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2.2 Protection Data Interfaces and Protection Data Topology

85

7SD5 Manual
C53000-G1176-C169-1

2.2.3

Differential Protection Topology

2.2.3.1

Setting Notes

Protection Data
Topology

First of all, define your protection data communication topology: number the devices
consecutively. This numbering is a serial device index that serves for your own over-
view. It starts for each distance differential protection system (i.e. for each protected
object) with 1. For the differential protection system the device with index 1 is always
the absolute-chronology master, i.e. the absolute time management of all devices
which belong together depends on the absolute time management of this device, if
synchronization is set to

Timing-Master

. As a result the time information of all devices

is comparable at all times. The device index serves for unique definition of the devices
within the differential protection system (i.e. for one protected object).

An ID number is also to be given to each single device (device-ID). The device–ID is
used by the communication system to identify each individual device. It must be
between 1 and 65534 and must be unique within the communication system. The ID
number identifies the devices in the communication system (like a device address)
since the exchange of information between several differential protection systems
(thus also for several protective relay) can be executed via the same communication
system.

Please make sure that the possible communication links and the existing interfaces
are in accordance with each other. If not all devices are equipped with

two

protection

data interfaces, those with only

one

protection data interface must be located at the

ends of the communication chain. A

ring topology

is only possible if

all

devices in a

differential protection system are equipped with two protection data interfaces.

If you work with different physical interfaces and communications links, please make
sure that every protection data interface corresponds to the projected communication
link.

For a protected object with two ends (e.g. a line) the addresses

4701

ID OF RELAY

1

and

4702

ID OF RELAY 2

are set, e.g. for device 1 the device-ID

16

and for device

2 the device-ID

17

(Figure 2-12). The indices of the devices and the device-IDs do not

have to match here, as mentioned above.

Figure 2-12

Differential protection topology for 2 ends with 2 devices — example

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Summary of Contents for siprotec 7SD5

Page 1: ...on with Distance Protection 7SD5 V 4 3 Manual C53000 G1176 C169 1 Preface Introduction 1 Functions 2 Mounting and Commissioning 3 Technical Data 4 Appendix A Literature Glossary Index w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 2: ...2 7SD5 Manual C53000 G1176 C169 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 3: ...he right to make technical improvements without notice Copyright Copyright Siemens AG 2004 All rights reserved Dissemination or reproduction of this document or evaluation and communication of its contents is not authorized except where expressly permitted Violations are liable for damages All rights reserved particularly for the purposes of patent application or trademark registration Registered ...

Page 4: ...4 7SD5 Manual C53000 G1176 C169 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 5: ... version V 4 3 Indication of Conformity This product is UL certified according to the Technical Data Additional Support Should further information on the System SIPROTEC 4 be desired or should partic ular problems arise which are not covered sufficiently for the purchaser s purpose the matter should be referred to the local Siemens representative This product complies with the directive of the Cou...

Page 6: ...e device Please observe them The following indicators and standard definitions are used DANGER indicates that death severe personal injury or substantial property damage can result if proper precautions are not taken Warning indicates that death severe personal injury or substantial property damage can result if proper precautions are not taken Caution indicates that minor personal injury or prope...

Page 7: ...er names Param eter addresses contain the suffix A in the overview tables if the parameter can only be set in DIGSI via the option Display additional settings Parameter Conditions Possible settings of text parameters which may appear word for word in the display of the device or on the screen of a personal computer with operation soft ware DIGSI are additionally written in italics This also applie...

Page 8: ...th positive below with negative edge Formation of one analog output signal from a number of analog input signals Limit stage with setting address and parameter designator name Timer pickup delay T example adjustable with setting address and parameter designator name Timer dropout delay T example non adjustable Dynamic triggered pulse timer T monoflop Static memory RS flipflop with setting input S ...

Page 9: ...Purpose of the Setting Groups 55 2 1 3 2 Setting Notes 55 2 1 3 3 Settings 56 2 1 3 4 Information List 56 2 1 4 General Protection Data Power System Data 2 56 2 1 4 1 Setting Notes 56 2 1 4 2 Settings 68 2 1 4 3 Information List 71 2 2 Protection Data Interfaces and Protection Data Topology 74 2 2 1 Functional Description 74 2 2 1 1 Protection Data Topology Protection Data Communication 74 2 2 2 P...

