 en_US Figure 2 16 Differential protection trip If the pickup signals apply for longer than...

Page 63: ...5 00 A 1206 87L Trip Delay 0 00 0 10 sec 0 00 sec Trip Delay 1207 87L Man Close DELAYED UNDELAYED DELAYED Trip response after manual close 1208 87L T EFdetect 0 00 32 00 sec 0 00 sec Evolving fault detect time 1ph faults 1214 87L Inrush blk NO YES NO Inrush blocking 1221 87N L Protect OFF ON Alarm Only ON 87N L protection 1222 87N L I DIFF 1A 0 10 20 00 A 0 30 A 3I0 DIFF Pickup value 5A 0 50 100 0...

Page 64: ... 87 ONoffBI IntSP 87 Commissioning state ON OFF via BI 32100 87L block SP 87L Protection blocking signal 32102 87L active OUT 87L Protection is active 32103 87L Fault A OUT 87L Fault detection A 32104 87L Fault B OUT 87L Fault detection B 32105 87L Fault C OUT 87L Fault detection C 32107 87L is blocked OUT 87L Protection is blocked 32108 87L is OFF OUT 87L Protection is switched off 32109 87L allo...

Page 65: ...ally measured currents interprets them as differential current but does not send them to the other devices This enables measuring the thresholds of the differential protection Moreover the test mode prevents in the local device that tripping of the differential protection generates a transfer trip signal The test mode can be activated deactivated as follows Operation panel Menu Control Taggings Se...

Page 66: ...de S Switch Switching the differential protection test mode on off 1 Binary input as make contact 2 Binary input as break contact If a test switch is to be used for changing to test mode we recommend the following procedure Block the differential protection via a binary input Use the test switch to activate deactivate the test mode Reset the blocking of the differential protection via the binary i...

Page 67: ...is generated either when operating the integrated keypad or when oper ating with DIGSI The second way is to use the binary inputs no 3260 Comm 87 ON no 3261 Comm 87 OFF Depending on the way used for controlling the commissioning mode either the indication Comm 87 ON OFF no 3262 or Comm 87 ONoffBI no 3263 is generated The way used for deactivating the commissioning mode always has to be identical t...

Page 68: ... 1 en_US Figure 2 23 External switch wiring for controlling the differential protection commissioning mode S Switch Switching the differential protection commissioning mode on off 1 Binary input as make contact 2 Binary input as break contact Functions 2 2 Phase Comparison Protection and Ground Differential Protection 68 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 69: ...intertrip and transmitted via the protection data interfaces and communication links The send function can be triggered via binary input 85 DT 3pol remote tripping The transmission signal can be delayed with 85 DT TD BI and prolonged with 85 DT TD BI lo mitnahme sendekreis 20101108 1 en_US Figure 2 24 Logic diagram of the intertrip Transmission circuit Receive Circuit On the receiving end the sign...

Page 70: ...he intertrip signal is trans mitted as well In this case the signal to be transmitted can be delayed with address 1303 85 DT TD BI This delay stabilizes the originating signal against dynamic interferences which may possibly occur on the control cabling Address 1304 85 DT T PROL BI is used to extend a signal after it has been effectively injected from an external source The reaction of a device wh...

Page 71: ...nly Trip Trip 85 DT React if intertrip cmd is receiv 1303 85 DT TD BI 0 00 30 00 sec 0 00 sec 85 DT Delay for intertrip via bin input 1304 85 DT T PROL BI 0 00 30 00 sec 0 00 sec 85 DT Prol for intertrip via bin input 1305 85 DT Iph rel 1A 0 0 25 0 A 0 0 A 85 DT minimal Phase Current to rel trip 5A 0 0 125 0 A 0 0 A 1306 85 DT 3I0 rel 1A 0 0 25 0 A 0 0 A 85 DT minimal 3I0 Current to rel trip 5A 0 ...

Page 72: ...ackup overcurrent protection can also act as the only short circuit protection if no suitable channels for the commu nication between the protection devices are available yet during the initial commissioning It can be used as busbar protection via reverse interlocking in combination with other protection devices or as backup protec tion function for protection device failure at continuing lines No...

Page 73: ... 2 The parameter names of the 50 2 elements are listed in Section 2 4 4 Setting Notes Definite Time Overcurrent Element 50 3 The 50 3 element operates independently of the other elements Its logic corresponds to the 50 1 and 50 2 elements described above but operates non directional only If parameter 50 3 Inrush address 2653 is set to YES the element is blocked Functions 2 4 Backup overcurrent SIP...

Page 74: ...AddTdelay may be selected which is added to the inverse time The possible charac teristics are shown in the Technical Data The non directional and the directional inverse time overcurrent element 51 always uses the same character istic curve that is parameterized via 2642 IEC or 2643 ANSI Different inverse times and additional times can be parameterized here The following figure shows the logic di...

Page 75: ...s or ground and of the individual elements are interlinked in such a way that both the phase information and the element which has picked up are indicated Table 2 1 Table 2 1 Pickup signals of the single phases Internal indication Display Output indication No 50 2 PU A 50 1 PU A 50 3 PU A 51 PU A Figure 2 26 5X B Pickup ØA 7162 Functions 2 4 Backup overcurrent SIPROTEC 4 7SD80 Manual 75 E50417 G11...

Page 76: ...hase element e g 50 N B2 TRIP i i NOTE There is no indication for tripping of the grounding stages If you need information link the internal pickup signal with the OFF command of the stage e g 50 1 PU N and 50 N B2 TRIP Directional Overcurrent Protection Measured Quantities The phase currents are fed to the device via the input transformers of the measuring input The ground current 3I0 is calculat...

Page 77: ...red quantities is available an already existing result of the direction determination is used or the directional element is blocked for the corresponding phase The behavior in the even to a measuring voltage failure can be set The elements operate directionally or nondirectionally The time overcurrent protection only operates directionally if all 3 phase to ground voltages are connected Address 14...

Page 78: ...y input BLOCK 51N Additionally the ground current element can be blocked separately via the binary input BLOCK 67N TOC The binary input 5X B InstTRIP and the evaluation of the indication switch onto fault can act sepa rately on the directional phase and or ground element Parameter 67 N B2 Pil BI address 2628 determines whether a non delayed trip of this element via binary input 5X B InstTRIP is po...

Page 79: ...t of the direction determination The direction determination is accomplished using the measured quantities and the corresponding directional characteristics 67 B1 PICKUP is used as setting values for the phase current 67N B1 PICKUP is used for the ground current A trip command is issued after pickup of an element and expiration of the associated time delays 67 Functions 2 4 Backup overcurrent SIPR...

Page 80: ...tics are shown in the Technical Data The indications 67 N forward or 67 N reverse are created from the individual directional indications 7257 to 7264 determined for the phase and ground current provided that a valid directional result forward or reverse was determined for the phase or ground current These indications can then be transmitted to another device where they can cause instantaneous tri...

Page 81: ...C characteristic Pickup Logic and Tripping Logic The pickup signals of the individual phases or ground and of the individual elements are interlinked in such a way that both the phase information and the element which has picked up are indicated Table 2 2 Functions 2 4 Backup overcurrent SIPROTEC 4 7SD80 Manual 81 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 82: ...g stages If you need information link the internal pickup signal with the OFF command of the stage e g 67 1 PU N and 67 N B2 TRIP Behavior during Measuring Voltage Failure An element specific parameter e g 67 N B1 on FFM allows you to define how the directional overcurrent protection acts when the measuring voltage fails The overcurrent protection then works either Non Direc tional or it is BLOCKE...

Page 83: ...ifically for each element The setting applies collectively to the corresponding phase and ground element 50 1 3I0 address 2622 50 2 3I0 address 2612 50N 3I0p address 2632 The following settings are possible Non Directional BLOCKED The 50 3 element always operates non directionally Inrush Blocking You can specify for each element of the overcurrent protection whether the element will be blocked whe...

Page 84: ... B2 DELAY address 2627 50 B1 DELAY 67 B1 DELAY address 2614 50N B1 DELAY 67N B1 DELAY address 2617 51 B TD IEC 67 TOC TD IEC address 2634 IEC characteristic 51N B TD IEC 67N TOC TD IEC address 2639 IEC characteristic 51 B TD ANSI 67 TOC TD ANSI address 2635 ANSI characteristic 51N B TD ANSI 67N TOC TD ANSI address 2640 ANSI characteristic They are determined by the time grading chart created for t...

Page 85: ... Short Inverse Long Inverse Moderately Inv Very Inverse Extremely Inv Definite Inv The characteristics and equations they are based on are listed in the Technical Data They apply for direc tional and non directional elements alike Settings Addresses which have an appended A can only be changed with DIGSI under Additional Settings The table indicates region specific default settings Column C config...

Page 86: ...ode67 N B2 ON Only Emer prot OFF Only Emer prot Operating Mode 67 N B2 2621 67 N B2 Dir Non Directional Forward Reverse Non Directional 67 N B2 Direction 2622 67 N B2 on FFM Non Directional BLOCKED BLOCKED 67 N B2 Direct stage on Fuse Failure 2623 50 B2 PICKUP 1A 0 10 25 00 A 1 50 A 50 B2 Pickup 5A 0 50 125 00 A 7 50 A 2623 67 B2 PICKUP 1A 0 10 25 00 A 1 50 A 67 B2 Pickup threshold 5A 0 50 125 00 ...

Page 87: ...35 67 TOC TD ANSI 0 50 15 00 5 00 67 TOC Time Dial for ANSI characteristic 2636 51 B AddT DELAY 0 00 30 00 sec 5 00 sec 51 B Additional Time Delay 2636 67 TOC AddTDel 0 00 30 00 sec 5 00 sec 67 TOC Additional Time Delay 2637 51 B Inrush NO YES NO 51 B Inrush blocking 2637 67 TOC Inrush NO YES NO 67 TOC Inrush blocking 2638 51N B PICKUP 1A 0 05 4 00 A A 51N B Pickup 5A 0 25 20 00 A A 2638 67N TOC P...

Page 88: ... YES NO Instantaneous trip via Pilot Prot BI 2650 50 3 OpMo ON Only Emer prot OFF OFF 50 N 3 Operating Mode 2651 50 3 PICKUP 1A 0 10 25 00 A 1 50 A 50 3 Pickup 5A 0 50 125 00 A 7 50 A 2652 50 3 DELAY 0 00 30 00 sec 0 30 sec 50 3 Delay 2653 50 3 Inrush NO YES NO 50 3 Inrush blocking 2654 50N 3 PICKUP 1A 0 05 25 00 A 0 20 A 50N 3 Pickup 5A 0 25 125 00 A 1 00 A 2655 50N 3 DELAY 0 00 30 00 sec 2 00 se...

Page 89: ... C PICKED UP 7162 5X B Pickup ØA OUT 50 N 51 N Backup O C PICKUP Phase A 7163 5X B Pickup ØB OUT 50 N 51 N Backup O C PICKUP Phase B 7164 5X B Pickup ØC OUT 50 N 51 N Backup O C PICKUP Phase C 7165 5X B Pickup Gnd OUT 50 N 51 N Backup O C PICKUP GROUND 7191 50 N B1 PICKUP OUT 50 N B1 Pickup 7192 50 N B2 PICKUP OUT 50 N B2 Pickup 7193 51 N B PICKUP OUT 51 N B Pickup 7201 50 3 PICKUP OUT 50 3 Pickup...

Page 90: ...C is ACTIVE 17532 67 N B2 OFF OUT Backup O C stage 67 N B2 is sw OFF 17533 67 N B1 OFF OUT Backup O C stage 67 N B1 is sw OFF 17534 67 N TOC OFF OUT Backup O C stage 67 N TOC is sw OFF 17535 67 N PICKUP OUT 67 N Backup O C PICKED UP 17536 67 Pickup ØA OUT 67 Backup O C PICKUP Phase A 17537 67 Pickup ØB OUT 67 Backup O C PICKUP Phase B 17538 67 Pickup ØC OUT 67 Backup O C PICKUP Phase C 17539 67N P...

Page 91: ...that it is effective at both ends of the protected object logikdia einschaltstabilisierung 290803st 1 en_US Figure 2 32 Logic diagram of the inrush restraint for one phase Since the inrush restraint operates individually for each phase the protection is fully operative when the trans former is switched onto a single phase fault in which case it is possible for an inrush current to flow through one...

Page 92: ...e no inrush restraint The peak value is decisive The set value should be higher than the maximum inrush current peak value that can be expected For transformers set the value above 2 ΙNTransf ukTransf If a line ends on a transformer a smaller value may be selected considering the damping of the current by the line impe dance The crossblock function can be activated YES or deactivated NO in address...

Page 93: ...s 3102 2nd Harmonic A OUT Tolerance invalid in phase A 3103 2nd Harmonic B OUT Tolerance invalid in phase B 3104 2nd Harmonic C OUT Tolerance invalid in phase C 2 5 4 Functions 2 5 InRush Restraint SIPROTEC 4 7SD80 Manual 93 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 94: ...ntinues to flow and the timer runs to its set limit The breaker failure protection then issues a command to trip the backup breakers and interrupt the fault current The reset time of the feeder protection is not relevant because the breaker failure protection itself recognizes the interruption of the current For protection functions where the tripping criterion is not dependent on current e g Buch...

Page 95: ...he residual current is not available the device calculates it with the formula 3 Ι0 ΙA ΙB ΙC Additionally the value calculated by 7SD80 of three times the negative sequence current 3 Ι2 is used for plau sibility check This is calculated according to the equation 3 Ι2 ΙA a2 ΙB a ΙC where a ej120 These plausibility currents do not have any direct influence on the basic function of the breaker failur...

Page 96: ... two separate wire pairs Nevertheless it is possible to initiate the breaker failure protection in single channel mode should a separate release criterion not be available The binary input 50BF release FNo 1432 must then not be assigned to any physical input of the device during configuration Figure 2 38 shows the operating principle When the trip signal appears from any internal or external feede...

Page 97: ...reaker is signaled to be open by the auxiliary contact criterion Initiation can be blocked via the binary input BLOCK 50BF e g during test of the feeder protection relay lo svs phasengem anwurf 20101108 1 en_US Figure 2 38 Circuit breaker failure protection with common phase initiation Time Delays When the initiate conditions are fulfilled the associated timers are started The circuit breaker pole...

Page 98: ...uit Breaker Malfunction There may be cases when it is already obvious that the circuit breaker associated with a feeder protection relay cannot clear a fault e g when the tripping voltage or the tripping energy is not available In such a case it is not necessary to wait for the response of the feeder circuit breaker If provision has been made for the detection of such a condition e g control volta...

Page 99: ...operly responded to the trip command endfehler ls strwdlr wlk 010802 1 en_US Figure 2 41 End fault between circuit breaker and current transformers The end fault protection has the task to recognize this situation and to transmit a trip signal to the remote end s of the protected object to clear the fault For this purpose the output command 50BF EndFltTrip is available to trigger a signal transmis...

Page 100: ... Breaker Failure Protection With two element operation the trip command is repeated after a time delay T1 to the local feeder breaker normally to a different set of trip coils of this breaker If the circuit breaker does not respond to this trip repetition the adjacent circuit breakers are tripped after T2 i e the circuit breakers of the busbar or of the concerned busbar section and if necessary al...

Page 101: ...ts is 15 ms If current transformer saturation is anticipated the time should be set to 25 ms ls versag zeitabl 1stuf versag oz 020802 1 en_US Figure 2 44 Time sequence example for normal clearance of a fault and with circuit breaker failure using single element breaker failure protection Malfunction of the Local Circuit Breaker If the circuit breaker associated with the feeder is not operational e...

Page 102: ...t short transient apparent end fault conditions which may occur during switching of the breaker Settings The table indicates region specific presettings Column C configuration indicates the corresponding secon dary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 3901 FCT 50BF Break ON OFF ON 50BF Breaker Failure Protection 3902 50BF PICKUP 1A 0 ...

Page 103: ... oI SP 50BF External start 3p w o current 1440 BkrFailON offBI IntSP Breaker failure prot ON OFF via BI 1451 50BF OFF OUT 50BF is switched OFF 1452 50BF BLOCK OUT 50BF is BLOCKED 1453 50BF ACTIVE OUT 50BF is ACTIVE 1461 50BF Start OUT 50BF Breaker failure protection started 1476 50BF LocTripABC OUT 50BF Local trip ABC 1493 50BF TripCBdef OUT 50BF Trip in case of defective CB 1494 50BF BusTrip OUT ...

Page 104: ...mperature threshold i e the final overtemperature tripping temperature is reached the protected object is disconnected from the network The overload protection can however also be set to Alarm Only In this case only an alarm is output when the final temperature is reached The overtemperatures are calculated separately for each phase in a thermal replica from the square of the associated phase curr...

Page 105: ...rent and this rated current formel therm ueberl k fakt 1 oz 020802 1 en_US The permissible continuous current is at the same time the current at which the e function of the overtemper ature has its asymptote It is not necessary to determine the tripping temperature since it results automatically from the final rise temperature at k ΙN Manufacturers of electrical machines usually state the permissi...

Page 106: ...cted object may flow formel therm ueberl zeitkonst 3 oz 020802 1 en_US Example Cable as above with Permissible 1 s current 13 5 kA formel therm ueberl zeitkonst 4 oz 020802 1 en_US Setting value TIME CONSTANT 29 4 min Warning Temperature Level By setting a thermal alarm stage 49 Θ ALARM address 4204 an alarm can be provided before the tripping temperature is reached so that a trip can be avoided b...

Page 107: ... the corresponding secon dary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 4201 FCT 49 OFF ON Alarm Only OFF 49 Thermal overload protection 4202 49 K FACTOR 0 10 4 00 1 10 49 K Factor 4203 TIME CONSTANT 1 0 999 9 min 100 0 min Time Constant 4204 49 Θ ALARM 50 100 90 49 Thermal Alarm Stage 4205 I ALARM 1A 0 10 4 00 A 1 00 A Current Overload Al...