Page 10: ... the Impedances 118 2 5 1 4 Setting Notes 125 2 5 1 5 Settings 132 2 5 1 6 Information List 135 2 5 2 Distance Protection with Quadrilateral Characteristic optional 137 2 5 2 1 Method of Operation 137 2 5 2 2 Setting Notes 143 2 5 2 3 Settings 147 2 5 3 Distance Protection with MHO Characteristic optional 150 2 5 3 1 Functional Description 150 2 5 3 2 Setting Notes 157 2 5 3 3 Settings 160 2 5 4 T...

Page 11: ...rth Fault Protection in Earthed Systems optional 207 2 8 1 Method of Operation 207 2 8 2 Setting Notes 219 2 8 3 Settings 228 2 8 4 Information List 231 2 9 Teleprotection for Earth Fault Protection optional 232 2 9 1 General 232 2 9 2 Directional Comparison Pickup 233 2 9 3 Directional Unblocking Scheme 236 2 9 4 Directional Blocking Scheme 239 2 9 5 Transient Blocking 242 2 9 6 Measures for Weak...

Page 12: ...269 2 14 3 Setting Notes 275 2 14 4 Settings 281 2 14 5 Information List 282 2 15 Automatic Reclosure Function optional 284 2 15 1 Functional Description 285 2 15 2 Setting Notes 301 2 15 3 Settings 309 2 15 4 Information List 312 2 16 Synchronism and Voltage Check optional 314 2 16 1 Method of Operation 314 2 16 2 Setting Notes 318 2 16 3 Settings 322 2 16 4 Information List 323 2 17 Undervoltage...

Page 13: ...tting Notes 388 2 22 1 6 Settings 390 2 22 1 7 Information List 391 2 22 2 Trip Circuit Supervision 391 2 22 2 1 Functional Description 392 2 22 2 2 Setting Notes 395 2 22 2 3 Settings 395 2 22 2 4 Information List 395 2 23 Function Control and Circuit Breaker Test 396 2 23 1 Function Control 396 2 23 1 1 Line Energization Recognition 396 2 23 1 2 Detection of the Circuit Breaker Position 399 2 23...

Page 14: ...aphic Fault Records 429 2 24 8 1 Functional Description 429 2 24 8 2 Settings 430 2 24 8 3 Information List 430 2 24 9 Demand Measurement Setup 431 2 24 9 1 Long term Average Values 431 2 24 9 2 Settings 431 2 24 9 3 Information List 431 2 24 10 Min Max Measurement Setup 432 2 24 10 1 Reset 432 2 24 10 2 Settings 432 2 24 10 3 Information List 432 2 24 11 Set Points Measured Values 434 2 24 11 1 L...

Page 15: ... 481 3 3 5 Checking the Protection Data Topology 484 3 3 6 Tests for the Circuit Breaker Failure Protection 490 3 3 7 Checking the Instrument Transformer Connections of One Line End 492 3 3 8 Checking the Instrument Transformer Connections of Two Line Ends 494 3 3 9 Checking the Instrument Transformer Connections for More than Two Ends 506 3 3 10 Measuring the Operating Time of the Circuit Breaker...

Page 16: ...ance Protection optional 540 4 8 Earth Fault Protection in Earthed Systems optional 541 4 9 Teleprotection for Earth Fault Protection optional 550 4 10 Weak infeed Tripping classic optional 551 4 11 Weak infeed Tripping French specif optional 552 4 12 Direct Remote Trip and Transmission of Binary Information 553 4 13 Instantaneous High Current Switch onto Fault Protection SOTF 554 4 14 Time Overcu...

Page 17: ...nal Assignments 590 A 2 1 Panel Flush Mounting or Cubicle Mounting 590 A 2 2 Panel Surface Mounting 595 A 3 Connection Examples 602 A 3 1 Current Transformer Connection Examples 602 A 3 2 Voltage Transformer Connection Examples 606 A 4 Default Settings 609 A 4 1 LEDs 609 A 4 2 Binary Input 610 A 4 3 Binary Output 611 A 4 4 Function Keys 612 A 4 5 Default Display 612 A 4 6 Pre defined CFC Charts 61...

Page 18: ...Contents 18 7SD5 Manual C53000 G1176 C169 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 19: ...al Protection with Distance Protection 7SD5 is intro duced in this chapter The 7SD5 is presented in its application characteristics and functional scope 1 1 Overall Operation 20 1 2 Application Scope 23 1 3 Characteristics 27 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 20: ... appropriate for the internal processing of the device The device has 4 current and 4 voltage inputs Three current inputs are provided for measurement of the phase currents a further measuring input I4 may be configured to measure the earth current residual current from the current trans former star point or separate earth current transformer the earth current of a parallel line for parallel line ...

Page 21: ...em Interrogation of threshold values and time sequences Processing of signals for the logic functions Decisions for trip and close commands Storage of messages fault annunciations as well as fault records for system fault analysis Operating system and related function management such as e g data recording real time clock communication interfaces etc The information is provided via output amplifier...

Page 22: ... commissioning checking and also during operation of the device using a standard browser A software program named WEB Monitor supports this function which has been optimized with regard to the line protection system Protection Data Interfaces The protection data interfaces are a particular case Depending on the model there are one or two protection data interfaces Via these interfaces the measured...

Page 23: ...tion function voltage transformers are required They are also needed for the acquisition and display of measured values voltages power power factor The devices located at the ends of the protected zone exchange measuring informa tion via protection data interfaces using dedicated communication links usually fibre optic cables or a communication network provided that they operate with differential ...

Page 24: ...ines is possible with or without serial compensation The distance protection may be supplemented by teleprotection using various signal transmission schemes for fast tripping on 100 of the line length In addition an earth fault protection for high resistance earth faults ordering option is available which may be directional non directional and may also be incorporated in signal transmission On lin...

Page 25: ...conditions for switching e g switching error protection can be established with the aid of integrated user configurable logic functions Messages and Mea sured Values Fault Recording The operating messages provide information about conditions in the power system and the device Measurement quantities and values that are calculated can be dis played locally and communicated via the serial interfaces ...

Page 26: ...s IRIG B or DCF77 Other interfaces provide for communication between the devices at the ends of the protected object These protection data interfaces have been mentioned above in the protection functions The operator and service interface allow to operate the device remotely or locally using a standard browser This is possible during commissioning checking and also during operation of the devices ...

Page 27: ...e stability against load jumps and power swings Due to phase segregated measurement the pickup sensitivity is independent of the type of fault Suited for transformers in the protected area order option Detection of high resistant weak current faults due to high sensitivity Insensitive against in rush and charge currents also for transformers in the pro tected area and against higher frequency swit...

Page 28: ...nce zones selectable as forward reverse or non directional reaching one may be used as an overreach zone Nine time stages for the distance zones Direction determination with polygon or polarization with MHO characteristic is done with unfaulted loop quadrature voltages and voltage memory thereby achieving unlimited directional sensitivity and not affected by capacitive voltage transformer transien...

Page 29: ...rror currents during current transformer saturation Second harmonic inrush restraint Optionally earth fault protection with zero sequence voltage tripping time or inverse time tripping Each stage can be set to be non directional or directional in the forward or reverse direction Single pole tripping enabled by integrated phase selector Direction determination with zero sequence system quantities I...

Page 30: ... for manual closure or following each closure of the circuit breaker With integrated line energization detection Automatic Reclo sure Function optional For reclosure after single pole three pole or single pole and three pole tripping Single or multiple reclosure up to 8 reclosure attempts With separate action times for every reclosure attempt optionally without action times With separate dead time...

Page 31: ... or overfrequency f with 4 frequency limits and delay times that are independently adjustable Particularly insensitive to harmonics and abrupt phase angle changes Large frequency range approx 25 Hz to 70 Hz Fault Locator Optionally single ended conventional or double ended fault location via communi cation interfaces Initiated by trip command or reset of the fault detection Fault location output i...