Page 108: ...ges by compensation of the line capacitance and thus reduction of the overvoltage the overvoltage will endanger the insulation if the reactors fail e g due to fault clearance The line must be de energized within a very short time The undervoltage protection can be applied for example for disconnection or load shedding tasks in a system Furthermore this protection scheme can detect pending stabilit...

Page 109: ...s phase to phase voltages Accordingly phase to phase voltages which have exceeded one of the element thresholds 59 1 Vpp PICKUP address 3712 or 59 2 Vpp PICKUP address 3714 are also indi cated Apart from that Figure 2 46 also applies generally The phase phase overvoltage protection can also be blocked via a binary input 59 Vphph BLOCK Functions 2 8 Undervoltage and Overvoltage Protection optional ...

Page 110: ... V1 BLOCK lo uespg mitsys 20101108 1 en_US Figure 2 47 Logic diagram of the overvoltage protection for the positive sequence voltage system Overvoltage Negative Sequence System V2 The device calculates the negative sequence system voltages according to its defining equation V2 1 3 VA a2 VB a VC where a ej120 The resulting negative sequence voltage is fed to the two threshold elements 59 1 V2 PICKU...

Page 111: ...wo threshold elements 59G 1 3V0PICKUP address 3722 and 59G 2 3V0PICKUP address 3724 Combined with the associated time delays 59G 1 3V0 DELAY address 3723 and 59G 2 3V0 DELAY address 3725 these elements form a two element over voltage protection for the zero sequence system Here too the dropout ratio can be set 59G RESET address 3729 Furthermore a restraint delay can be configured which is implemen...

Page 112: ...behavior of the undervoltage protection when the line is de energized While the voltage usually remains present or reappears on the busbar side after a trip command and opening of the circuit breaker it becomes zero on the outgoing side For the undervoltage protection this results in a pickup state being present if the voltage transformers are on the outgoing side If this pickup must be reset the ...

Page 113: ...Basically the phase to phase undervoltage protection operates like the phase to ground protection except that it detects phase to phase voltages Accordingly both phases are indicated during pickup of an under voltage element if one of the stage thresholds 27 1 Vpp PICKUP address 3762 or 27 2 Vpp PICKUP address 3764 was undershot Apart from that Figure 2 50 also applies generally Functions 2 8 Unde...

Page 114: ...two element overvoltage protection for the positive sequence system Current can be used as an additional criterion for the undervoltage protection of the positive sequence system current criterion CURR SUP 27 V1 address 3778 An undervoltage is only detected if the current flow is detected in at least one phase together with the undervoltage criterion The undervoltage protection for the positive se...

Page 115: ... tripping The 52 2 phase Vph element address 3704 is provided for high overvoltages with short duration Here an adequately high pickup value is set e g the 1 2 fold of the nominal phase to ground voltage 0 1 s to 0 2 s are then sufficient for the time delay 59 2 Vph DELAY address 3705 Overvoltage Phase to Phase Basically the same considerations apply as for the phase undervoltage elements These el...

Page 116: ...ication Here no general guidelines can be established The element 59G 1 3V0PICKUP address 3722 is usually set with a high sensitivity and a longer time delay 59G 1 3V0 DELAY address 3723 The 59G 2 3V0PICKUP element address 3724 and its time delay 59G 2 3V0 DELAY address 3725 allow to implement a second element with less sensitivity and a shorter time delay The zero voltage stages feature a special...

Page 117: ...itive Sequence System V1 The positive sequence undervoltage elements can be used instead of or in addition to previously mentioned undervoltage elements Accordingly set address 3771 27 V1 Mode to ON OFF Alarm Only or V Alarm V Trip Basically the same considerations apply as for the other undervoltage elements Especially in case of stability problems the positive sequence system is advantageous sin...

Page 118: ...up 3V0 zero seq 3723 59G 1 3V0 DELAY 0 00 100 00 sec 2 00 sec 59G 1 Time Delay 3724 59G 2 3V0PICKUP 1 0 220 0 V 50 0 V 59G 2 Pickup 3V0 zero seq 3725 59G 2 3V0 DELAY 0 00 100 00 sec 1 00 sec 59G 2 Time Delay 3728A 59G 3Vo Stabil ON OFF ON 59G Stabilization 3Vo Measure ment 3729A 59G RESET 0 30 0 99 0 95 Reset ratio 3731 59 V1 Mode OFF Alarm Only ON V Alarm V Trip OFF Operating mode V1 overvoltage ...

Page 119: ...se 3763 27 1 Vpp DELAY 0 00 100 00 sec 2 00 sec 27 1 Time Delay 3764 27 2 Vpp PICKUP 1 0 175 0 V 17 0 V 27 2 Pickup Undervoltage phase phase 3765 27 2 Vpp DELAY 0 00 100 00 sec 1 00 sec 27 2 Time Delay 3768 CURR SUP 27 Vpp ON OFF ON Current supervision Vph ph 3769A 27 Vph ph RESET 1 01 1 20 1 05 Reset ratio 3771 27 V1 Mode OFF Alarm Only ON V Alarm V Trip OFF Operating mode V1 Undervoltage prot 37...

Page 120: ...T 27 Vphg Undervolt is BLOCKED 10227 27 Vphph OFF OUT 27 Vphph Undervolt is switched OFF 10228 27 Vphph BLK OUT 27 Vphph Undervolt is BLOCKED 10229 27 V1 OFF OUT 27 V1 Undervolt is switched OFF 10230 27 V1 BLK OUT 27 V1 Undervolt is BLOCKED 10231 27 59 ACTIVE OUT 27 59 Voltage protection is ACTIVE 10240 59 1 Vpg Pickup OUT 59 1 Vphg Pickup 10241 59 2 Vpg Pickup OUT 59 2 Vphg Pickup 10242 59 Vpg PU...

Page 121: ...TimeOut 10293 59 2 V2TimeOut OUT 59 2 V2 TimeOut 10294 59 V2 TRIP OUT 59 V2 TRIP command 10300 27 1 V1 Pickup OUT 27 1 V1 Pickup 10301 27 2 V1 Pickup OUT 27 2 V1 Pickup 10302 27 1 V1TimeOut OUT 27 1 V1TimeOut 10303 27 2 V1TimeOut OUT 27 2 V1TimeOut 10304 27 V1 TRIP OUT 27 V1 TRIP command 10310 27 1 Vpg Pickup OUT 27 1 Vphg Pickup 10311 27 2 Vpg Pickup OUT 27 2 Vphg Pickup 10312 27 Vpg PU A OUT 27 ...

Page 122: ...OUT 27 Vphph TRIP command 10333 27 1 Vpp PU AB OUT 27 1 Vphph Pickup A B 10334 27 1 Vpp PU BC OUT 27 1 Vphph Pickup B C 10335 27 1 Vpp PU CA OUT 27 1 Vphph Pickup C A 10336 27 2 Vpp PU AB OUT 27 2 Vphph Pickup A B 10337 27 2 Vpp PU BC OUT 27 2 Vphph Pickup B C 10338 27 2 Vpp PU CA OUT 27 2 Vphph Pickup C A Functions 2 8 Undervoltage and Overvoltage Protection optional 27 59 122 SIPROTEC 4 7SD80 Ma...

Page 123: ...ement is set exactly to the rated frequency it is inactive Each element can be blocked via binary input and also the entire frequency protection function can be blocked Frequency Measurement The largest of the 3 phase to phase voltages is used for frequency measurement It must have an amount of at least 65 of the rated voltage which is set in parameter 204 Vnom SECONDARY Below that value frequency...

Page 124: ...nary outputs e g power swing detection of an external distance protection or by corresponding logic operations using the user defined logic CFC If however the power swing frequencies are known tripping of the frequency protection function can also be avoided by adapting the time delays of the frequency protec tion correspondingly Pickup Tripping Figure 2 52 shows the logic diagram for the frequenc...

Page 125: ...ency protection function features 4 frequency elements f1 to f4 each of which can function as over frequency element or underfrequency element Each zone can be set active or inactive This is set in addresses 3601 81 O U FREQ f1 for frequency element f1 3611 81 O U FREQ f2 for frequency element f2 3621 81 O U FREQ f3 for frequency element f3 3631 81 O U FREQ f4 for frequency element f4 The followin...

Page 126: ...f2 at fN 50 Hz Address 3613 81 2 PICKUP pickup value for frequency element f2 at fN 60 Hz Address 3614 81 2 DELAY trip delay for frequency element f2 Adresse 3622 81 3 PICKUP pickup value for frequency element f3 at fN 50 Hz Address 3623 81 3 PICKUPpickup value for frequency element f3 at fN 60 Hz Address 3624 81 3 DELAY trip delay for frequency element f3 Adresse 3632 81 4 PICKUP pickup value for...

Page 127: ...requency Prot element f2 3612 81 2 PICKUP 45 50 54 50 Hz 49 00 Hz 81 2 Pickup 3613 81 2 PICKUP 55 50 64 50 Hz 57 00 Hz 81 2 Pickup 3614 81 2 DELAY 0 00 600 00 sec 30 00 sec 81 2 Time Delay 3621 81 O U FREQ f3 ON Alarm only ON with Trip OFF ON Alarm only 81 Over Under Frequency Prot element f3 3622 81 3 PICKUP 45 50 54 50 Hz 47 50 Hz 81 3 Pickup 3623 81 3 PICKUP 55 50 64 50 Hz 59 50 Hz 81 3 Pickup ...

Page 128: ...5 81 4 picked up OUT 81 4 picked up 5236 81 1 TRIP OUT 81 1 TRIP 5237 81 2 TRIP OUT 81 2 TRIP 5238 81 3 TRIP OUT 81 3 TRIP 5239 81 4 TRIP OUT 81 4 TRIP 5240 81 1 Time Out OUT 81 1 Time Out 5241 81 2 Time Out OUT 81 2 Time Out 5242 81 3 Time Out OUT 81 3 Time Out 5243 81 4 Time Out OUT 81 4 Time Out Functions 2 9 Frequency Protection optional 81 128 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edit...

Page 129: ...loesung 20101108 1 en_US Figure 2 53 Logic diagram of the local external trip Setting Notes General In order to use the direct and remote tripping functions address 122 DTT Direct Trip must have been set to Enabled during the configuration of the device functional scope At address 2201 Direct Trip DT it can also be switched ON or OFF It is possible to set a trip delay for both the local external t...

Page 130: ...e Delay 2203 Iph rel Trip 1A 0 0 25 0 A 0 0 A Minimal Phase Current to release trip 5A 0 0 125 0 A 0 0 A 2204 3I0 rel Trip 1A 0 0 25 0 A 0 0 A Minimal 3I0 Current to release trip 5A 0 0 125 0 A 0 0 A Information List No Information Type of Informa tion Comments 4403 BLOCK DTT SP BLOCK Direct Transfer Trip option 4417 DTT Trip ØABC SP Direct Transfer Trip INPUT Phases ABC 4421 DTT OFF OUT Direct Tr...

Page 131: ... or the use of one 7SD80 with an automatic reclosing function and a second protection with its own automatic reclosing function are equally possible Functional Description Reclosing following interruption by a short circuit protection is performed by an automatic reclosing function AR An example of the normal time sequence of double reclosing is shown in the figure below ablaufdia 2 mal we wirkzei...

Page 132: ...itiate By means of the action times and the permission to start the recloser permission to be the first cycle that is executed it is possible to determine which reclose cycles are executed depending on the time it takes the protection function to trip Operating Mode of the Automatic Reclose Function The dead times these are the times from elimination of the fault drop out of the trip command or si...

Page 133: ...nary input indicates that the circuit breaker is ready to complete another CLOSE TRIP cycle The time needed by the circuit breaker to regain the ready state can be monitored by the 7SD80 This moni toring time CB TIME OUT address 3409 starts as soon as the CB indicates the not ready state The dead time may be extended if the ready state is not indicated when it expires However if the circuit breake...

Page 134: ...king the Reclosing Function Handling of Evolving Faults If reclose cycles are executed in the power system particular attention must be paid to evolving faults Sequential faults are faults which occur during the dead time after clearance of the first fault To detect an evolving fault you can select either the trip command of a protection function during the dead time or every further pickup as the...

Page 135: ...utomatic Reclosure The interaction is controlled via binary outputs and binary inputs 2889 79 1 CycZoneRel Internal automatic reclosure ready for the first reclose cycle i e releases the element of the external protection decisive for reclosure the corre sponding output can be used for the second cycle This output can be omitted if the external protection does not require an overreaching element e...

Page 136: ...osing taking place after a trip due to a short circuit is that the circuit breaker is ready for at least one OPEN CLOSE OPEN cycle at the time the automatic reclose circuit is started i e at the time of the first trip command The readiness of the circuit breaker is signaled to the device via the binary input Bkr1 Ready no 371 If no such signal is available leave the setting under address 3402 52 1...

Page 137: ...d to a trip command by a protec tion function This may also include trip commands which are received from an external device via a binary input or which have been transmitted from another end of the protected object If an external protection device operates together with the internal auto reclosure evolving fault detection with pickup presupposes that a pickup signal from the external device is al...

Page 138: ...ssible to make the dead times dependent on the type of fault detected by the initiating protection function s Table 2 3 AR control mode with PICKUP 3453 1 AR DeadT 1Flt is the dead time after 1 phase pickup 3454 1 AR DeadT 2Flt is the dead time after 2 phase pickup 3455 1 AR DeadT 3Flt is the dead time after 3 phase pickup If the dead time is to be the same for all types of faults set all three pa...

Page 139: ...r not ready This information indicates to the opera tional information system that in the event of an upcoming system fault there will be a final trip i e without reclosure If the automatic reclosure has been started this information does not appear 79 not ready Nr 2784 The automatic reclosure is not ready for reclosure at the moment In addition to the 79 is blocked No 2783 mentioned above there a...

Page 140: ... 0 01 1800 00 sec 0 50 sec Dead time after 3phase faults 3457 1 AR Dead 3Trip 0 01 1800 00 sec 0 50 sec Dead time after 3pole trip 3458 1 AR DeadT EV 0 01 1800 00 sec 1 20 sec Dead time after evolving fault 3459 1 AR 52 CLOSE YES NO NO 52 ready interrogation before reclosing 3461 2 AR START YES NO NO AR start allowed in this cycle 3462 2 AR ActionTime 0 01 300 00 sec 0 20 sec Action time 3464 2 AR...

Page 141: ... recloser ON OFF via BI 2801 79 in progress OUT 79 in progress 2809 79 T Start Exp OUT 79 Start signal monitoring time expired 2810 79 TdeadMax Exp OUT 79 Maximum dead time expired 2818 79 Evolving Flt OUT 79 Evolving fault recognition 2821 79 Td evol Flt OUT 79 dead time after evolving fault 2840 79 Tdead 3pTrip OUT 79 dead time after 3pole trip running 2843 79 Tdead 3pFlt OUT 79 dead time after ...

Page 142: ...igure shows the logic diagram lo hand ein 011010 2 en_US Figure 2 58 Logic diagram of the manual CLOSE procedure Reclosing via the integrated local control or control using DIGSI can have the same effect as manual reclosure parameter 1152 Section 2 1 6 1 Setting Notes under margin heading Circuit Breaker Status If the device has an integrated automatic reclosure the integrated manual closure logic...

Page 143: ...closing with external automatic reclosure device 52 Circuit breaker 52TC Circuit breaker trip coil CBAux Auxiliary contact of the circuit breaker Besides the manual CLOSE detection the device records any energization of the line via the integrated line energization detection This function processes a change of state of the measured quantities as well as the position of the breaker auxiliary contac...

Page 144: ... indication Line closure no 590 Parameter 1132 SI Time all Cl can be used to set the signal to a defined length These settings can only be changed via DIGSI at Display Additional Settings Figure 2 61 shows the logic diagram In order to avoid that an energization is detected mistakenly the state line open which precedes any energi zation must apply for a minimum time settable with the address 1133 ...

Page 145: ... is flowing The decisive setting for the evaluation of the measured quantities is PoleOpenCurrent address 1130 for the presence of the currents In 7SD80 the position of the circuit breaker poles detected by a device is also transmitted to the remote end device Thus the circuit breaker positions at both ends are known lo ls stellung 2010112 1 en_US Figure 2 62 Circuit breaker position logic For Aut...

Page 146: ...formation on the circuit breaker position is not automatically derived from the position logic according to the above section For the circuit breaker test there are separate binary inputs for position feedback These must be taken into consideration when routing the binary inputs The device generates indications that show the corresponding test status ein aus pruefzyklus wlk 170902 1 en_US Figure 2...

Page 147: ...ime No other settings are required for the transmission of binary information The device sends the injected infor mation to the device at the end of the protected object Information List No Information Type of Informa tion Comments 3549 Rem Signal 1 SP Remote Signal 1 input 3550 Rem Signal 2 SP Remote Signal 2 input 3551 Rem Signal 3 SP Remote Signal 3 input 3552 Rem Signal 4 SP Remote Signal 4 in...

Page 148: ...T Remote signal 11 received 3584 Rem Sig 12 Rx OUT Remote signal 12 received 3585 Rem Sig 13 Rx OUT Remote signal 13 received 3586 Rem Sig 14 Rx OUT Remote signal 14 received 3587 Rem Sig 15 Rx OUT Remote signal 15 received 3588 Rem Sig 16 Rx OUT Remote signal 16 received Functions 2 13 Direct Remote Trip and Transmission of Binary Information 148 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Editi...

Page 149: ...cyclically and compared to the cross sum that is freshly generated each time a setting process has taken place If a malfunction occurs the processor system is restarted Sampling Sampling and synchronism between the internal buffer components are monitored constantly If any occur ring deviations cannot be removed by renewed synchronization the processor system is restarted Measured Value Acquisitio...

Page 150: ...d Error LED lights up The readiness relay drops out and indicates device malfunction with its normally closed contact Offset Monitoring This monitoring function checks all ring buffer data channels for corrupt offset replication of the analog digital transformers and the analog input paths using offset filters Possible offset errors are detected using DC filters and the associated sampled values a...