Page 32: ...breaker auxiliary contacts for com mands with feedback Plausibility monitoring of the circuit breaker position and monitoring of interlocking conditions for switching operations Monitoring Functions Increase of the availability of the device by monitoring of the internal measurement circuits auxiliary power supply hardware and software Current transformer and voltage transformer secondary circuits...

Page 33: ...cumulation of the interrupted fault currents Communication with central control and memory components possible via serial in terfaces depending on the individual ordering variant optionally via electrical RS485 bus connection fiber optic cable or a modem connection Commissioning aids such as connection and direction checks as well as interface check and circuit breaker test functions The IBS Tool ...

Page 34: ...1 Introduction 34 7SD5 Manual C53000 G1176 C169 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 35: ...ction optional 175 2 8 Earth Fault Protection in Earthed Systems optional 207 2 9 Teleprotection for Earth Fault Protection optional 232 2 10 Weak infeed Tripping optional 250 2 11 Direct Local Trip 260 2 12 Direct Remote Trip and Transmission of Binary Information 262 2 13 Instantaneous High Current Switch onto Fault Protection SOTF 265 2 14 Backup Time Overcurrent Protection 269 2 15 Automatic R...

Page 36: ...2 Functions 36 7SD5 Manual C53000 G1176 C169 1 2 24 Ancillary Functions 414 2 25 Command Processing 436 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 37: ...se of application After entering some System Data frequency you inform the device Section 2 1 2 of the properties of the main protected object This comprises e g nominal system data nominal data of instrument transformers polarity and connection type of measured values The above information is sufficient to describe the protected object to the device s main protection function i e the differential...

Page 38: ...addresses 1201 STATE OF DIFF and 1501 FCT Distance When the differential protection is switched off or blocked the distance protection continues to operate without restrictions You can also operate the differential protection without distance protection mode 2 addresses 115 116 and 117 Disabled The device behaves in this case like a normal line differential protection relay In mode 3 the different...

Page 39: ...Topology provides more information The number of relays address 147 NUMBER OF RELAY must be equal to the number of measuring locations at the ends of the protected object Please observe that only current transformer sets that limit the protected object are counted The line in Figure 2 1 for instance has three ends and three devices It is limited by three current trans former sets Two devices would...

Page 40: ...ich are set highest establish the pickup criteria If you set address 117 Dis PICKUP to Disabled the distance protection function and all associated functions will not be available Please note that the power swing supplement see also Section 2 6 only works to gether with the Z quadrilat pickup In all other cases it is ineffective even though you have set address 120 Power Swing Enabled To complemen...

Page 41: ...en using the earth fault protection it can be complemented by teleprotection schemes Select the desired scheme at address 132 Teleprot E F You can select the direction comparison scheme Dir Comp Pickup the unblocking scheme UNBLOCKING and the blocking scheme BLOCKING The procedures are described in detail in Section 2 9 If you do not want to use teleprotection in conjunction with earth fault prote...

Page 42: ...ing is recommended for time graded protection If the protection function which is to operate with automatic reclosure does not have a general pickup signal for starting the action times select Trip without T action Address 137 U O VOLTAGE allows to activate the voltage protection function with a variety of undervoltage and overvoltage protection stages In particular the overvolt age protection wit...

Page 43: ...nabled Disabled Power Swing detection 121 Teleprot Dist PUTT Z1B PUTT Pickup POTT Dir Comp Pickup UNBLOCKING BLOCKING Rev Interlock Pilot wire comp Disabled Disabled Teleprotection for Distance prot 122 DTT Direct Trip Disabled Enabled Disabled DTT Direct Transfer Trip 124 HS SOTF O C Disabled Enabled Disabled Instantaneous HighSpeed SOTF Overcurrent 125 Weak Infeed Disabled Enabled Logic no 2 Dis...

Page 44: ...tection 140 Trip Cir Sup Disabled 1 trip circuit 2 trip circuits 3 trip circuits Disabled Trip Circuit Supervision 142 Therm Overload Disabled Enabled Disabled Thermal Overload Protection 143 TRANSFORMER NO YES NO Transformer inside protection zone 144 V TRANSFORMER Not connected connected connected Voltage transformers 145 P INTERFACE 1 Enabled Disabled Enabled Protection Interface 1 Port D 146 P...

Page 45: ... Figure 2 2 Polarity of current transformers Nominal Values of theTransformers If voltage transformers are connected the device obtains in addresses 203 Unom PRIMARY and 204 Unom SECONDARY information on the primary and secondary nominal voltage phase to phase voltage and in addresses 205 CT PRIMARY and 206 CT SECONDARY information on the primary and secondary nominal currents of the current trans...

Page 46: ...e for determining the life line condition in case of automatic reclosure During configuration of the device functions Section 2 1 1 it has been de termined whether the device is to work with or without measured voltages w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 47: ...212 Usync connect the type of voltage used by the busbar for synchronism check is configured The device then selects automatically the appropriate feeder voltage If the two measuring points used for synchronism check i e feeder voltage trans former and busbar voltage transformer are not separated by devices that cause a relative phase shift then the parameter in address 214 ϕ Usync Uline is not re...

Page 48: ... which are connected to the set of current transformers Various possibilities exist for the fourth current input I4 Connection of the I4 input to the earth current in the starpoint of the set of current transformers on the protected feeder normal connection Address 220 is then set to I4 transformer In prot line and address 221 I4 Iph CT 1 Connection of the I4 input to a separate earth current tran...

Page 49: ...t Address 220 I4 transformer Not connected Address 221 I4 Iph CT is then irrelevant In this case the neutral current is calculated from the sum of the phase currents NominalFrequency The nominal frequency of the system is set in address 230 Rated Frequency The presetting according to the ordering code MLFB only needs to be changed if the device is applied in a region different to the one indicated...

Page 50: ...e that the circuit breaker has securely closed There is no risk in setting this time too long as the close command will in any event be ter minated following a new trip command from a protection function This setting is only possible via DIGSI at Additional Settings Circuit Breaker Test 7SD5 allows a circuit breaker test during operation by means of a tripping and a closing command entered on the ...

Page 51: ...oughly from the DC resistance Ri of the secondary wind ing Pi Ri IN 2 The ratio between the operational accuracy limit factor and the nominal accuracy limit factor n n is set under address 251 K_ALF K_ALF_N The CT error at nominal current plus a safety margin is set under address 253 E ALF ALF_N It is equal to the current measuring deviation for primary nominal current intensity F1 according to VD...

Page 52: ...th single phase faults flows back and forth via the secondary lines factor 2 From that the power for nominal current IN 5 A is calculated Pl 0 175 Ω 5 A 2 4 375 VA The entire connected burden consists of the burden of the incoming lines and the burden of the device P 4 375 VA 0 3 VA 4 675 VA Thus the ratio of the accuracy limit factors is as follows CT Class Standard Error at Rated Current Error a...

Page 53: ... the maximum differential current at the limits of the tap changer under nominal conditions referred to the mean current and add it to the current transformer error as discussed above addresses 253 and 254 This correction is performed only at that relay facing the regulated winding of the power transformer Calculation example Transformer YNd5 35 MV 110 kV 25 kV Y winding with tap changer 10 From t...

Page 54: ...tching ratio Phase VT To Open Delta VT 212 Usync connect L1 E L2 E L3 E L1 L2 L2 L3 L3 L1 L1 E VT connection for sync voltage 214A ϕ Usync Uline 0 360 0 Angle adjustment Usync Uline 215 U line Usync 0 50 2 00 1 00 Matching ratio U line Usync 220 I4 transformer Not connected In prot line In paral line IY starpoint In prot line I4 current transformer is 221 I4 Iph CT 0 010 5 000 1 000 Matching ratio...

Page 55: ...quickly All setting groups are stored in the relay Only one setting group may be active at a given time 2 1 3 2 Setting Notes General If multiple setting groups are not required Group A is the default selection Then the rest of this section is not applicable If multiple setting groups are desired the setting group change option must be set to Grp Chge OPTION Enabled in the relay configuration of t...

Page 56: ...r if address 143 TRANSFORMER has been set to NO see Section 2 1 1 3 With address 1103 FullScaleVolt you inform the device of the primary nominal voltage phase to phase of the equipment to be protected if voltages are applied This setting influences the displays of the operational measured values in The primary nominal current address 1104 FullScaleCurr is that of the protect ed object For cables t...