Page 151: ...ail I balance no 163 stromsymmetrieueberwachung 020313 kn 1 en_US Figure 2 65 Current symmetry monitoring Voltage Balance During healthy system operation a certain balance of the voltages can be assumed The monitoring of the measured values in the device checks this balance The smallest phase to phase voltage is compared to the largest Imbalance is recognized if Vmin Vmax BAL FACTOR V solange Vmax...

Page 152: ... monitoring supplied by the device at the other end of the protected object At each sampling moment the function checks whether there is a jump in one of the three phase currents if there is it gener ates the suspected wire break signal There is a suspected local wire break if a jump has been detected in the affected phase and the current has dropped to 0 A WARNING If the CT secondary circuits are...

Page 153: ...urrent of more than 2 ΙNom A phase current of such a magnitude is a certain indicator of a power system fault When a wire break has been detected according to the above criteria it is signaled via the protection data interface to the device at the other end of the protected object and leads immediately to a wire break message The differential protection functions are blocked as well if this has be...

Page 154: ...rt circuit fault or a broken conductor in the voltage transformer secondary circuit certain measuring loops may mistakenly see a voltage of zero Simultaneously existing load currents may then cause spurious pickup If fuses are used instead of a secondary miniature circuit breaker VT mcb with connected auxiliary contacts then the Fuse Failure Monitor can detect problems in the voltage transformer s...

Page 155: ...efore the zero sequence voltage is not evaluated in such systems but only the negative sequence voltage and the ratio of negative sequence voltage to positive sequence voltage As soon as this state is recognized all functions that operate on the basis of undervoltage are blocked The immediate blocking requires that current flows in at least one of the phases The differential protection can be swit...

Page 156: ...re 2 70 A 3 pole measuring voltage failure is detected if All 3 phase to ground voltages assume a value smaller than the threshold value FFM V max 3ph address 2913 The current differential in all 3 phases is smaller than the threshold value FFM Idiff 3ph address 2914 If such a voltage failure is recognized the protection functions that operate on the basis of undervoltage are blocked until the vol...

Page 157: ...oltage failure is detected before the protection picks up If this monitoring function picks up the indication Fail V absent no 168 is generated The effect of this monitoring indication is described in the following section Impact of the Measuring Voltage Failure lo zusaetzl messspgausfall 110428 1 en_US Figure 2 71 Logic diagram of the additional measuring voltage failure detection Fail V absent I...

Page 158: ... life status contact The red ERROR LED on the device front lights up provided that there is an internal auxiliary voltage and the green RUN LED goes off If the internal auxiliary voltage supply fails all LEDs are dark Table 2 4 shows a summary of the monitoring functions and the fault responses of the device Table 2 4 Summary of the Device s Fault Responses Monitoring Possible causes Fault respons...

Page 159: ... blocked VT FuseFail 10s 169 VT FuseFail 170 as routed Voltage failure 3 phase External power system or connection Indication Undervoltage protection blocked Fail V absent 168 as routed Trip circuit supervision External trip circuit or control voltage Indication 74TC Trip cir 6865 as routed 1 Following three unsuccessful restarting attempts the device is put out of operation 2 DOK Device OK NC con...

Page 160: ... a phase voltage fails but not such that false activation occurs during ground faults in a grounded network Address 2912 FFM I max must be set as sensitive as required with ground faults below the smallest fault current These settings can only be changed via DIGSI at Display Additional Settings In address 2910 FUSE FAIL MON the Fuse Failure Monitor can be switched OFF e g during asymmetrical testi...

Page 161: ...14A FFM Idiff 3ph 1A 0 05 1 00 A 0 10 A Differential Current Threshold 3phase 5A 0 25 5 00 A 0 50 A 2915 V Supervision w CURR SUP w I 52a OFF w CURR SUP Voltage Failure Supervision 2916A T V Supervision 0 00 30 00 sec 3 00 sec Delay Voltage Failure Supervision 2931 BROKEN WIRE ON OFF Alarm only OFF Fast broken current wire supervision 2933 FAST Σ i SUPERV ON OFF ON State of fast current summation ...

Page 162: ... potential supervision with one or two binary inputs can be selected If the routing of the binary inputs required for this does not comply with the selected monitoring mode an alarm is given TripC1 ProgFAIL with identification of the non compliant circuit When using two binary inputs malfunctions in the trip circuit can be detected under all circuit breaker condi tions When only one binary input i...

Page 163: ... A state in which both binary inputs are not activated L is only possible in intact trip circuits for a short tran sition period trip relay contact closed but circuit breaker not yet open A continuous state of this condition is only possible when the trip circuit has been interrupted a fault exists in the trip circuit a loss of battery voltage occurs or malfunctions occur with the circuit breaker ...

Page 164: ...ast twice as high as the minimum voltage drop at the binary input VCtrl 2 VBImin Since at least 19 V are necessary at the binary input this supervision can be used with a system control voltage higher than 38 V A calculation example for the resistance shunt R is shown in the configuration notes in Section Mounting and Connections margin Trip Circuit Supervision prinzip ausloesekrueb 1 be wlk 01080...

Page 165: ...n address 4002 No of BI If routing of the required binary inputs does not comply with the selected supervision mode the alarm TripCx Prog FAIL is given with identification of the non compliant circuit Monitoring with One Binary Input The alarm for monitoring with two binary inputs is always delayed by approx 1 s to 2 s whereas the time delay of the alarm for monitoring with one binary input can be...

Page 166: ...ision OFF 6865 74TC Trip cir OUT 74TC Failure Trip Circuit 6866 74TC 1 ProgFAIL OUT 74TC 1 blocked Binary input is not set 6867 74TC 2 ProgFAIL OUT 74TC 2 blocked Binary input is not set 6868 74TC 3 ProgFAIL OUT 74TC 3 blocked Binary input is not set Functions 2 14 Monitoring Functions 166 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 167: ...nt monitoring 50 50G 37 X X Ιrms True RMS r m s value Overcurrent protection Thermal overload protec tion Undercurrent monitoring 50 50G 37 X X 3Ι0 Zero sequence system Time overcurrent protec tion ground 50N X Ι1 Positive sequence component X Ι2 Negative sequence component Negative sequence protec tion 46 X Ι2 Ι1 Positive negative sequence component ratio X Frequency f Frequency Frequency protect...

Page 168: ...can be tailored to assume a specific protective function for a concrete application in parameters OPERRAT MODE MEAS QUANTITY MEAS METHOD and PICKUP WITH Parameter OPERRAT MODE can be set to specify whether the function works 3 phase 1 phase or no reference i e without a fixed phase reference The three phase method evaluates all three phases in parallel This implies that threshold evaluation pickup...

Page 169: ...p time delay and the fault log This is not the case if set to Alarm only If the threshold violation persists after the trip time delay has elapsed the trip will be initiated upon its expiration no 235 2126 00 TRIP The timeout is reported via no 235 2125 00 Time Out Expiry of the trip time delay can be blocked via binary input no 235 2113 00 BLK TDly The time delay will not be started as long as th...

Page 170: ...Function AR The AR cannot be started directly To cooperate with AR the trip command of the flexible function must be linked with the binary input No 2716 79 TRIP 3p via CFC To use an action time the pickup of the flexible function must additionally be linked to the binary input No 2711 79 Start Fuse Failure Monitor see description at Blocking Functions With inrush restraint A direct cooperation wi...

Page 171: ... rising df dt falling Binary Input Measurement Methods The measurement methods shown in the following tables can be parameterized for the measurands current voltage and power Additionally the dependencies of the available measurement methods on the parameter ized operating method and measurand are shown Table 2 8 Parameter in the Setting Dialog Measurement Procedure Mode of Operation 3 phase Param...

Page 172: ...ulty voltage drops to zero the affected phase to ground voltage is thus zero and the respec tive phase to phase voltages drop to the variable of a phase to ground voltage i i NOTE We see a special behavior of the phase selective pickup indications for the 3 phase voltage protection with phase to phase quantities as the phase selective pickup indication Flx01 Pickup Lx is assigned to the correspond...

Page 173: ...er threshold values it is important to take into consideration that a minimum current of 0 03 ΙN is required for power calculation The power calculation is blocked for lower currents The dropout of pickup can be delayed via parameter T DROPOUT DELAY This setting is also set to zero by default standard setting A setting deviating from zero may be required if the device is utilized together with ele...

Page 174: ...egion specific default settings Column C configuration indicates the corresponding secondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 0 FLEXIBLE FUNC OFF ON Alarm Only OFF Flexible Function 0 OPERRAT MODE 3 phase 1 phase no reference 3 phase Mode of Operation 0 MEAS QUANTITY Please select Current Voltage P forward P reverse Q forward Q re...

Page 175: ...T TRIP DELAY 0 00 3600 00 sec 1 00 sec Trip Time Delay 0 T PICKUP DELAY 0 00 60 00 sec 0 00 sec Pickup Time Delay 0 T PICKUP DELAY 0 00 60 00 sec 0 00 sec Pickup Time Delay 0A T DROPOUT DELAY 0 00 60 00 sec 0 00 sec Dropout Time Delay 0A BLK by Vol Loss NO YES YES Block in case of Meas Voltage Loss 0A DROPOUT RATIO 0 70 0 99 0 95 Dropout Ratio 0A DROPOUT RATIO 1 01 3 00 1 05 Dropout Ratio 0A DO di...

Page 176: ...cked up 235 2122 00 pickup A OUT Function 00 Pickup Phase A 235 2123 00 pickup B OUT Function 00 Pickup Phase B 235 2124 00 pickup C OUT Function 00 Pickup Phase C 235 2125 00 Time Out OUT Function 00 TRIP Delay Time Out 235 2126 00 TRIP OUT Function 00 TRIP 235 2128 00 inval set OUT Function 00 has invalid settings Functions 2 15 Flexible Protection Functions 176 SIPROTEC 4 7SD80 Manual E50417 G1...

Page 177: ... drop out all fault messages are entered in the trip log Initialization of fault storage The storage and maintenance of fault values can also be made dependent on the occurrence of a trip command Generation of spontaneous indications Certain fault indications can be displayed as spontaneous indica tions see margin heading Spontaneous indications This indication can also be made dependent on the ge...

Page 178: ...hat the value falls below the setting in address 1130 PoleOpenCurrent see above If Current AND 52a is set the circuit breaker auxiliary contact must also send a message that the circuit breaker is open This setting requires the position of the auxiliary contact to be routed via a binary input If this additional condition is not required for resetting the trip command e g if test sockets are used f...

Page 179: ...device or using DIGSI on a PC For each case please ensure that the corresponding logic operations security measures etc are taken into account when routing the binary inputs and outputs and may have to be considered when creating the user defined logic functions See also the SIPROTEC 4 System Description Breaker Tripping Alarm Suppression While every trip command by a protection function is final ...

Page 180: ...itched off or due to other reasons is not ready for automatic reclosure e g tripping only occurred after the action time expired Figure 2 81 shows time diagrams for manual trip and close as well as for short circuit tripping with a single failed automatic reclosure cycle schalterfall meldeunterdrueck ablauf wlk 020802 1 en_US Figure 2 81 Breaker tripping alarm suppression sequence examples Functio...

Page 181: ...out if the self check feature of the microprocessor recognizes an abnormal occurrence or if the auxiliary voltage is lost When auxiliary voltage is present but the relay has an internal malfunction then the red LED ERROR lights up and the relay is blocked Information via Display Field or PC Using the front PC interface or the port B at the bottom a personal computer can be connected to which the i...

Page 182: ...n 1 en_US Figure 2 82 Display of spontaneous messages in the display example Retrievable Messages The messages for the last eight network faults can be retrieved and read out The definition of a network fault is such that the time period from fault detection up to final clearing of the disturbance is considered to be one network fault If auto reclosing occurs then the network fault ends after the ...

Page 183: ...ice registers the value of each current phase that was switched off in each pole This information is then provided in the trip log and summated in a register The maximum current that was switched off is also stored Measured values are indicated in primary values Transmission Statistics In 7SD80 the protection communication is registered in statistics The runtimes of the information between the dev...

Page 184: ...ctions always use the locally measured frequency For the thermal overload protection the calculated overtemperatures are indicated in relation to the trip over temperature Overload measured values can appear only if the overload protection was configured Enabled The power and operating values upon delivery are set such that power in line direction is positive Active components in line direction an...

Page 185: ...ation List No Information Type of Informa tion Comments 601 Ia MV Ia 602 Ib MV Ib 603 Ic MV Ic 610 3I0 MV 3I0 zero sequence 611 3I0sen MV 3I0sen sensitive zero sequence 612 Ig MV Ig grounded transformer 613 3I0par MV 3I0par parallel line neutral 619 I1 MV I1 positive sequence 620 I2 MV I2 negative sequence 621 Va MV Va 622 Vb MV Vb 623 Vc MV Vc 624 Va b MV Va b 625 Vb c MV Vb c 626 Vc a MV Vc a 62...

Page 186: ... Information List No Information Type of Informa tion Comments 7748 Diff3I0 MV Diff3I0 Differential current 3I0 32226 Rest3I0 MV Rest3I0 Operational nominal current Measured Values Constellation Functional Description The measured values of the constellation of both possible devices are shown here by evaluating the device see Table 2 12 Information on the second device is given in the Appendix The...

Page 187: ...power S the frequency and the power factor cos φ a formed as primary values including the date and time they were last updated The minimum and maximum values of the long term mean values listed in the next section are also calcu lated The minimum and maximum values can be reset at any time via binary inputs or by using the integrated control panel or the DIGSI software Additionally the reset can b...

Page 188: ... MIN MAX Buffer Reset 407 Frq MiMa Reset SP Frq MIN MAX Buffer Reset 408 PF MiMaReset SP Power Factor MIN MAX Buffer Reset 837 IAdmdMin MVT I A Demand Minimum 838 IAdmdMax MVT I A Demand Maximum 839 IBdmdMin MVT I B Demand Minimum 840 IBdmdMax MVT I B Demand Maximum 841 ICdmdMin MVT I C Demand Minimum 842 ICdmdMax MVT I C Demand Maximum 843 I1dmdMin MVT I1 positive sequence Demand Minimum 844 I1dm...

Page 189: ... 1046 Qmin Rev MVT Reactive Power Minimum Reverse 1047 Qmax Rev MVT Reactive Power Maximum Reverse 1048 PFminForw MVT Power Factor Minimum Forward 1049 PFmaxForw MVT Power Factor Maximum Forward 1050 PFmin Rev MVT Power Factor Minimum Reverse 1051 PFmax Rev MVT Power Factor Maximum Reverse 10102 3V0min MVT Min Zero Sequence Voltage 3V0 10103 3V0max MVT Max Zero Sequence Voltage 3V0 Demand Measurem...

Page 190: ... Setting Options Default Setting Comments 2801 DMD Interval 15 Min 1 Sub 15 Min 3 Subs 15 Min 15 Subs 30 Min 1 Sub 60 Min 1 Sub 60 Min 1 Sub Demand Calculation Intervals 2802 DMD Sync Time On The Hour 15 After Hour 30 After Hour 45 After Hour On The Hour Demand Synchronization Time Information List No Information Type of Informa tion Comments 833 I1 dmd MV I1 positive sequence Demand 834 P dmd MV ...

Page 191: ...ground They can be called up at the front of the device read out via the operating interface using a PC with DIGSI or trans ferred to a central master station via the system interface Energy Metering 7SD80 integrates the calculated power as a function of time and then provides the results under Measured Values The components as listed in Table 2 13 can be read out The signs of the operating values...

Page 192: ...d address 201 Information List No Information Type of Informa tion Comments Meter res IntSP_Ev Reset meter 888 Wp puls PMV Pulsed Energy Wp active 889 Wq puls PMV Pulsed Energy Wq reactive 916 WpΔ Increment of active energy 917 WqΔ Increment of reactive energy 924 Wp MVMV Wp Forward 925 Wq MVMV Wq Forward 928 Wp MVMV Wp Reverse 929 Wq MVMV Wq Reverse 2 17 9 2 2 17 9 3 Functions 2 17 Auxiliary Func...

Page 193: ...urn to the control mode via one of these keys Then select the switchgear to be operated with the help of the navigation keys The switching direction is determined by operating the I or O pushbutton The selected switching direction is displayed flashing in the bottom line of the following security prompt Password and security prompts prevent unintended switching operations With Enter the entries ar...

Page 194: ...perationcounter 31002 Q2 OpCnt VI Q2 operationcounter 31008 Q8 OpCnt VI Q8 operationcounter 31009 Q9 OpCnt VI Q9 operationcounter Types of Commands In conjunction with the power system control several command types can be distinguished for the device Functional Description Commands to the Process These are all commands that are directly output to the switchgear to change their process state Switch...

Page 195: ...uccessfully concluded Standard Interlocking checks are provided for each individual control command Additionally user defined interlocking conditions can be programmed separately for each command The actual execution of the command is also monitored afterwards The overall command task procedure is described in brief in the following list Functional Description Check Sequence Please observe the fol...

Page 196: ...ata base feedbacks of the bay unit Cross bay interlocking via GOOSE messages directly between bay units and protection relays with IEC61850 The inter relay communication with GOOSE is performed via the EN100 module The extent of the interlocking checks is determined by the configuration of the relay To obtain more informa tion about GOOSE please refer to the SIPROTEC 4 System Description Switching...

Page 197: ... for each switching device which can be individually enabled or disabled using parameters Device Status Check set actual The switching command is rejected and an error indication is displayed if the circuit breaker is already in the set position If this check is enabled then it works whether interlocking e g zone controlled is activated or deactivated This condition is checked in both interlocked ...

Page 198: ...en Switching Authority REMOTE will be accepted by the device Remote switching commands will be rejected Switching Authority REMOTE A remote control command command with command source REMOTE is only allowed if the Key Switch for devices without key switch via configuration is set to REMOTE schutz standardverriegelungen 090902 kn 1 en_US Figure 2 84 Standard interlockings The following figure shows...

Page 199: ... Protection blocking B B Control Logic using CFC For bay interlocking a release logic can be created using CFC Via specific release conditions the information released or bay interlocked are available e g object 52 Close and 52 Open with the data values ON OFF Switching Authority The interlocking condition Switching Authority serves for determining the switching authority It enables the user to se...

Page 200: ...ed with SC3 LOCAL Command Issued from SC LOCAL or REMOTE Command issued from SC DIGSI LOCAL not registered Allowed Interlocked 2 switching authority LOCAL Interlocked DIGSI not registered LOCAL Checked Allowed Interlocked 2 switching authority LOCAL Interlocked 2 switching authority LOCAL verrie gelt da VORORT Steuerung REMOTE Not checked Interlocked 1 switching authority REMOTE Allowed Interlocke...

Page 201: ... arrived all command objects subject to the interlocking are checked to know whether a command is being processed While the command is being executed interlocking is enabled for other commands Blocking by Protection The pickup of protective elements blocks switching operations Protective elements are configured separately for each switching component to block specific switching commands sent in CL...

Page 202: ...on the serial digital interface The acknowledgment of commands is therefore not executed by a response indication as it is done with the local command but by ordinary command and feedback information recording Monitoring of Feedback Information The processing of commands monitors the command execution and timing of feedback information for all commands At the same time the command is sent the moni...

Page 203: ...5 seconds Set the contrast in the menu with the scrolling keys downward less contrast upward more contrast Entry of Negative Signs Only a few parameters can reach a negative value i e a negative sign can only be entered for these If a negative sign is permissible the prompt v appears in the bottom line when changing the param eter The sign can be determined via the scrolling keys downward negative...

Page 204: ...undbild parameter 20070404 1 en_US Figure 2 87 Representation of the active parameter group line 6 Functions 2 19 Notes on Device Operation 204 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 205: ...th the relevant safety rules and guidelines Under certain circumstances it may become necessary to adapt parts of the power system hardware Some of the primary tests require the protected line or equipment to carry load 3 1 Mounting and Connections 206 3 2 Checking Connections 222 3 3 Commissioning 227 3 4 Final Preparation of the Device 247 3 SIPROTEC 4 7SD80 Manual 205 E50417 G1100 C474 A2 Editi...

Page 206: ...ix C Connection Examples examples for the possibilities of the current transformer connections in dependence on network conditions are displayed For normal connection address 220 I4 transformer In prot line must be set and furthermore address 221 I4 Iph CT 1 000 When using separate ground current transformers address 220 I4 transformer In prot line must be set The factor 221 I4 Iph CT may deviate ...

Page 207: ...ram Wahl1 Param Wahl2 no no Group A yes no Group B no yes Group C yes yes Group D einstellgruppenumschaltung ueber binaere 160502 wlk 1 en_US Figure 3 1 Connection diagram example for setting group switching using binary inputs Trip Circuit Supervision 74TC It must be noted that two binary inputs or one binary input and one bypass resistor R must be connected in series The pick up threshold of the...

Page 208: ...stant current with activated BI 0 4 mA VBI min Minimum control voltage for BI 19 V at delivery setting for nominal voltages of 24 V 48 V 88 V at delivery setting for nominal voltages of 60 V 110 V 125 V 220 V 250 V VCTR Control voltage for trip circuit RCBTC Ohmic resistance of the circuit breaker coil VCBTC LOW Maximum voltage on the circuit breaker coil that does not lead to tripping If the calc...

Page 209: ...0 kΩ is selected the following applies for the power beispiel leistungvonr 20061211 1 en_US Hardware Modifications Disassembly Work on the Printed Circuit Boards i i NOTE Before carrying out the following steps make sure that the device is not operative i i NOTE Apart from the communication modules and the fuse there are no further components that can be config ured or operated by the user inside ...

Page 210: ...insert the terminal blocks back into the device like assembled terminals Sections Panel Flush Mounting Panel Surface Mounting or Cubicle Mounting In order to install or exchange communication modules or to replace the fuse proceed as follows Remove the two covers at the top and bottom Thus 1 housing screw each at the top and bottom becomes accessible First only unscrew the bottom housing screw so ...

Page 211: ... without housing Replacing the Fuse The fuse holder is located at the edge of the basic I O board close to the power supply connection Mounting and Commissioning 3 1 Mounting and Connections SIPROTEC 4 7SD80 Manual 211 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 212: ... the device to Siemens for repair The device can now be reassembled again see Section Reassembly Connections of the Current Terminals Fixing Elements The fixing elements for the transformer connection are part of the current terminal housing side They have a stress crack and corrosion resistant alloy The head shape of the terminal screw allows for using a flat screwdriver 5 0 x 1 0 mm or a crossti...

Page 213: ...an be used with terminal points in a stacked arrangement When using jumpers only ring lugs are allowed When connecting single wires the following cross sections are allowed Cable cross section AWG 14 10 2 0 mm2 to 5 2 mm2 Connector sleeve with plastic collar L 10 mm 0 39 in or L 12 mm 0 47 in Stripping length when used without conductor sleeve 15 mm 0 59 in Use exclusively solid copper conductors ...

Page 214: ...he connected components are designed for the following mechanical requirements Permissible tightening torque at the terminal screw 1 0 Nm 8 85 lb in Permissible traction per connected conductor 50 N based on IEC 60947 1 VDE 660 Part 100 Interface Modules General The 7SD80 relay is supplied with preconfigured interfaces according to the ordering version You do not have to make any adaptations to th...

Page 215: ...et been existing is retrofitted If a SIPROTEC 4 communication module has to be removed or replaced the steps are to be performed in reverse order i i NOTE Installation is only possible alone or before installing the optical fiber protection interface If an optical fiber protection data interface exists it has to be removed before installing the SIPROTEC 4 communication module As shown in the follo...

Page 216: ... longest connection elements of the communication module can be moved in this space between the lower supporting plate reinforcement and the locking latch in the direction of the transformer module The mounting bracket of the module is now drawn up to the stop in the direction of the lower supporting plate reinforcement Thus the 60 pin plug connector on the module and the basic I O board are align...

Page 217: ... housing Press the left housing wall slightly out and insert the electronics block carefully further into the housing When the front edge of the housing and the inside of the front plate touch center the front plate by carful lateral movements This makes sure that the front plate encloses surrounds the housing The electronics block can only be inserted centered up to the end stop Fix the front cov...

Page 218: ...t abdeckungen 20071107 1 _ Figure 3 10 Housing with covers front 7sj80 ohne abdeckungen 20071107 1 _ Figure 3 11 Housing with fixing holes without covers Panel Flush Mounting The housing housing size 1 6 has 2 covers and 4 fixing holes 3 1 3 3 1 3 1 3 1 3 2 Mounting and Commissioning 3 1 Mounting and Connections 218 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 219: ...n and the details on the connection technique for the current and voltage terminals on the rear of the device in the Sections Connections of the Current Terminals and Connections of the Voltage Terminals must be strictly observed schalttafeleinbau 7sj80 1 6tel gehaeuse 20070107 1 en_US Figure 3 12 Panel flush mounting of a 7SD80 Cubicle Mounting To install the device in a rack or cubicle two mount...

Page 220: ...S Figure 3 13 Example installation of a 7SD80 in a rack or cubicle Panel Surface Mounting When ordering the device as surface mounting case 9th digit of the ordering number B the mounting frame shown below is part of the scope of delivery For installation proceed as follows Drill the holes for the mounting frame into the control panel Fasten the mounting frame with 4 screws to the control panel th...

Page 221: ...terminals on the rear of the device in the Sections Connections of the Current Terminals and Connections of the Voltage Terminals must be strictly observed Insert the device into the mounting frame make sure that no cables are jammed Secure the device to the mounting frame with 4 screws For dimensional drawings refer to the Technical Data Section 4 19 Dimensions montagehalterung 20070116 1 en_US F...

Page 222: ...g figures usb schnittst auf geraetefrontseite 20070111 1 en_US Figure 3 15 USB interface ethernet anschluss b 100801 1 en_US Figure 3 16 Ethernet connections at the device bottom side wirk ss a 7sd80 100801 1 en_US Figure 3 17 FO protection data interface at the device bottom side port A 3 2 3 2 1 Mounting and Commissioning 3 2 Checking Connections 222 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 ...

Page 223: ...Appendix in Section A Ordering Information and Accessories Accessories Connections at port B Table 3 3 Assignments of the port B sockets Pin No RS232 RS232 time synchroni zation2 RS485 Profibus DP RS485 Modbus RS485 DNP3 0 RS485 Ethernet EN 100 IEC 60870 5 103 redundant 1 Shield with shield ends electrically connected Tx B B RxD TxD P 2 RxD Tx A A RxD TxD N 3 TxD A A RxD TxD N B B RxD TxD P A Rx 4...

Page 224: ...optic Cables WARNING Laser Radiation Do not look directly into the fiber optic elements Signals transmitted via optical fibers are unaffected by interference The fibers guarantee electrical isolation between the connections Transmit and receive connections are represented by symbols The standard setting of the character idle state for the optical fiber interface is Light off If the character idle ...

Page 225: ...ARNING Warning of dangerous voltages Non observance of the following measures can result in death personal injury or substantial prop erty damage Therefore only qualified people who are familiar with and adhere to the safety procedures and precautionary measures should perform the inspection steps CAUTION Take care when operating the device without a battery on a battery charger Non observance of ...

Page 226: ... level and if applicable the polarity of the voltage at the device terminals or at the connection modules The current input should correspond to the power input in neutral position of the device The measured steady state current should be insignificant Transient movement of the ammeter merely indicates the charging current of capacitors Remove the voltage from the power supply by opening the prote...

Page 227: ... the device with secondary test equipment make sure that no other measurement quantities are connected and that the trip and close circuits to the circuit breakers and other primary switches are discon nected from the device DANGER Hazardous voltages during interruptions in secondary circuits of current transformers Non observance of the following measure will result in death severe personal injur...

Page 228: ...ronization sources are used the data of the time source antenna system time gener ator are checked see Technical Data under Time Synchronization A correct function IRIG B DCF77 is recognized in such a way that 3 minutes after the startup of the device the clock status is displayed as synchronized accompanied by the message Alarm Clock OFF For further information see SIPROTEC 4 Systemdescription Ta...

Page 229: ...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 half of the screen Double click Generate Indications in the list view The Generate Indications dialog box opens see following figure Structure of the Test Dialog Box In the column Indication the display texts of all indications are disp...

Page 230: ...t click on Close The device is briefly out of service while the start up routine is executed The dialog box closes Test in Command Direction The information transmitted in command direction must be indicated by the central station Check whether the reaction is correct Configuring Communication Modules Required Settings in DIGSI 4 The following applies in general In the case of a first time install...

Page 231: ...ocols at device the following Display of the selected communication module Selection Mapping file listing all Profibus DP Modbus DNP3 0 and VDEW Redundant mapping files available for the respective device type with their names and reference to the corresponding bus mapping document Edit field Module specific settings for changing the bus specific parameters auswahl mapping 071122 1 en_US Figure 3 ...

Page 232: ...e dialog box Interface settings Select the bus mapping corresponding to your requirements The documentation of the individual bus mappings is available on the Internet www siprotec com in the download area After having selected the bus mapping the area of the mapping file in which you can make device specific settings appears in the window see Figure 3 24 The type of this setting depends of the pr...

Page 233: ...mask 255 255 255 0 the IP bandwidth 192 168 64 xx is not available For subnet mask 255 255 255 0 the IP Band 192 168 1 xx is not available For subnet mask 255 255 0 0 the IP bandwidth 192 168 xx xx is not available For subnet mask 255 0 0 0 the IP band 192 xx xx xx is not available Checking the Status of Binary Inputs and Outputs Prefacing Remarks The binary inputs outputs and LEDs of a SIPROTEC 4...

Page 234: ...he function selection appears in the right half of the screen Double click in the list view on Hardware Test The dialog box of the same name opens see the following figure Structure of the Test Dialog Box The dialog box is classified into three groups BI for binary inputs REL for output relays and LED for lightemit ting diodes On the left of each of these groups is an accordingly labeled button By...

Page 235: ...ardware test function This for example means that a switching 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 Ensure that the switching of the output relay can be executed without danger see above under DANGER Each output relay must be tested via the corresponding Sche...

Page 236: ...pdating the Display As the Hardware Test dialog opens the operating states of the hardware components which are current at this time are read in and displayed An update is made for each hardware component if a command to change the condition is successfully performed for all hardware components if the Update button is clicked for all hardware components with cyclical updating cycle time is 20 seco...

Page 237: ...data interface connected with no 3244 is provided with the device index of the other device in case of a copper connection a link has been established and one device has recognized the other The device indicates Slave Login no 3492 or Master Login no 3491 if the other device has been detected In case of an incorrect communication link the indication PDI FO faulty no 3230 or PDI Cu faulty no 3232 i...

Page 238: ... is used the integration of this protection function in the system must be tested under practical conditions Due to the variety of application options and the available system configurations it is not possible to make a detailed description of the necessary tests It is important to observe local conditions and protection and system drawings Before starting the circuit breaker tests it is recommend...

Page 239: ...ed A general detailed test guide cannot be specified because the layout of the adjacent circuit breakers largely depends on the system topology In particular with multiple busbars the trip distribution logic for the adjacent circuit breakers must be checked Here it should be checked for every busbar section that all circuit breakers which are connected to the same busbar section as the feeder circ...

Page 240: ...s if there are phase to phase voltages which are almost equal to the phase to ground voltages instead of having a value that is 3 larger The meas urements are to be repeated after correcting the connections In general the phase rotation is a clockwise phase rotation If the system has an anti clockwise phase rotation this must be identical at all ends of the protected object The phase assignment of...

Page 241: ...0 phase current one or two phase currents are missing 3 Ι0 twice the phase current one or two phase currents have a reversed polarity The measurements are to be repeated after correcting the connections Polarity Check If the device is connected to voltage transformers the local measured values already allow a polarity check A load current of at least 5 of the rated operational current is still req...

Page 242: ...ons The above described tests of the measured values also have to be performed at the other end of the tested current path The current and voltage values as well as the phase angles of the other end can also be read out locally as percentage values Please observe that currents flowing through the object without charging currents ideally have opposite signs at both ends i e they are turned by 180 T...

Page 243: ...lled up in the PC via the operator or service interface and compared with the actual measured quantities as primary or secondary values The absolute values as well as the phase differences of the voltages are indicated so that the correct phase sequence and polarity of individual transformers can also be seen The same manipulation is carried out with the current and voltage transformers at the oth...

Page 244: ...he signal transmission path is the same and has already been checked as part of the previous subsections it needs not be checked again here A function check is sufficient whereby the externally derived command is executed For this purpose the external tripping event is simulated and the response of the circuit breaker at the opposite line end is verified Checking User defined Functions The device ...

Page 245: ...mmands used Triggering Oscillographic Recording for Test In order to test the stability of the protection during switch on procedures also switch on trials can also be carried out at the end Oscillographic records obtain the maximum information about the behavior of the protection Prerequisite Along with the possibility of storing fault records via pickup of the protection function the 7SD80 also ...

Page 246: ...ing the recording an annunciation is output in the left area of the status line Bar segments additionally indicate the progress of the procedure The SIGRA or the Comtrade Viewer program is required to view and analyze the oscillographic data Mounting and Commissioning 3 3 Commissioning 246 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 247: ...counters in the switching statistics should be reset to the values that were existing prior to the testing see also SIPROTEC 4 System Description The counters of the operational measured values e g operation counter if available are reset under Main Menu Measurement Reset see also SIPROTEC 4 System Description Press the ESC key several times if necessary to return to the default display The defaul...

Page 248: ...248 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 249: ...5 Ground Fault Differential Protection in Resonant grounded Isolated Systems 265 4 6 Breaker Intertrip and Remote Tripping Direct Local Trip 266 4 7 Time Overcurrent Protection 267 4 8 Inrush Current Restraint Breaker Intertrip and Remote Tripping 274 4 9 Circuit Breaker Failure Protection Optional 275 4 10 Thermal Overload Protection 49 276 4 11 Voltage Protection Optional 278 4 12 Frequency Prot...

Page 250: ...ous 750 A half cycle 1 only in models with input for sensitive ground fault detection see ordering data in the Appendix Voltage inputs Nominal voltage 34 V 225 V adjustable for connection of phase to ground voltages 34 V 200 V adjustable for connection of phase to phase voltages Measuring Range 0 V to 200 V Burden at 100 V approx 0 005 VA Overload capacity in the voltage path thermal rms 230 V con...

Page 251: ...put approx 4 ms approx 5 ms Secured switching thresholds adjustable For rated voltages DC 24 V to 125 V V high DC 19 V V low DC 10 V For rated voltages DC 110 V to 250 V V high DC 88 V V low DC 44 V For rated voltages DC 220 V and 250 V V high DC 176 V V low DC 88 V Maximum admissible voltage DC 300 V Input interference suppression 220 V induced above 220 nF at a recovery time between two switchin...

Page 252: ...9 pin DSUB socket Test voltage PELV 500 V 50 Hz Transmission speed min 1 200 Bd max 115 000 Bd factory setting 9 600 Bd Bridgeable distance 15 m RS485 Terminal Back case bottom mounting location B 9 pin DSUB socket Test voltage PELV 500 V 50 Hz Transmission speed min 1 200 Bd max 115 000 Bd factory setting 9 600 Bd Bridgeable distance max 1 km Fiber optic cable FO FO connector type ST connector Te...

Page 253: ...using glass fiber 50 125 μm or glass fiber 62 5 125 μm Permissible optical signal attenuation max 8 dB with glass fiber 62 5 125 μm Bridgeable distance max 1 5 km DNP3 0 MODBUS RS485 Terminal Back case bottom mounting location B 9 pin DSUB socket Test voltage PELV 500 V 50 Hz Transmission speed up to 19 200 Bd Bridgeable distance max 1 km DNP3 0 MODBUS FO FO connector type ST connector transmitter...