Page 57: ... measured voltages are applied to the relay In general select the nominal voltage of the transformer winding facing the device However if the protected transformer is equipped with a voltage tap changer at one winding then do not use the nominal voltage of that winding but the voltage that cor responds to the mean value of the currents at the ends of the control range of the tap changer In this wa...

Page 58: ...vant for the differential protection whereas address 1161 VECTOR GROUP U serves as a basis for the computation of measured voltages beyond the transformer Address 1163 TRANS STP IS is used to set whether the power transformer starpoint facing the device is earthed or not If the starpoint is earthed the device will eliminate the zero sequence current of the relevant side since this zero sequence cu...

Page 59: ...in Ω mile if mile was selected as distance unit The corresponding line length is entered in address 1113 Line Length in kilometers or in miles If after entry of the reactance per unit of line length in address 1111 or of the line length in address 1113 the distance unit is changed in address 236 the line data must be entered again for the revised distance unit The capacitance per unit length C of ...

Page 60: ...11 the setting x 0 229 Ω km is entered The secondary per distance unit capacitance is therefore In address 1112 the setting c 0 015 µF km is entered Earth Impedance Residual Com pensation Matching of the earth to line impedance is an essential prerequisite for the accurate measurement of the fault distance distance protection fault locator during earth faults This compensation is either achieved b...

Page 61: ...19 Ω km zero sequence impedance where s line length For earth impedance ratios the following emerge The earth impedance residual compensation factor setting for the first zone Z1 may be different from that of the remaining zones of the distance protection This allows the setting of the exact values for the protected line while at the same time the setting for the back up zones may be a close appro...

Page 62: ...ignificant angle differences may exist as illustrat ed by the following example Calculation Example 110 kV single conductor oil filled cable 3 185 mm2 Cu with the following data Z1 s 0 408 ej73 Ω km positive sequence impedance Z0 s 0 632 ej18 4 Ω km zero sequence impedance where s line length The calculation of the earth impedance residual compensation factor K0 results in The magnitude of K0 is t...

Page 63: ...evice is applied to a double circuit line parallel lines and parallel line compen sation for the distance and or fault location function is used the mutual coupling of the two lines must be considered A prerequisite for this is that the earth residual current of the parallel line has been connected to the measuring input I4 of the device and that this was configured with the power system data Sect...

Page 64: ...ich it picks up can be set in address 1140 I CTsat Thres This is the current level above which saturation may be present The setting disables the saturation detector This parameter can only be altered with DIGSI under Additional Settings If current transformer saturation is ex pected the following equation may be used as a thumb rule for this setting PN Nominal CT burden VA Pi Nominal CT internal ...

Page 65: ...ed to determine closure of the circuit breaker whereas CB OR I or M C implies that either the cur rents or the states of the circuit breaker auxiliary contacts are used to determine closure of the circuit breaker If the voltage transformers are not situated on the line side the setting CB OR I or M C must be used In the case of I or Man Close only the currents or the manual close signals are used ...

Page 66: ...losure usually Q0 If none is set here a CLOSE command via the control will not generate a MANUAL CLOSE impulse for the protection function Three pole Coupling Three pole coupling is only relevant if single pole auto reclosures are carried out If not tripping is always three pole The remainder of this margin heading section is then irrelevant Address 1155 3pole coupling determines whether any multi...

Page 67: ... 2 6 This is because the generator considers the two single phase to earth faults as one double phase earth fault with correspondingly high dynamic load on the turbine shaft With the setting 1155 3pole coupling with PICKUP the two lines are switched off three pole since each device picks up as with L1 L2 E i e as with a multi phase fault Figure 2 6 Multiple fault on a double circuit line next to a...

Page 68: ...tection zone 1107 P Q sign not reversed reversed not reversed P Q operational measured values sign 1111 x 1A 0 0050 9 5000 Ω km 0 1500 Ω km x Line Reactance per length unit 5A 0 0010 1 9000 Ω km 0 0300 Ω km 1111 x 1A 0 0050 15 0000 Ω mi 0 2420 Ω mi x Line Reactance per length unit 5A 0 0010 3 0000 Ω mi 0 0484 Ω mi 1112 c 1A 0 000 100 000 µF km 0 010 µF km c capacit per unit line len µF km 5A 0 000...