Page 254: ...except communication inter face and CU protection data interface category III 5 kV peak value 1 2 µs 50 µs 0 5 J 3 positive and 3 negative impulses at intervals of 1 s Impulse voltage test type test all processor circuits against the internal electronics except communication interface and CU protection data interface 6 kV peak value 1 2 µs 50 µs 0 5 J 3 positive and 3 negative impulses at interval...

Page 255: ...ing inputs and relay outputs common mode 4 kV 42 Ω 0 5 µF diff mode 1 kV 42 Ω 0 5 µF Binary inputs common mode 4 kV 42 Ω 0 5 µF diff mode 1 kV 42 Ω gas filled tube CU protection interface unscreened a and b common mode 4 kV 42 Ω gas filled tube CU protection interface screened common mode 4 kV 2 Ω coupling into shield Line conducted high frequency amplitude modulated class III IEC 60255 22 6 IEC 6...

Page 256: ...soidal 5 Hz to 8 Hz 7 5 mm amplitude 8 Hz to 150 Hz 2 g acceleration Frequency sweep 1 octave min 20 cycles in 3 orthogonal axes Shock IEC 60255 21 2 Class 1 IEC 60068 2 27 Semi sinusoidal 15 g acceleration duration 11 ms each 3 shocks in both directions of the 3 axes Continuous Shock IEC 60255 21 2 Class 1 IEC 60068 2 29 Semi sinusoidal 10 g acceleration duration 16 ms each 1000 shocks in both di...

Page 257: ...voltages no special measures are normally required Do not withdraw or insert individual modules or boards while the protective device is energized In with drawn condition some components are electrostatically endangered during handling the ESD stand ards for Electrostatic Sensitive Devices must be observed They are not endangered when inserted into the case Design Case 7XP20 Dimensions see dimensi...

Page 258: ... may present a fire or chemical burn hazard if mistreated Do not recharge disassemble heat above 100 C 212 F or incin erate Dispose of used battery promptly Keep away from children Climatic Stress Tests Surrounding air temperature tsurr max 70 C 158 F normal opera tion Design Field Wires of Control Circuits shall be separated from other circuits with respect to the end use requirements Type 1 if m...

Page 259: ...les for monomode and multimode fiber For multimode fiber you must additionally take the product of the bandwidth lengths into consideration 1 When using multimode fiber a monomode patch cable is used on the sending side a multimode patch cable is used on the receiving side mode conditioning patch cable Electrical protection data interface Maximum distance 16 km 9 94 miles for AWG 19 0 65 mm2 Maxim...

Page 260: ... the properties of the cable the number of joints and splices To select the modes of the Cu protection interface connection please observe the following criteria The connection must be established in the selected mode The number of message errors per minute and or per hour should be as small as possible opera tional measured value Mode Signal noise ratio S N the higher this value the better Attenu...

Page 261: ...ms to 40 ms Trip times with infeed at both ends approx 35 ms to 40 ms Command time approx 15 ms to 90 ms Start time at 50 Hz approx 51 ms Frequency range 45 Hz to 55 Hz at 50 Hz 55 Hz to 65 Hz at 60 Hz 25 Hz to 45 Hz at 50 Hz 30 Hz to 55 Hz at 60 Hz if only the static element is active Tolerances ΙNom 1 A 20 mA ΙNom 5 A 100 mA Time Delaytime delays Tripping delay 87L Trip Delay 0 00 s to 0 10 s In...

Page 262: ...eristic dyn mode pcc 101206 1 en_US Figure 4 1 Dynamic pickup characteristic Technical Data 4 3 87 Differential Protection Phase Comparison Protection 262 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 263: ...at mode pcc 101206 1 en_US Figure 4 2 Static pickup characteristic Technical Data 4 3 87 Differential Protection Phase Comparison Protection SIPROTEC 4 7SD80 Manual 263 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 264: ...ange 45 Hz to 55 Hz at 50 Hz 55 Hz to 65 Hz at 60 Hz 25 Hz to 45 Hz at 50 Hz 30 Hz to 55 Hz at 60 Hz Increased tolerances Time Delays Tripping delay 87L Trip Delay 0 00 s to 0 10 s Increments0 01 s Expiry tolerances 1 of setting value or 10 ms The set times are pure time delays Emergency Operation Communication failure See section Time Overcurrent Protection Frequency Operating Range Operating Ran...

Page 265: ...t for direction determination 5 of setting value or 1 ΙNom Delay of the 87N L I DIFF element approx 1 of setting value or 10 ms Frequency range 45 Hz to 55 Hz at 50 Hz 55 Hz to 65 Hz at 60 Hz 25 Hz to 45 Hz at 50 Hz 30 Hz to 55 Hz at 60 Hz Increased tolerances Time Delays Tripping delay 87N L Trip Delay 0 00 s to 320 s Increments 0 01 s Expiry tolerances 1 of setting value or 10 ms The set times a...

Page 266: ... a command injected via binary inputs The command times depend on the communication speed The following data require a transmission rate of 512 kbit s for the optical fiber protection interface Operating times total approx minimum 10 ms typical 13 ms maximum 15 ms Dropout times minimum 26 ms typical 27 ms maximum 29 ms Tripping delay 85 DT TD BI 0 00 s to 30 00 s Increments 0 01 s Trip time prolon...

Page 267: ...ffective Pickup value 50N B1 PICKUP ground for ΙNom 1 A 0 05 A to 25 00 A or ineffective Increments0 01 A for ΙNom 5 A 0 25 A to 125 00 A or ineffective Pickup value 67 B1 PICKUP directional phases for ΙNom 1 A 0 10 A to 25 00 A or ineffective Increments 0 01 A for ΙNom 5 A 0 50 A to 125 00 A or ineffective Delays directional phases 67 B1 DELAY 0 00 s to 30 00 s or ineffective Increments 0 01 s 67...

Page 268: ...Delays 50 3 DELAY 0 00 s to 30 00 s or ineffective Increments 0 01 s 50N 3 DELAY 0 00 s to 30 00 s or ineffective Increments 0 01 s Pickup value 67 B2 PICKUP directional phases for ΙNom 1 A 0 10 A to 25 00 A or ineffective Increments 0 01 A for ΙNom 5 A 0 50 A to 125 00 A or ineffective Pickup value 67N B2 PICKUP directional ground for ΙNom 1 A 0 05 A to 25 00 A or ineffective Increments 0 01 A fo...

Page 269: ...directional phases for ΙNom 1 A 0 10 A to 4 00 A or ineffective Increments 0 01 A for ΙNom 5 A 0 50 A to 20 00 A or ineffective Pickup value 67N TOC PICKUP directional ground for ΙNom 1 A 0 05 A to 4 00 A or ineffective Increments 0 01 A for ΙNom 5 A 0 25 A to 20 00 A or ineffective Time multipliers directional phases 67 TOC TD IEC phases 0 05 s to 3 00 s or ineffective Increments 0 01 s 67N TOC T...

Page 270: ...C PICKUP directional phases for ΙNom 1 A 0 10 A to 4 00 A or ineffective Increments 0 01 A for ΙNom 5 A 0 50 A to 20 00 A or ineffective Pickup value 67N TOC PICKUP directional ground for ΙNom 1 A 0 05 A to 4 00 A or ineffective Increments 0 01 A for ΙNom 5 A 0 25 A to 20 00 A or ineffective Time multipliers directional phases 67 TOC TD ANSI phases 0 50 s to 15 00 s or ineffective Increments 0 01 ...

Page 271: ...60802 1 en_US Figure 4 3 Trip time characteristics of inverse time overcurrent elements acc IEC phases and ground Technical Data 4 7 Time Overcurrent Protection SIPROTEC 4 7SD80 Manual 271 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 272: ...0802 1 en_US Figure 4 4 Trip time characteristics of inverse time overcurrent element acc ANSI IEEE phases and ground Technical Data 4 7 Time Overcurrent Protection 272 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 273: ...0802 1 en_US Figure 4 5 Trip time characteristics of inverse time overcurrent element acc ANSI IEEE phases and ground Technical Data 4 7 Time Overcurrent Protection SIPROTEC 4 7SD80 Manual 273 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 274: ...ssblock deactivated or active until dropout Increments 0 01 s Restricted Earth Fault Protection Restraint ratio 2 Inrush stabilization Ι2fNom ΙfNom 0 to 45 Increments 1 Max current for restraint ΙNom 1 A 1 1 A to 25 0 A Increments 0 1 A ΙNom 5 A 5 5 A to 125 0 A Crossblock function zu und abschaltbar Max action time for crossblock CROSSB 2HM 0 00 s to 60 00 s or 0 crossblock deactivated or active ...

Page 275: ...t protection and circuit breaker pole discrepancy supervi sion Initiation Conditions For circuit breaker failure protection Internal or external 1 pole trip 1 Internal or external 3 pole trip 1 Internal or external 3 pole trip without current 1 1 Via binary inputs Times Pickup time approx 5 ms with measured quantities present approx 20 ms after switch on of measured quantities Drop off time intern...

Page 276: ...urrent Trip Characteristic Formula for primary values Trip Characteristic curve for Ι k ΙNom 8 with t Trip time in minutes τth Heating up time constant Ιn Actual load current Ιpre Preload current k Setting factor per IEC 60255 8 ΙNom Nominal current for the protected object Drop off to Pick up Ratio Θ ΘTrip Θ ΘAlarm Ι ΙAlarm Drops out with ΘAlarm approx 0 99 approx 0 97 Tolerances Referring to k Ι...

Page 277: ...inie ueberlast 1111203 he 1 en_US Figure 4 6 Trip time curves for the thermal overload protection 49 Technical Data 4 10 Thermal Overload Protection 49 SIPROTEC 4 7SD80 Manual 277 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 278: ...ances Voltages 3 of setting value or 1 V Times 1 of setting value or 10 ms Overvoltage Positive Sequence System V1 Overvoltage V1 2 0 V to 220 0 V Increments 0 1 V Delay TV1 0 00 s to 100 00 s Increments 0 01 s Overvoltage V1 2 0 V to 220 0 V Increments 0 1 V Delay TV1 0 00 s to 100 00 s Increments 0 01 s Dropout ratio 0 30 to 0 99 Increments 0 01 Compounding can be switched on off Pickup time app...

Page 279: ...0 V Increments 0 1 V Delay TVPh 0 00 s to 100 00 s Increments 0 01 s Dropout ratio 1 01 to 1 20 Increments 0 01 Current criterion can be switched on off Pickup time approx 40 ms Dropout time approx 35 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of setting value or 10 ms Undervoltages Phase to Phase Undervoltage VPhPh 1 0 V to 175 0 V Increments 0 1 V Delay TVPhPh 0 00 s to 100 00 s In...

Page 280: ...1 01 to 1 20 Increments 0 01 Current criterion can be switched on off Pickup time approx 40 ms Dropout time approx 35 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of setting value or 10 ms Technical Data 4 11 Voltage Protection Optional 280 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 281: ...te on drop off times Drop off was enforced by current 0 A and voltage 0 V Enforcing the drop off by means of a frequency change below the drop off threshold extends the drop off times Dropout Difference Δf Ι pickup value dropout value Ι 0 02 Hz to 1 Hz Operating Ranges In voltage range approx 0 65 VN to 230 V phase to phase In frequency range 25 Hz to 70 Hz Tolerances Frequencies f f in specific r...

Page 282: ...0 s Increments 0 01 s Dead times after evolving fault recognition 0 01 s to 1800 00 s Increments 0 01 s Blocking time after reclosure 0 50 s to 300 00 s Increments 0 01 s Blocking time after dynamic blocking 0 5 s Blocking time after manual closing 0 50 s to 300 00 s 0 Increments 0 01 s Start signal monitoring time 0 01 s to 300 00 s Increments 0 01 s Circuit breaker monitoring time 0 01 s to 300 ...

Page 283: ...e of 512 kbit s for the optical fiber protection interface The operating times refer to the entire signal path from entry via binary inputs until output of commands via output relays Operating times total approx typical 20 ms 5 ms Dropout times total approx typical 15 ms 4 14 Technical Data 4 14 Transmission of Binary Information and Commands SIPROTEC 4 7SD80 Manual 283 E50417 G1100 C474 A2 Editio...

Page 284: ...ent Voltage Balance Vmin Vmax SYM FAK V as long as Vmax SYM VGRENZ BAL FACTORV 0 58 to 0 95 Increments 0 01 BAL VLIMIT 10 V to 100 V Increments 1 V T BAL VLIMIT 5 s to 100 s Increments 1 s Voltage phase sequence VA leads VB leads VC as long as VA VB VC 40 V 3 non symmetrical voltages Fuse Failure Monitor 3 V0 FFM V ODER 3 V2 FFM V AND at the same time 3 Ι0 FFM Ι AND 3 Ι2 FFM Ι FFM V 10 V to 100 V ...

Page 285: ...s 0 01 s T VT mcb 0 ms to 30 ms Increments 1 ms Trip Circuit Supervision Number of supervised trip circuits 1 to 3 Operation of each trip circuit With 1 binary input or with 2 binary inputs Pickup and dropout time approx 1 to 2 s Settable time delay for operation with 1 binary input 1 s to 30 s Increments 1 s Technical Data 4 15 Monitoring Functions SIPROTEC 4 7SD80 Manual 285 E50417 G1100 C474 A2...

Page 286: ... Q for ΙN 1 A 2 0 W to 10000 W Increments 0 1 W for ΙN 5 A 10 W to 50000 W Power facto cosφ 0 99 to 0 99 Increments 0 01 Frequency for fNom 50 Hz for fNom 60 Hz 40 0 Hz to 60 0 Hz 50 0 Hz to 70 0 Hz Increments 0 01 Hz Increments 0 01 Hz Frequency change df dt 0 10 Hz s to 20 00 Hz s Increments 0 01 Hz s Dropout ratio element 1 01 to 3 00 Increments 0 01 Dropout ratio element 0 70 to 0 99 Increment...

Page 287: ...0 ms Dropout times Current voltage phase quantities 20 ms Current voltage symmetrical components 30 ms Power typical maximum 50 ms 350 ms Power factor 300 ms Frequency 100 ms Frequency change 200 ms Binary input 10 ms Tolerances Pickup thresholds Current for ΙNom 1 A 3 of setting value or 15 mA for ΙNom 5 A 3 of setting value or 75 mA Current symmetrical components for ΙNom 1 A 4 of setting value ...

Page 288: ...b 55 C 131 F 0 5 10 K Frequency in the range of 25 Hz to 70 Hz Frequency in the range of 0 95 f fNom 1 05 fNom 50 Hz or 60 Hz 1 Frequency outside range 0 95 f fNom 1 05 Increased tolerances Harmonics up to 10 3rd harmonic up to 10 5th harmonic 1 1 Technical Data 4 16 Flexible Protection Functions 288 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 289: ... 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 indi cation decoder X X X X DI_SET_STATUS Double point indication with status encoder X X X X DI_TO_BOOL Double Point to Boolean conver sion X X X DINT_TO_REAL DoubleInt after real adapter X X X X DIST_DECODE Double point indication with status decoder X X X X DIV Division X X X X DM_DE...

Page 290: ...vel 16 Only Error Message evolving fault in processing procedure Maximum number of all CFC inputs considering all charts 400 When the limit is exceeded an error message is output by the device Consequently the device starts monitoring The red ERROR LED lights up Maximum number of inputs of one chart for each task level number of unequal information items of the left border per task level 400 Only ...

Page 291: ...of TICKS in the Task Levels Task Level Limit in TICKS 1 MW_BEARB Measured Value Processing 10 000 PLC1_BEARB slow PLC Processing 1 900 PLC_BEARB fast PLC Processing 200 SFS_BEARB switchgear interlocking 10 000 1 When the sum of TICKS of all blocks exceeds the limits before mentioned an error message is output by CFC Processing Times in TICKS required by the Individual Elements Individual Element N...

Page 292: ...ement Number of Ticks Adapter REAL_TO_UINT 10 Alarm ALARM 21 Vergleich COMPARE 12 Decoder DIST_DECODE 8 Technical Data 4 17 User defined Functions CFC 292 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 293: ...für Leistungen S P Q apparent active and reactive power in MVA MW Mvar primary and SN operational nominal power 3 VNom ΙNom Tolerance für S 1 5 of SN at Ι ΙN and V VN in range 50 to 120 Tolerance für P 2 of PN at Ι ΙN and V VN im in range 50 to 120 and ABS cos φ in range 0 7 Tolerance für Q 2 of QN at Ι ΙN and V VN in range 50 to 120 and ABS cos φ in range 0 7 Betriebsmesswert Leistungsfaktor cos ...

Page 294: ...nzahl der vom Gerät veranlassten automatischen Wiedereinschaltungen getrennt für 1 AWE Zyklus and alle weiteren Summe der Ausschaltströme getrennt je Schalterpol Maximal abgeschalteter Strom getrennt je Schalterpol Echtzeitzuordnung und Pufferbatterie Auflösung für Betriebsmeldungen 1 ms Auflösung für Störfallmeldungen 1 ms Pufferbatterie Typ 3 V 1 Ah Typ CR 1 2 AA Selbstentladezeit ca 10 Jahre In...

Page 295: ...ne Synchronisation über Zeitzeichen DCF 77 5 Impuls über Binäreingang Externe Synchronisation mit Impuls über Binäreingang Technical Data 4 18 Additional Functions SIPROTEC 4 7SD80 Manual 295 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 296: ...h mounting housing size 1 6 Note A set of mounting brackets consisting of upper and lower mounting rail order no C73165 A63 D200 1 is required for cabinet flush mounting Provide for sufficient space at the device bottom side or below the device to accommodate the cables of the communication modules 4 19 4 19 1 Technical Data 4 19 Dimensions 296 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition ...

Page 297: ... Figure 4 8 Dimensional drawing of a 7SD80 for panel surface mounting housing size 1 6 Bottom View ansicht unten 7sd80 100801 1 en_US Figure 4 9 Bottom view of a 7SD80 housing size 1 6 4 19 2 4 19 3 Technical Data 4 19 Dimensions SIPROTEC 4 7SD80 Manual 297 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 298: ...298 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 299: ...Ordering Information and Accessories A 1 Ordering Information 7SD80 V4 7 300 A 2 Accessories 303 A SIPROTEC 4 7SD80 Manual 299 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 300: ...ings Pos 7 Ιph 1 A 5 A ΙN 1 A 5 A 1 Ιph 1 A ΙNs sensitive 0 001 A to 1 6 A 0 005 A to 8 A 2 Auxiliary voltage power supply Pos 8 DC 24 V 48 V 1 DC 60 V 110 V 125 V 220 V 250 V AC 115 V AC 230 V 5 Construction Pos 9 Surface mounted housing screw type terminals B Flush mounting case screw type terminals E Region specific language default settings and function versions Pos 10 Region DE IEC language G...

Page 301: ...erage values min max values 3 Protection functions Pos 15 ANSI Nr Description Basic design included in all versions A 87L 87N L Line differential protection phase comparison and 3I0 differential protection 1 Inrush current detection 50 TD 51 Overcurrent protection phase 50 1 50 2 50 3 51 50N TD 51N Overcurrent protection ground 50N 1 50N 2 50N 3 51N 49 Thermal overload protection 49 74TC Trip circ...

Page 302: ...osition 7 1 required Ιph 1A 5A ΙN 1A 5A 2 function available if MLFB Position 6 5 6 or 7 voltage transformer 3 MLFB position 6 5 6 or 7 required voltage transformer 4 MLFB position 7 2 required Ιph 1A 5A ΙNs sensitive 0 001 A to 1 6 A 0 005 A to 8 A Additional functions Pos 16 without 0 Bin Transmission of 16 binary signals via protection interface 1 79 with automatic reclosing AR 2 Bin 79 Transmi...

Page 303: ...ibus DP double ring C53207 A351 D613 1 Modbus RS 485 C53207 A351 D621 1 Modbus 820 nm C53207 A351 D623 1 DNP 3 0 RS 485 C53207 A351 D631 1 DNP 3 0 820 nm C53207 A351 D633 1 Ethernet electrical EN 100 C53207 A351 D675 2 Ethernet optical EN 100 4 ST connectors C53207 A351 D678 1 C53207 A351 D688 1 RS485 FO converter RS485 FO converter Order No 820 nm FC Connector 7XV5650 0AA00 820 nm with ST Connect...

Page 304: ...rminal block 4xI C53207 A406 D185 1 Current terminal block 3xI 1xINs sensitive C53207 A406 D186 1 Current terminal short circuit links 3 pieces C53207 A406 D193 1 Voltage terminal short circuit links 6 pieces C53207 A406 D194 1 Ordering Information and Accessories A 2 Accessories 304 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 305: ...Terminal Assignments B 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounting 306 B SIPROTEC 4 7SD80 Manual 305 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 306: ...ace Mounting 7SD801 7SD801 kl uebers 7sd80 1 100801 1 en_US Figure B 1 Overview diagram 7SD801 B 1 Terminal Assignments B 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounting 306 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 307: ...00801 1 en_US Figure B 2 Overview diagram 7SD802 Terminal Assignments B 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounting SIPROTEC 4 7SD80 Manual 307 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 308: ...SD803 The optical fiber interface at port A can only be delivered if the 12th digit equals 7 Terminal Assignments B 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounting 308 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 309: ...100801 1 en_US Figure B 4 Overview diagram 7SD805 Terminal Assignments B 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounting SIPROTEC 4 7SD80 Manual 309 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 310: ...100801 1 en_US Figure B 5 Overview diagram 7SD806 Terminal Assignments B 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounting 310 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 311: ...SD807 The optical fiber interface at port A can only be delivered if the 12th digit equals 7 Terminal Assignments B 1 7SD80 Housing for Panel Flush Mounting Cabinet Flush Mounting and Panel Surface Mounting SIPROTEC 4 7SD80 Manual 311 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 312: ...312 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 313: ...Connection Examples C 1 Connection Examples for Current and Voltage Transformers 314 C SIPROTEC 4 7SD80 Manual 313 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 314: ...le for all power systems neutral point in line direction anschl 3 stromwdl sternpkt 110301 1 en_US Figure C 2 Current transformer connections to three current transformers and neutral point current ground current Holmgreen connection standard connection suitable for all power systems neutral point in busbar direction C 1 Connection Examples C 1 Connection Examples for Current and Voltage Transform...

Page 315: ...t Grounding of the cable shield must be effected at the cable side The switchover of the current polarity address 201 also reverses the polarity of the current input IN anschl u1e u2e u3e abgang 20070129 1 en_US Figure C 4 Example for the connection type VAN VBN VCN with voltage connection on the feeder side Connection Examples C 1 Connection Examples for Current and Voltage Transformers SIPROTEC ...

Page 316: ... anschl nur u0 110301 1 en_US Figure C 5 V0 connection Connection Examples C 1 Connection Examples for Current and Voltage Transformers 316 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 317: ...former Requirements D 1 Current Transformer Ratio 318 D 2 Overcurrent Factors 319 D 3 Class Conversion 320 D 4 Core Balance Current Transformer 321 D SIPROTEC 4 7SD80 Manual 317 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 318: ...ed greater or smaller It may be that the sensitivity of the differential protection indicated in the technical data are no longer observed Ιpn local Primary rated transformer current of the local device Ιpn remote Primary rated transformer current of the remote device D 1 Current Transformer Requirements D 1 Current Transformer Ratio 318 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018...

Page 319: ...t winding resistance of the current transformer at 75 C Rb Rated burden resistance of the current transformer R b Connected burden resistance at the current transformer usually resistance of the current transformer feed cable burden resistance of the protection device Example Current transformer 5P40 5 VA Ιsn 1 A Ιpn 500 A Rb 5 Ω 5 VA Ιsn 2 RCT 3 Ω R b 0 6 Ω ΙSSC max ext fault 20 kA 88 9 48 and 88...

Page 320: ...nternal burden RB Rated burden Ιsn Secondary rated transformer current KSSC Rated overcurrent factor Us t max sec terminal voltage at 20 Ιpn i i NOTE Detailed information on the transformer design is available on the Internet www siprotec de D 3 Current Transformer Requirements D 3 Class Conversion 320 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 321: ... system and the magnitude of the maximum ground fault current a different ratio may have to be selected 60 1 Overcurrent limiting factor FS 10 Minimum power 1 2 VA Maximum connected burden for secondary current thresholds 20 mA for secondary current thresholds 20 mA 1 2 VA 1 2 Ω 0 4 VA 0 4 Ω Class Accuracy Table D 2 Minimum required class accuracy depending on the neutral point grounding and the o...

Page 322: ...322 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 323: ...nctions E 1 LEDs 324 E 2 Binary Input 325 E 3 Binary Output 326 E 4 Function Keys 327 E 5 Default Display 328 E 6 Pre defined CFC Charts 331 E 7 Protocol dependent Functions 332 E SIPROTEC 4 7SD80 Manual 323 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 324: ...elay PICKUP ØC 505 Relay PICKUP Phase C LED5 Relay PICKUP G 506 Relay PICKUP GROUND LED6 87 N L Gen TRIP 32125 87 N L General TRIP 85 DT Gen TRIP 3517 85 DT General TRIP LED7 Emer mode 2054 Emergency mode LED8 Alarm Sum Event 160 Alarm Summary Event Failure Σi 289 Alarm Current summation supervision E 1 Default Settings and Protocol dependent Functions E 1 LEDs 324 SIPROTEC 4 7SD80 Manual E50417 G...

Page 325: ... BI3 BLOCK 50 3 7130 BLOCK 50 3 BLOCK 50N 3 7132 BLOCK 50N 3 BI4 Rem Signal 1 3549 Remote Signal 1 input BI5 52a 3p Closed 379 52a Bkr aux contact 3pole closed 52a Bkr1 3p Cl 410 52a Bkr1 aux 3pClosed for AR CB Test BI6 52b 3p Open 380 52b Bkr aux contact 3pole open 52b Bkr1 3p Op 411 52b Bkr1 aux 3p Open for AR CB Test BI7 Manual Close 356 Manual close signal E 2 Default Settings and Protocol dep...

Page 326: ...arm Summary Event BO3 Relay PICKUP 501 Relay PICKUP BO4 Relay TRIP 511 Relay GENERAL TRIP command BO5 Relay TRIP 511 Relay GENERAL TRIP command BO6 Rem Sig 1 Rx 3573 Remote signal 1 received BO7 PDI FO faulty 3230 PDI FO failure PDI Cu faulty 3232 PDI Cu failure BO8 E 3 Default Settings and Protocol dependent Functions E 3 Binary Output 326 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2...

Page 327: ...ion F1 Display of operational indications F2 Display of the primary operational measured values F3 Overview of the last 8 fault indications F4 no default value E 4 Default Settings and Protocol dependent Functions E 4 Function Keys SIPROTEC 4 7SD80 Manual 327 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 328: ...e DD auswählen for the 6 line display of the 7SD80 grundbild6zei mit u ohne erw mw 20070116 1 en_US Figure E 1 Default display of the 7SD80 for models with V without extended measured values For V0 I0 ϕ measurement the measured ground current INB is shown under N and the ground current IN or INs under Ns E 5 Default Settings and Protocol dependent Functions E 5 Default Display 328 SIPROTEC 4 7SD80...

Page 329: ...70116 1 en_US Figure E 2 Default display of the 7SD80 for models with V with extended measured values Default Settings and Protocol dependent Functions E 5 Default Display SIPROTEC 4 7SD80 Manual 329 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 330: ...interface grundbild lwl 110413 1 en_US Figure E 6 Default display of the device with fiber optic protection interface Spontaneous Fault Display After a fault has occurred the most important fault data are automatically displayed after general device pickup in the order shown in the picture below anzeige spontanmeldungen im display des geraetes 260602 kn 1 en_US Figure E 7 Representation of spontan...

Page 331: ...m the binary input DataStop into the internal single point indication UnlockDT cfc topo geraet abmeld 040216 wlk 1 en_US Figure E 8 Connection of input and output E 6 Default Settings and Protocol dependent Functions E 6 Pre defined CFC Charts SIPROTEC 4 7SD80 Manual 331 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 332: ...sioning aids Data transmission stop Yes Yes Yes No No No No Creating test messages Yes Yes Yes No No No No Physical mode Asynchro nous Asynchro nous Synchronous Asynchro nous Asynchronous Transmission mode cyclic event cyclic event cyclic event cyclic cyclic cyclic event cyclic event DNP cyclic Modbus Baud rate 1 200 to 115 000 2 400 to 57 600 up to 100 MBaud up to 100 MBaud up to 1 5 MBaud Fiber ...

Page 333: ...ons Settings Information F 1 Functional Scope 334 F 2 Settings 336 F 3 Information List 352 F 4 Group Indications 392 F 5 Measured Values 393 F SIPROTEC 4 7SD80 Manual 333 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 334: ...PU w o ActionT Trip w ActionT Trip w oActionT Trip w ActionT Auto Reclose control mode 136 81 O U Disabled Enabled Disabled 81 Over Underfrequency Protec tion 137 27 59 Disabled Enabled Disabled 27 59 Under Overvoltage Protec tion 139 50BF Disabled Enabled enabled w 3I0 Disabled 50BF Breaker Failure Protection 140 74 Trip Ct Supv Disabled 1 trip circuit Disabled 74TC Trip Circuit Supervision 142 4...

Page 335: ...lexible Function 08 Flexible Function 09 Flexible Function 10 Flexible Function 11 Flexible Function 12 Flexible Function 13 Flexible Function 14 Flexible Function 15 Flexible Function 16 Flexible Function 17 Flexible Function 18 Flexible Function 19 Flexible Function 20 Please select Flexible Functions1 20 Functions Settings Information F 1 Functional Scope SIPROTEC 4 7SD80 Manual 335 E50417 G110...

Page 336: ...forward P reverse Q forward Q reverse Power factor Frequency df dt rising df dt falling Binary Input Please select Selection of Measured Quantity 0 MEAS METHOD Flx Fundamental True RMS Positive seq Negative seq Zero sequence Ratio I2 I1 Fundamental Selection of Measure ment Method 0 PICKUP WITH Flx Exceeding Dropping below Exceeding Pickup with 0 CURRENT Flx Ia Ib Ic In In sensitive Ia Current 0 V...

Page 337: ... 0 95 Dropout Ratio 0A DROPOUT RATIO Flx 1 01 3 00 1 05 Dropout Ratio 0A DO differential Flx 0 02 1 00 Hz 0 02 Hz Dropout differential 201 CT Starpoint P System Data 1 towards Line towards Busbar towards Line CT Starpoint 203 Vnom PRIMARY P System Data 1 0 4 500 0 kV 10 0 kV Rated Primary Voltage 204 Vnom SECONDARY P System Data 1 80 125 V 100 V Rated Secondary Voltage Ph Ph 205 CT PRIMARY P Syste...

Page 338: ...6V Threshold for Binary Input 7 301 ACTIVE GROUP Change Group Group A Group B Group C Group D Group A Active Setting Group is 302 CHANGE Change Group Group A Group B Group C Group D Binary Input Protocol Group A Change to Another Setting Group 402A WAVEFORM TRIGGER Osc Fault Rec Save w Pickup Save w TRIP Start w TRIP Save w Pickup Waveform Capture 403A WAVEFORM DATA Osc Fault Rec Fault event Pow S...

Page 339: ...mal time for line open before SOTF 1134 Line Closure P System Data 2 only with ManCl I OR V or ManCl 52a OR I or M C I or Man Close only with ManCl Recognition of Line Closures with 1135 Reset Trip CMD P System Data 2 CurrentOpenPole Current AND 52a Pickup Reset CurrentOpenPole RESET of Trip Command 1150A SI Time Man Cl P System Data 2 0 01 30 00 sec 0 30 sec Seal in Time after MANUAL closures 115...

Page 340: ...element 1230 87N L TD F det 87 Diff Prot 0 00 320 00 sec 1 00 sec Time delay for fault detection 1231 87N L TripDelay 87 Diff Prot 0 00 320 00 sec 0 00 sec Trip Delay 1233 CT Err I1 87 Diff Prot 0 003 1 600 A 0 050 A Current I1 for CT Angle Error 1234 CT Err F1 87 Diff Prot 0 0 5 0 0 0 CT Angle Error at I1 1235 CT Err I2 87 Diff Prot 0 003 1 600 A 1 000 A Current I2 for CT Angle Error 1236 CT Err ...

Page 341: ...F OFF Operating Mode 67 N B1 2611 67 N B1 Dir Back Up O C Non Directional Forward Reverse Non Directional 67 N B1 Direction 2612 67 N B1 on FFM Back Up O C Non Directional BLOCKED BLOCKED 67 N B1 Direct stage on Fuse Failure 2613 50 B1 PICKUP Back Up O C 1A 0 10 25 00 A 2 00 A 50 B1 Pickup 5A 0 50 125 00 A 10 00 A 2613 67 B1 PICKUP Back Up O C 1A 0 10 25 00 A 2 00 A 67 B1 Pickup threshold 5A 0 50 ...

Page 342: ...NO 67 B2 Inrush blocking 2626 50N B2 PICKUP Back Up O C 1A 0 05 25 00 A 0 20 A 50N B2 Pickup 5A 0 25 125 00 A 1 00 A 2626 67N B2 PICKUP Back Up O C 1A 0 05 25 00 A 0 20 A 67N B2 Pickup threshold 5A 0 25 125 00 A 1 00 A 2627 50N B2 DELAY Back Up O C 0 00 30 00 sec 2 00 sec 50N B2 Delay 2627 67N B2 DELAY Back Up O C 0 00 30 00 sec 2 00 sec 67N B2 set time delay 2628 50 N B2 Pil BI Back Up O C NO YES...

Page 343: ... A A 67N TOC Pickup threshold 5A 0 25 20 00 A A 2639 51N B TD IEC Back Up O C 0 05 3 00 sec 0 50 sec 51N B Time Dial for IEC characteristic 2639 67N TOC TD IEC Back Up O C 0 05 3 00 sec 0 50 sec 67N TOC Time Dial for IEC characteristic 2640 51N B TD ANSI Back Up O C 0 50 15 00 5 00 51N B Time Dial for ANSI characteristic 2640 67N TOC TD ANSI Back Up O C 0 50 15 00 5 00 67N TOC Time Dial for ANSI c...

Page 344: ...lot Prot BI 2801 DMD Interval Demand meter 15 Min 1 Sub 15 Min 3 Subs 15 Min 15 Subs 30 Min 1 Sub 60 Min 1 Sub 60 Min 1 Sub Demand Calculation Inter vals 2802 DMD Sync Time Demand meter On The Hour 15 After Hour 30 After Hour 45 After Hour On The Hour Demand Synchronization Time 2811 MinMax cycRESET Min Max meter NO YES YES Automatic Cyclic Reset Function 2812 MiMa RESET TIME Min Max meter 0 1439 ...

Page 345: ...URR SUP Voltage Failure Supervi sion 2916A T V Supervision Meas urem Superv 0 00 30 00 sec 3 00 sec Delay Voltage Failure Supervision 2931 BROKEN WIRE Meas urem Superv ON OFF Alarm only OFF Fast broken current wire supervision 2933 FAST Σ i SUPERV Meas urem Superv ON OFF ON State of fast current summation supervis 2935A ΔI min Meas urem Superv 1A 0 05 1 00 A 0 10 A Min current diff for wire break ...

Page 346: ...79 Auto Recl 0 01 1800 00 sec 1 20 sec Dead time after evolving fault 3459 1 AR 52 CLOSE 79 Auto Recl YES NO NO 52 ready interrogation before reclosing 3461 2 AR START 79 Auto Recl YES NO NO AR start allowed in this cycle 3462 2 AR ActionTime 79 Auto Recl 0 01 300 00 sec 0 20 sec Action time 3464 2 AR DeadT 1Flt 79 Auto Recl 0 01 1800 00 sec 1 20 sec Dead time after 1phase faults 3465 2 AR DeadT 2...