Page 69: ...32A SI Time all Cl 0 01 30 00 sec 0 10 sec Seal in Time after ALL clo sures 1134 Line Closure only with ManCl I OR U or ManCl CB OR I or M C I or Man Close I or Man Close Recognition of Line Clo sures with 1135 Reset Trip CMD CurrentOpenPole Current AND CB CurrentOpenPole RESET of Trip Command 1140A I CTsat Thres 1A 0 2 50 0 A 20 0 A CT Saturation Threshold 5A 1 0 250 0 A 100 0 A 1150A SI Time Man...

Page 70: ...08 S1 center ph unknown sym Phase 1 Phase 2 Phase 3 unknown sym S1 center phase 6009 S1 XE XL 0 33 7 00 1 00 S1 Zero seq compensat ing factor XE XL 6010 S1 RE RL 0 33 7 00 1 00 S1 Zero seq compensat ing factor RE RL 6011 S1 K0 0 000 4 000 1 000 S1 Zero seq compensat ing factor K0 6012 S1 angle K0 135 00 135 00 0 00 S1 Zero seq compensat ing angle of K0 6021 S2 Line angle 30 89 85 S2 Line angle 602...

Page 71: ... 0 000 500 000 µF km 0 050 µF km 6043 S3 c 1A 0 000 160 000 µF mi 0 016 µF mi S3 feeder capacitance c in µF mile 5A 0 000 800 000 µF mi 0 080 µF mi 6044 S3 Line length 0 1 1000 0 km 100 0 km S3 Line length in kilome ter 6044 S3 line length 0 1 650 0 Miles 62 1 Miles S3 line length in miles 6048 S3 center ph unknown sym Phase 1 Phase 2 Phase 3 unknown sym S3 center phase 6049 S3 XE XL 0 33 7 00 1 0...

Page 72: ...ut OUT Relay Drop Out 503 Relay PICKUP L1 OUT Relay PICKUP Phase L1 504 Relay PICKUP L2 OUT Relay PICKUP Phase L2 505 Relay PICKUP L3 OUT Relay PICKUP Phase L3 506 Relay PICKUP E OUT Relay PICKUP Earth 507 Relay TRIP L1 OUT Relay TRIP command Phase L1 508 Relay TRIP L2 OUT Relay TRIP command Phase L2 509 Relay TRIP L3 OUT Relay TRIP command Phase L3 510 Relay CLOSE OUT General CLOSE of relay 511 R...

Page 73: ...losure detected 591 1pole open L1 OUT Single pole open detected in L1 592 1pole open L2 OUT Single pole open detected in L2 593 1pole open L3 OUT Single pole open detected in L3 No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 74: ...Protection Data Communication Protection Data Topology For a standard layout of lines with two ends you require one protection data interface for each device The protection data interface is named PI1 see also Figure 2 7 The corresponding protection data interface must be configured as Enabled during con figuration of the functional scope see Section 2 1 1 With 7SD5 it is also possible to connect ...

Page 75: ...dex 2 at PI 2 to the device with index 4 etc until it reaches the device with index 3 at PI 1 The example shows that the indexing of the devices must not necessarily have to cor respond to the sequence of the communication chain Which protection data interface is connected to which protection data interface does not play a role One device with one protection data interface at each terminal of the ...

Page 76: ...A transmission via modem and communication networks can also be realized Please note however that the tripping times of the dif ferential protection devices depend on the transmission quality and that they are pro longed in case of a reduced transmission quality and or an increased transmission time Figure 2 11 shows some examples for communication connections In case of a direct connection the di...

Page 77: ...ice Connector Type Fibre Type Optical Wavelength Perm Path At tenuation Distance Typical FO5 ST Multimode 62 5 125 µm 820 nm 8 dB 1 5 km 0 95 miles FO6 ST Multimode 62 5 125 µm 820 nm 16 dB 3 5 km 2 2 miles FO7 ST Monomode 9 125 µm 1300 nm 7 dB 10 km 6 25 miles FO8 FC Monomode 9 125 µm 1300 nm 18 dB 35 km 22 miles FO17 1 LC Monomode 9 125 µm 1300 nm 13 dB 24 km 14 9 miles FO18 1 LC Monomode 9 125 ...