Page 347: ...1 59 Vph g Mode 27 59 O U Volt OFF Alarm Only ON V Alarm V Trip OFF Operating mode Vph g overvoltage prot 3702 59 1 Vph PICKUP 27 59 O U Volt 1 0 170 0 V 85 0 V 59 1 Pickup Overvoltage phase ground 3703 59 1 Vph DELAY 27 59 O U Volt 0 00 100 00 sec 2 00 sec 59 1 Time Delay 3704 59 2 Vph PICKUP 27 59 O U Volt 1 0 170 0 V 100 0 V 59 2 Pickup Overvoltage phase ground 3705 59 2 Vph DELAY 27 59 O U Vol...

Page 348: ...0 sec 59 2 Time Delay 3739A 59 V1 RESET 27 59 O U Volt 0 30 0 99 0 98 Reset ratio 3741 59 V2 Mode 27 59 O U Volt OFF Alarm Only ON V Alarm V Trip OFF Operating mode V2 over voltage prot 3742 59 1 V2 PICKUP 27 59 O U Volt 2 0 220 0 V 30 0 V 59 1 Pickup Overvoltage neg seq 3743 59 1 V2 DELAY 27 59 O U Volt 0 00 100 00 sec 2 00 sec 59 1 Time Delay 3744 59 2 V2 PICKUP 27 59 O U Volt 2 0 220 0 V 50 0 V...

Page 349: ...ltage pos seq 3773 27 1 V1 DELAY 27 59 O U Volt 0 00 100 00 sec 2 00 sec 27 1 Time Delay 3774 27 2 V1 PICKUP 27 59 O U Volt 1 0 100 0 V 0 10 0 V 27 2 Pickup Undervoltage pos seq 3775 27 2 V1 DELAY 27 59 O U Volt 0 00 100 00 sec 1 00 sec 27 2 Time Delay 3778 CURR SUP 27 V1 27 59 O U Volt ON OFF ON Current supervision V1 3779A 27 V1 RESET 27 59 O U Volt 1 01 1 20 1 05 Reset ratio 3901 FCT 50BF Break...

Page 350: ...rload 1A 0 10 4 00 A 1 00 A Current Overload Alarm Setpoint 5A 0 50 20 00 A 5 00 A 4206 CALC METHOD 49 Th Overload Θ max Average Θ Θ from Imax Θ max Method of Acquiring Temperature 4501 PDI FO Prot Interface ON OFF ON Protection Data Interface fibre optic 4502 PDI FO TER Prot Interface 0 5 20 0 1 0 PDI FO max telegram error rate 4503 PDI FO level Prot Interface 30 10 dBm 28 dBm PDI FO min receive ...

Page 351: ...tting Comments 4702 ID OF SLAVE Diff Topo 1 65534 2 Identification number of Slave 4710 LOCAL RELAY Diff Topo Master Slave Master Local relay is Functions Settings Information F 2 Settings SIPROTEC 4 7SD80 Manual 351 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 352: ...ely set not allocatable lower case notation m preset allocatable not preset allocatable blank neither preset nor allocatable No Description Function Typ e of Info rma tion 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 ...

Page 353: ... Group A is active P GrpA act Change Group IntS P O N OF F LED BO 19 2 23 1 Yes Setting Group B is active P GrpB act Change Group IntS P O N OF F LED BO 19 2 24 1 Yes Setting Group C is active P GrpC act Change Group IntS P O N OF F LED BO 19 2 25 1 Yes Setting Group D is active P GrpD act Change Group IntS P O N OF F LED BO 19 2 26 1 Yes Fault Recording Start FltRecSta Osc Fault Rec IntS P On Of ...

Page 354: ...24 0 16 1 1 Yes Ground Switch GndSwit Control Device CF_ D2 On Of f BO 24 0 16 4 20 Ground Switch GndSwit Control Device DP On Of f BI CB 24 0 16 4 1 Yes Interlocking 52 Open 52 Open Control Device IntS P Interlocking 52 Close 52 Close Control Device IntS P Interlocking Disconnect switch Open Disc Open Control Device IntS P Interlocking Disconnect switch Close Disc Close Control Device IntS P Inte...

Page 355: ...ata SP On Of f LED BI BO CB 10 1 2 1 Yes Error Motor Voltage Err Mot V Process Data SP On Of f LED BI BO CB 24 0 18 1 1 Yes Error Control Voltage ErrCntrlV Process Data SP On Of f LED BI BO CB 24 0 18 2 1 Yes SF6 Loss SF6 Loss Process Data SP On Of f LED BI BO CB 24 0 18 3 1 Yes Error Meter Err Meter Process Data SP On Of f LED BI BO CB 24 0 18 4 1 Yes Transformer Tempera ture Tx Temp Process Data...

Page 356: ...009 01 00 Failure EN100 Modul Failure Modul EN100 Modul 1 IntS P On Of f LED BO 009 01 01 Failure EN100 Link Channel 1 Ch1 Fail Ch1 EN100 Modul 1 IntS P On Of f LED BO 009 01 02 Failure EN100 Link Channel 2 Ch2 Fail Ch2 EN100 Modul 1 IntS P On Of f LED BO 11 User defined annuncia tion 1 Annunc 1 Device General SP LED BI BO 19 2 27 1 Yes 12 User defined annuncia tion 2 Annunc 2 Device General SP LE...

Page 357: ...No 68 Clock Synchronization Error Clock SyncError Device General OUT O N OF F LED BO 69 Daylight Saving Time DayLightSavTime Device General OUT O N OF F LED BO 70 Setting calculation is running Settings Calc Device General OUT O N OF F LED BO 19 2 22 1 Yes 71 Settings Check Settings Check Device General OUT LED BO 72 Level 2 change Level 2 change Device General OUT O N OF F LED BO 73 Local setting...

Page 358: ...urrent Balance Fail I balance Meas urem Super v OUT O N OF F LED BO 13 5 18 3 1 Yes 164 Failure General Voltage Supervision Fail V Superv Meas urem Super v OUT LED BO 19 2 33 1 Yes 167 Failure Voltage Balance Fail V balance Meas urem Super v OUT O N OF F LED BO 13 5 18 6 1 Yes 168 Failure Voltage absent Fail V absent Meas urem Super v OUT O N OF F LED BO 13 5 18 7 1 Yes 169 VT Fuse Failure alarm 1...

Page 359: ...r Board 3 Error Board 3 Device General OUT O N OF F LED BO 13 5 17 3 1 Yes 186 Error Board 4 Error Board 4 Device General OUT O N OF F LED BO 13 5 17 4 1 Yes 187 Error Board 5 Error Board 5 Device General OUT O N OF F LED BO 13 5 17 5 1 Yes 190 Error Board 0 Error Board 0 Device General OUT O N OF F LED BO 13 5 21 0 1 Yes 191 Error Offset Error Offset Device General OUT O N OF F LED BO 193 Alarm A...

Page 360: ... On Of f On Off LED BI FK TO NL IN E BO 235 21 11 Function 00 instanta neous TRIP 00 instant Flx SP On Of f On Off LED BI FK TO NL IN E BO 235 21 12 Function 00 Direct TRIP 00 Dir TRIP Flx SP On Of f On Off LED BI FK TO NL IN E BO 235 21 13 Function 00 BLOCK TRIP Time Delay 00 BLK TDly Flx SP On Of f On Off LED BI FK TO NL IN E BO 235 21 14 Function 00 BLOCK TRIP 00 BLK TRIP Flx SP On Of f On Off ...

Page 361: ...00 picked up Flx OUT On Of f On Off LED BO 235 21 22 Function 00 Pickup Phase A 00 pickup A Flx OUT On Of f On Off LED BO 235 21 23 Function 00 Pickup Phase B 00 pickup B Flx OUT On Of f On Off LED BO 235 21 24 Function 00 Pickup Phase C 00 pickup C Flx OUT On Of f On Off LED BO 235 21 25 Function 00 TRIP Delay Time Out 00 Time Out Flx OUT On Of f On Off LED BO 235 21 26 Function 00 TRIP 00 TRIP F...

Page 362: ...9 Alarm Current summa tion supervision Failure Σi Meas urem Super v OUT O N OF F LED BO 13 5 25 0 1 Yes 290 Alarm Broken current wire detected L1 Broken Iwire L1 Meas urem Super v OUT O N OF F LED BO 13 5 13 7 1 Yes 291 Alarm Broken current wire detected L2 Broken Iwire L2 Meas urem Super v OUT O N OF F LED BO 13 5 13 8 1 Yes 292 Alarm Broken current wire detected L3 Broken Iwire L3 Meas urem Supe...

Page 363: ...21 Warn Limit of Memory Parameter exceeded Warn Mem Para Device General OUT On Of f LED BO 322 Warn Limit of Memory Operation exceeded Warn Mem Oper Device General OUT On Of f LED BO 323 Warn Limit of Memory New exceeded Warn Mem New Device General OUT On Of f LED BO 356 Manual close signal Manual Close P System Data 2 SP LED BI BO 15 0 6 1 Yes 357 Block manual close cmd from external Blk Man Clos...

Page 364: ...Min Max meter SP O N LED BI BO 397 V MIN MAX Buffer Reset V MiMaReset Min Max meter SP O N LED BI BO 398 Vphph MIN MAX Buffer Reset VphphMiMaRes Min Max meter SP O N LED BI BO 399 V1 MIN MAX Buffer Reset V1 MiMa Reset Min Max meter SP O N LED BI BO 400 P MIN MAX Buffer Reset P MiMa Reset Min Max meter SP O N LED BI BO 401 S MIN MAX Buffer Reset S MiMa Reset Min Max meter SP O N LED BI BO 402 Q MIN...

Page 365: ...Phase B Relay PICKUP ØB P System Data 2 OUT m LED BO 19 2 65 2 Yes 505 Relay PICKUP Phase C Relay PICKUP ØC P System Data 2 OUT m LED BO 19 2 66 2 Yes 506 Relay PICKUP GROUND Relay PICKUP G P System Data 2 OUT m LED BO 19 2 67 2 Yes 510 Relay GENERAL CLOSE command Relay CLOSE P System Data 2 OUT LED BO 511 Relay GENERAL TRIP command Relay TRIP P System Data 2 OUT OFF M LED BO 19 2 68 2 No 530 LOCK...

Page 366: ... VI 1027 Accumulation of inter rupted current Ph A Σ Ia Statistics VI 1028 Accumulation of inter rupted current Ph B Σ Ib Statistics VI 1029 Accumulation of inter rupted current Ph C Σ Ic Statistics VI 1030 max fault current Phase A Ia max Statistics VI 1031 max fault current Phase B Ib max Statistics VI 1032 max fault current Phase C Ic max Statistics VI 1401 50BF Switch on breaker fail prot 50BF...

Page 367: ...s switched OFF 50BF OFF 50BF BkrFai lure OUT O N OF F LED BO 16 6 15 1 1 Yes 1452 50BF is BLOCKED 50BF BLOCK 50BF BkrFai lure OUT O N OF F ON OFF LED BO 16 6 15 2 1 Yes 1453 50BF is ACTIVE 50BF ACTIVE 50BF BkrFai lure OUT LED BO 16 6 15 3 1 Yes 1461 50BF Breaker failure protection started 50BF Start 50BF BkrFai lure OUT ON OFF LED BO 16 6 16 1 2 Yes 1476 50BF Local trip ABC 50BF LocTripABC 50BF Bk...

Page 368: ...rload Alarm Near Thermal Trip 49 O L Θ Alarm 49 Th Over load OUT O N OF F LED BO 16 7 16 1 Yes 1517 49 Winding Overload 49 Winding O L 49 Th Over load OUT O N OF F LED BO 16 7 17 1 Yes 1521 49 Thermal Overload TRIP 49 Th O L TRIP 49 Th Over load OUT ON LED BO 16 7 21 2 Yes 2054 Emergency mode Emer mode Device General OUT O N OF F ON OFF LED BO 19 2 37 1 Yes 2701 79 ON 79 ON 79 Auto Recl SP LED BI ...

Page 369: ...cycle BLK 1 AR cycle 79 Auto Recl SP O N OF F LED BI BO 40 37 1 Yes 2743 79 Block 2nd AR cycle BLK 2 AR cycle 79 Auto Recl SP O N OF F LED BI BO 40 38 1 Yes 2746 79 External Trip for AR start Trip for AR 79 Auto Recl SP ON LED BI BO 40 41 2 Yes 2752 79 External pickup 3phase for AR start Pickup 3ph AR 79 Auto Recl SP ON LED BI BO 40 47 2 Yes 2781 79 Auto recloser is switched OFF 79 OFF 79 Auto Rec...

Page 370: ...ving fault 79 Td evol Flt 79 Auto Recl OUT ON OFF LED BO 40 19 7 2 Yes 2840 79 dead time after 3pole trip running 79 Tdead 3pTrip 79 Auto Recl OUT ON LED BO 40 14 9 2 Yes 2843 79 dead time after 3phase fault running 79 Tdead 3pFlt 79 Auto Recl OUT ON LED BO 40 15 4 2 Yes 2844 79 1st cycle running 79 1stCyc run 79 Auto Recl OUT ON LED BO 40 15 5 2 Yes 2845 79 2nd cycle running 79 2ndCyc run 79 Auto...

Page 371: ...rance invalid in phase A 2nd Harmonic A InRushRes traint OUT LED BO 92 89 1 Yes 3103 Tolerance invalid in phase B 2nd Harmonic B InRushRes traint OUT LED BO 92 90 1 Yes 3104 Tolerance invalid in phase C 2nd Harmonic C InRushRes traint OUT LED BO 92 91 1 Yes 3190 87 Set test state of 87 Test 87 87 Diff Prot IntS P On Of f LED FK TO NL IN E BO 92 10 6 1 Yes 3191 87 Set Commissioning state of 87 Comm...

Page 372: ...ce SP On Of f LED BI BO 3228 PDI Cu is stopped PDI Cu stop Prot Inter face SP O N OF F LED BI BO 3230 PDI FO failure PDI FO faulty Prot Inter face OUT On Of f LED BO 93 13 6 1 Yes 3232 PDI Cu failure PDI Cu faulty Prot Inter face OUT On Of f LED BO 93 13 8 1 Yes 3243 PDI FO connected to relay ID PDI FO con to Prot Inter face VI On Of f 3244 PDI Cu connected to relay ID PDI Cu con to Prot Inter fac...

Page 373: ...IntS P 3272 Alarm Broken current wire detected B Broken Iwire b Meas urem Super v IntS P 3273 Alarm Broken current wire detected C Broken Iwire c Meas urem Super v IntS P 3491 Master in Login state Master Login Diff Topo OUT O N OF F LED BO 93 19 1 1 Yes 3492 Slave in Login state Slave Login Diff Topo OUT O N OF F LED BO 93 19 2 1 Yes 3504 86 DT Intertrip 3 pole signal input 85 DT 3pol 85 DT Inter...

Page 374: ...ignals SP On Of f LED BI BO 3557 Remote Signal 9 input Rem Signal 9 Remote Signals SP On Of f LED BI BO 3558 Remote Signal 10 input Rem Signal10 Remote Signals SP On Of f LED BI BO 3559 Remote Signal 11 input Rem Signal11 Remote Signals SP On Of f LED BI BO 3560 Remote Signal 12 input Rem Signal12 Remote Signals SP On Of f LED BI BO 3561 Remote Signal 13 input Rem Signal13 Remote Signals SP On Of ...

Page 375: ...es 3579 Remote signal 7 received Rem Sig 7 Rx Remote Signals OUT On Of f LED BO 93 16 4 1 Yes 3580 Remote signal 8 received Rem Sig 8 Rx Remote Signals OUT On Of f LED BO 93 16 5 1 Yes 3581 Remote signal 9 received Rem Sig 9 Rx Remote Signals OUT On Of f LED BO 93 16 6 1 Yes 3582 Remote signal 10 received Rem Sig 10 Rx Remote Signals OUT On Of f LED BO 93 16 7 1 Yes 3583 Remote signal 11 received ...

Page 376: ... DTT OFF DTT Direct Trip OUT O N OF F LED BO 51 21 1 Yes 4422 Direct Transfer Trip is BLOCKED DTT BLOCK DTT Direct Trip OUT O N OF F ON OFF LED BO 51 22 1 Yes 4435 DTT TRIP command Phases ABC DTT TRIP ØABC DTT Direct Trip OUT ON LED BO 51 35 2 No 5203 BLOCK 81O U BLOCK 81O U 81 O U Freq SP O N OF F LED BI BO 70 17 6 1 Yes 5206 BLOCK 81 1 BLOCK 81 1 81 O U Freq SP O N OF F LED BI BO 70 17 7 1 Yes 5...

Page 377: ... picked up 81 O U Freq OUT ON OFF LED BO 70 23 2 2 Yes 5235 81 4 picked up 81 4 picked up 81 O U Freq OUT ON OFF LED BO 70 23 3 2 Yes 5236 81 1 TRIP 81 1 TRIP 81 O U Freq OUT ON LED BO 70 23 4 2 Yes 5237 81 2 TRIP 81 2 TRIP 81 O U Freq OUT ON LED BO 70 23 5 2 Yes 5238 81 3 TRIP 81 3 TRIP 81 O U Freq OUT ON LED BO 70 23 6 2 Yes 5239 81 4 TRIP 81 4 TRIP 81 O U Freq OUT ON LED BO 70 23 7 2 Yes 5240 8...

Page 378: ...BO 6861 74TC Trip circuit supervi sion OFF 74TC OFF 74TC Trip Circ OUT O N OF F LED BO 17 0 53 1 Yes 6865 74TC Failure Trip Circuit 74TC Trip cir 74TC Trip Circ OUT O N OF F LED BO 19 2 36 1 Yes 6866 74TC 1 blocked Binary input is not set 74TC 1 ProgFAIL 74TC Trip Circ OUT O N OF F LED BO 6867 74TC 2 blocked Binary input is not set 74TC 2 ProgFAIL 74TC Trip Circ OUT O N OF F LED BO 6868 74TC 3 blo...

Page 379: ...BackupO C InstantaneousTrip 5X B InstTRIP Back Up O C SP O N OF F ON OFF LED BI BO 64 10 1 Yes 7112 BLOCK Backup OverCur rent 67 TOC BLOCK 67 TOC Back Up O C SP O N OF F LED BI BO 7114 BLOCK Backup OverCur rent 67N TOC BLOCK 67N TOC Back Up O C SP O N OF F LED BI BO 7115 BLOCK Backup OverCur rent 67 B1 BLOCK 67 B1 Back Up O C SP O N OF F LED BI BO 7116 BLOCK Backup OverCur rent 67N B1 BLOCK 67N B1...

Page 380: ...C OUT LED BO 7157 Backup O C stage 51 N B is sw OFF 51 N B OFF Back Up O C OUT LED BO 7161 50 N 51 N Backup O C PICKED UP 5X B PICKUP Back Up O C OUT OFF m LED BO 64 61 2 Yes 7162 50 N 51 N Backup O C PICKUP Phase A 5X B Pickup ØA Back Up O C OUT ON LED BO 64 62 2 Yes 7163 50 N 51 N Backup O C PICKUP Phase B 5X B Pickup ØB Back Up O C OUT ON LED BO 64 63 2 Yes 7164 50 N 51 N Backup O C PICKUP Phas...

Page 381: ... 67 N TOC Pickup 67 N TOC PICK Back Up O C OUT On LED BO 7253 67 N General TRIP command 67 N TRIP Back Up O C OUT On LED BO 7254 67 N B1 TRIP 67 N B1 TRIP Back Up O C OUT On LED BO 7255 67 N B2 TRIP 67 N B2 TRIP Back Up O C OUT On LED BO 7256 67 N TOC TRIP 67 N TOC TRIP Back Up O C OUT On LED BO 7257 67 Phase A forward 67 forward ØA Back Up O C OUT On LED BO 7258 67 Phase B forward 67 forward ØB B...

Page 382: ...ting OUT O N OF F LED BO 15 3 45 1 Yes 7346 CB TEST canceled due to Power Sys Fault CB TSTstop FLT Testing OUT _Ev O N 7347 CB TEST canceled due to CB already OPEN CB TSTstop OPEN Testing OUT _Ev O N 7348 CB TEST canceled due to CB was NOT READY CB TSTstop NOTr Testing OUT _Ev O N 7349 CB TEST canceled due to CB stayed CLOSED CB TSTstop CLOS Testing OUT _Ev O N 7350 CB TEST was succesful CB TST OK...

Page 383: ... OFF 59 Vphg OFF 27 59 O U Volt OUT O N OF F LED BO 73 15 1 Yes 10216 59 Vphg Overvolt is BLOCKED 59 Vphg BLK 27 59 O U Volt OUT O N OF F ON OFF LED BO 73 16 1 Yes 10217 59 Vphph Overvolt is switched OFF 59 Vphph OFF 27 59 O U Volt OUT O N OF F LED BO 73 17 1 Yes 10218 59 Vphph Overvolt is BLOCKED 59 Vphph BLK 27 59 O U Volt OUT O N OF F ON OFF LED BO 73 18 1 Yes 10219 59 3V0 Overvolt is switched ...

Page 384: ...s switched OFF 27 Vphph OFF 27 59 O U Volt OUT O N OF F LED BO 73 27 1 Yes 10228 27 Vphph Undervolt is BLOCKED 27 Vphph BLK 27 59 O U Volt OUT O N OF F ON OFF LED BO 73 28 1 Yes 10229 27 V1 Undervolt is switched OFF 27 V1 OFF 27 59 O U Volt OUT O N OF F LED BO 73 29 1 Yes 10230 27 V1 Undervolt is BLOCKED 27 V1 BLK 27 59 O U Volt OUT O N OF F ON OFF LED BO 73 30 1 Yes 10231 27 59 Voltage protection...

Page 385: ...pg PU B 27 59 O U Volt OUT LED BO 73 13 7 2 Yes 10253 59 2 Vphg Pickup C 59 2 Vpg PU C 27 59 O U Volt OUT LED BO 73 13 8 2 Yes 10255 59 1 Vphph Pickup 59 1 Vpp Pickup 27 59 O U Volt OUT ON OFF LED BO 73 55 2 Yes 10256 59 2 Vphph Pickup 59 2 Vpp Pickup 27 59 O U Volt OUT ON OFF LED BO 73 56 2 Yes 10257 59 Vphph Pickup A B 59 Vpp PickupAB 27 59 O U Volt OUT ON OFF LED BO 73 57 2 Yes 10258 59 Vphph P...

Page 386: ...T ON LED BO 73 74 2 Yes 10280 59 1 V1 Pickup 59 1 V1 Pickup 27 59 O U Volt OUT ON OFF LED BO 73 80 2 Yes 10281 59 2 V1 Pickup 59 2 V1 Pickup 27 59 O U Volt OUT ON OFF LED BO 73 81 2 Yes 10282 59 1 V1 TimeOut 59 1 V1TimeOut 27 59 O U Volt OUT LED BO 10283 59 2 V1 TimeOut 59 2 V1TimeOut 27 59 O U Volt OUT LED BO 10284 59 V1 TRIP command 59 V1 TRIP 27 59 O U Volt OUT ON LED BO 73 84 2 Yes 10290 59 1 ...

Page 387: ... 27 2 VpgTimeOut 27 59 O U Volt OUT LED BO 10317 27 Vphg TRIP command 27 Vpg TRIP 27 59 O U Volt OUT ON LED BO 73 11 7 2 Yes 10318 27 1 Vphg Pickup A 27 1 Vpg PU A 27 59 O U Volt OUT LED BO 73 14 5 2 Yes 10319 27 1 Vphg Pickup B 27 1 Vpg PU B 27 59 O U Volt OUT LED BO 73 14 6 2 Yes 10320 27 1 Vphg Pickup C 27 1 Vpg PU C 27 59 O U Volt OUT LED BO 73 14 7 2 Yes 10321 27 2 Vphg Pickup A 27 2 Vpg PU A...

Page 388: ...olt OUT LED BO 73 15 4 2 Yes 10337 27 2 Vphph Pickup B C 27 2 Vpp PU BC 27 59 O U Volt OUT LED BO 73 15 5 2 Yes 10338 27 2 Vphph Pickup C A 27 2 Vpp PU CA 27 59 O U Volt OUT LED BO 73 15 6 2 Yes 17525 85 DT Received 3pole 85 DT rec 3pole 85 DT Inter trip OUT On Of f LED BO 17526 85 DT Sending 3pole 85 DT sen 3pole 85 DT Inter trip OUT O N OF F LED BO 17530 67 N Backup O C is BLOCKED 67 N BLOCK Bac...

Page 389: ...erationcounter Q9 OpCnt Control Device VI 32100 87L Protection blocking signal 87L block 87 Diff Prot SP On Of f LED BI BO 32102 87L Protection is active 87L active 87 Diff Prot OUT On LED BO 92 13 3 1 Yes 32103 87L Fault detection A 87L Fault A 87 Diff Prot OUT On Off m LED BO 92 13 4 2 Yes 32104 87L Fault detection B 87L Fault B 87 Diff Prot OUT On Off m LED BO 92 13 5 2 Yes 32105 87L Fault dete...

Page 390: ...87N L Protection is active 87N L active 87 Diff Prot OUT On LED BO 92 16 3 1 Yes 32122 87 N L Fault detection 87 N L Gen Flt 87 Diff Prot OUT On Off m LED BO 92 11 1 2 Yes 32124 87N L Fault detection of I Diff 87N L I Flt 87 Diff Prot OUT On Off m LED BO 92 16 4 2 Yes 32125 87 N L General TRIP 87 N L Gen TRIP 87 Diff Prot OUT On Off m LED BO 92 11 2 2 Yes 32126 87N L Protection is blocked 87N L bl...

Page 391: ...N OF F 32201 PDI Test Mode Cu ON OFF PDITestCuon OFF Device General IntS P O N OF F 32202 PDI Test Mode PDI Test Mode Device General OUT O N OF F LED BO 32203 PDI Test Mode remote PDI Test remote Device General OUT O N OF F LED BO 32224 PDI FO aging distance damping high PDI FO AGING Device General OUT LED BO 32225 PDI Cu aging distance damping high PDI Cu AGING Device General OUT LED BO 32227 PDI...

Page 392: ...balance Fail V absent VT FuseFail 10s VT FuseFail Fail Ph Seq Fail Battery Error Board 0 Error Offset Alarm adjustm Error Board 1 Error Board 2 Error Board 3 Error Board 4 Error Board 5 161 Fail I Superv 289 163 Failure Σi Fail I balance 164 Fail V Superv 167 168 Fail V balance Fail V absent F 4 Functions Settings Information F 4 Group Indications 392 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 E...

Page 393: ...C CD DD 619 I1 positive sequence I1 Measurement CFC CD DD 620 I2 negative sequence I2 Measurement CFC CD DD 621 Va Va Measurement 134 129 No 9 4 CFC CD DD 622 Vb Vb Measurement 134 129 No 9 5 CFC CD DD 623 Vc Vc Measurement 134 129 No 9 6 CFC CD DD 624 Va b Va b Measurement 134 129 No 9 10 CFC CD DD 625 Vb c Vb c Measurement 134 129 No 9 11 CFC CD DD 626 Vc a Vc a Measurement 134 129 No 9 12 CFC C...

Page 394: ...ax meter CFC CD DD 841 I C Demand Minimum ICdmdMin Min Max meter CFC CD DD 842 I C Demand Maximum ICdmdMax Min Max meter CFC CD DD 843 I1 positive sequence Demand Minimum I1dmdMin Min Max meter CFC CD DD 844 I1 positive sequence Demand Maximum I1dmdMax Min Max meter CFC CD DD 845 Active Power Demand Minimum PdMin Min Max meter CFC CD DD 846 Active Power Demand Maximum PdMax Min Max meter CFC CD DD...

Page 395: ... aMax Min Max meter CFC CD DD 874 V1 positive sequence Voltage Minimum V1 Min Min Max meter CFC CD DD 875 V1 positive sequence Voltage Maximum V1 Max Min Max meter CFC CD DD 880 Apparent Power Minimum Smin Min Max meter CFC CD DD 881 Apparent Power Maximum Smax Min Max meter CFC CD DD 882 Frequency Minimum fmin Min Max meter CFC CD DD 883 Frequency Maximum fmax Min Max meter CFC CD DD 888 Pulsed E...

Page 396: ...051 Power Factor Maximum Reverse PFmax Rev Min Max meter CFC CD DD 1052 Active Power Demand Forward Pdmd Forw Demand meter CFC CD DD 1053 Active Power Demand Reverse Pdmd Rev Demand meter CFC CD DD 1054 Reactive Power Demand Forward Qdmd Forw Demand meter CFC CD DD 1055 Reactive Power Demand Reverse Qdmd Rev Demand meter CFC CD DD 7731 PHI I AB local Φ I AB Measurement CFC CD DD 7732 PHI I BC loca...

Page 397: ...764 I B of Operational nominal current I B_opN Measure Master CFC CD DD 7765 Angle I B_remote I B_local ΦI B Measure Master CFC CD DD 7766 I C of Operational nominal current I C_opN Measure Master CFC CD DD 7767 Angle I C_remote I C_local ΦI C Measure Master CFC CD DD 7769 V A of Operational nominal voltage V A_opN Measure Master CFC CD DD 7770 Angle V A_remote V A_local ΦV A Measure Master CFC CD...

Page 398: ... CD DD 10102 Min Zero Sequence Voltage 3V0 3V0min Min Max meter CFC CD DD 10103 Max Zero Sequence Voltage 3V0 3V0max Min Max meter CFC CD DD 32204 Output power of the FO Interface OutputPower FO Measure PDI CFC CD DD 32205 Input power of the FO Interface Input Power FO Measure PDI CFC CD DD 32206 Budget of the FO Interface Budget FO Measure PDI CFC CD DD 32208 Attenuation of the Cu Interface Atten...

Page 399: ...3 PDI FO BIAS current PDI FO BIAS Measure PDI CFC CD DD 32226 Rest3I0 Operational nominal current Rest3I0 IDiff IRest CFC CD DD 32230 Send telegrams in the last second Send Tel sec Measure PDI CFC CD DD 32231 Good received telegrams in the last sec Good Rec sec Measure PDI CFC CD DD 32232 Bad received telegrams in the last sec Bad Rec sec Measure PDI CFC CD DD 32233 Send telegrams in the last minu...

Page 400: ...400 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 401: ... Description E50417 H1176 C151 B6 2 SIPROTEC DIGSI Start UP E50417 G1176 C152 A3 3 DIGSI CFC Manual E50417 H1176 C098 B2 4 SIPROTEC SIGRA 4 Manual E50417 H1176 C070 A7 SIPROTEC 4 7SD80 Manual 401 E50417 G1100 C474 A2 Edition 02 2018 ...

Page 402: ...402 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 2018 ...

Page 403: ... CFC is a graphical editor with which a program can be created and configured by using ready made blocks CFC blocks Blocks are parts of the user program delimited by their function their structure or their purpose Chatter ON 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...

Page 404: ...e contents of the area selected in the navigation window for example indications measured values etc of the information lists or the function selection for the device configuration DCF77 The extremely precise official time is determined in Germany by the Physikalisch Technische Bundesanstalt PTB in Braunschweig The atomic clock station of the PTB transmits this time via the long wave time signal t...

Page 405: ...pparatus to function fault free in a specified environment without influencing the environment unduly EMC Electromagnetic compatibility ESD protection ESD protection is the total of all the means and measures used to protect electrostatic sensitive devices EVA Limiting value user defined ExBPxx External bit pattern indication via an ETHERNET connection device specific Bit pattern indication ExC Ex...

Page 406: ...nication system They serve for direct information exchange among the relays This mechanism implements cross communication between bay units GPS Global Positioning System Satellites with atomic clocks on board orbit the earth twice a day on different paths in approx 20 000 km They transmit signals which also contain the GPS universal time The GPS receiver determines its own position from the signal...

Page 407: ...ands These are transmitted to the modem within the framework of modem initialization The commands can for example force specific settings for the modem Inter relay communication IRC combination IntSP Internal single point indication Single point indication IntSP_Ev Internal indication Spontaneous event Fleeting indication Single point indication IRC combination Inter Relay Communication IRC is use...

Page 408: ... value energy purchase supply energy transportation MLFB MLFB is the abbreviation for MaschinenLesbare FabrikateBezeichnung machine readable product designa tion This is the equivalent of an order number The type and version of a SIPROTEC 4 device is coded in the order number Modem connection This object type contains information on both partners of a modem connection the local modem and the remot...

Page 409: ...nection 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 OUT_Ev Output indication Spontaneous event Fleeting indication Parameterization Comprehensive term for all setting work on the device The parameterization is done with DIGSI or sometimes also directly on the device Parameter set The pa...

Page 410: ...ron RSxxx interface Serial interfaces RS232 RS422 485 Service interface Rear serial interface on the devices for connecting DIGSI for example via modem SICAM PAS Power Automation System Substation control system The range of possible configurations spans from integrated standalone systems SICAM PAS and M C with SICAM PAS CC on one computer to separate hardware for SICAM PAS and SICAM PAS CC to dis...

Page 411: ...e may only exchange data with a master after being prompted to do so by the master SIPROTEC 4 devices operate as slaves SP Single point indication SP_W Single point indication Spontaneous event Fleeting indication Single point indication System interface Rear serial interface on the devices for connecting to a substation controller via IEC or PROFIBUS TI Transformer Tap Indication Time stamp Time ...

Page 412: ...services A VD can be a physical device a module of a device or a software module VD address The VD address is assigned automatically by DIGSI Manager It exists only once in the entire project and thus serves to identify unambiguously a real SIPROTEC 4 device The VD address assigned by DIGSI Manager must be transferred to the SIPROTEC 4 device in order to allow communication with DIGSI Device Edito...

Page 413: ...Recording 245 Check Polarität 241 Switching Check for Configured Equipment 245 Time Synchronization 228 Transformer Connections of Two Line Ends 244 User defined Functions 244 Check Circuit Breaker Failure Protection 238 Checking a Connection 237 Checking the System Connections 225 Checking phase rotation 239 Transformer Connections 239 Checking Status of Binary Inputs and Outputs 233 Circuit brea...

Page 414: ...ping 124 Power Swings 124 Underfrequency 123 Frequency Protection 281 Operating Ranges 281 Pickup Values 126 281 Time Delay 126 Times 281 Tolerances 281 Function Modules 289 Fuse Failure Monitor 154 160 G General limits for user defined functions 290 Ground Current Differential Protection Pickup Value 57 Ground Fault 59 Ground Fault Differential Protection 25 25 Ground Fault Direction Determinatio...

Page 415: ... Tripping 70 Restraint current values 186 Retrieving Parameters 192 S Schalthoheit 199 Schaltmodus 200 Schaltstatistik 294 Selection of Default Display Start page 34 Service Conditions 257 Setting Group Change 207 Setting Groups Changing 41 Single element Breaker Failure Protection 101 Software Monitoring 150 Standard Interlocking 197 Standards 254 Starting Test Fault Recording 245 Statistik 294 S...

Page 416: ...ionary Opera tion 256 Vibration and Shock Stress during Transport 256 Voltage Balance 151 Voltage inputs 250 Voltage Phase Rotation 154 Voltage Protection 26 Voltage Protection ANSI 59 108 Voltage transformers connection Polarity Check 241 W Warning Temperature Level 106 Watchdog 150 Wire Break Monitoring 152 Wirkschnittstellen 252 Index 416 SIPROTEC 4 7SD80 Manual E50417 G1100 C474 A2 Edition 02 ...

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