Page 78: ...is affected You may use this alarm to block the differential protection either via binary output and input or via logical combination by means of the integrated user definable logic CFC If several faulty telegrams or no data telegrams at all are received this is regarded as an Error as soon as a time delay for data disturbance alarm default setting 100 ms can be altered is exceeded A corresponding...

Page 79: ... long as GPS synchronization is intact When the GPS synchronization detects that the permissible time difference is exceeded during operation the message PI 1 PD unsym No 3250 for interface 1 will be issued When a transmission time jump exceeds the maximum permissible transmission delay time this is annunciated If transmission time jumps occur frequently the regular op eration of the differential ...

Page 80: ...y Otherwise the differential protection system is blocked in all linked devices Depending on the parameter settings either the distance protection assumes the entire protection function over all zones or the time overcurrent pro tection becomes effective as emergency function This mode can be switched on or off in the following ways Using the integrated keypad Menu Control Taggings Set Test mode V...

Page 81: ...mmunication route The setting depends on the features of the communication media As a general rule it can be stated that the higher the transmission rate the shorter the tripping time of the differential protection system The devices measure and monitor the transmission times Deviations are corrected as long as they are within the permissible range These permissible ranges are set under addresses ...

Page 82: ...faulty telegram per 100 telegrams is permissible The sum of telegrams in both directions is decisive If frequent transmission time jumps occur the regular operation of the differential pro tection is endangered Under address 4515 PI1 BLOCK UNSYM you can decide whether the differential protection shall be blocked in this case Normal setting is YES default If a ring topology is configured the system...

Page 83: ...NC OFF TEL and GPS PI1 Synchronizationmode 4512 Td ResetRemote 0 00 300 00 sec 0 00 sec Remote signal RESET DELAY for comm fail 4513A PROT1 max ERROR 0 5 20 0 1 0 Prot 1 Maximal permissible error rate 4515A PI1 BLOCK UNSYM YES NO YES Prot 1 Block due to unsym delay time 4601 STATE PROT I 2 ON OFF ON State of protection interface 2 4602 CONNEC 2 OVER F optic direct Com conv 64 kB Com conv 128 kB Co...

Page 84: ...t and receive 3239 PI1 TD alarm OUT Prot Int 1 Transmission delay too high 3240 PI2 TD alarm OUT Prot Int 2 Transmission delay too high 3243 PI1 with VI Prot Int 1 Connected with relay ID 3244 PI2 with VI Prot Int 2 Connected with relay ID 3245 GPS failure SP GPS failure from external 3247 GPS loss OUT GPS local pulse loss 3248 PI 1 GPS sync OUT GPS Prot Int 1 is GPS sychronized 3249 PI 2 GPS sync...

Page 85: ... must be unique within the communication system The ID number identifies the devices in the communication system like a device address since the exchange of information between several differential protection systems thus also for several protective relay can be executed via the same communication system Please make sure that the possible communication links and the existing interfaces are in acco...

Page 86: ...ndicate the actual local device Enter the index for each device according to the consecutive numbering used Each index from 1 to the entire number of devices must be used once but may not be used twice Figure 2 13 Differential protection topology for 4 ends with 4 devices example Make sure that the parameters of the differential protection topology for the differential protection system are conclu...

Page 87: ...AY 1 1 65534 1 Identification number of relay 1 4702 ID OF RELAY 2 1 65534 2 Identification number of relay 2 4703 ID OF RELAY 3 1 65534 3 Identification number of relay 3 4704 ID OF RELAY 4 1 65534 4 Identification number of relay 4 4705 ID OF RELAY 5 1 65534 5 Identification number of relay 5 4706 ID OF RELAY 6 1 65534 6 Identification number of relay 6 4710 LOCAL RELAY relay 1 relay 2 relay 3 r...

Page 88: ...Login state 3492 Rel2 Login OUT Relay 2 in Login state 3493 Rel3 Login OUT Relay 3 in Login state 3494 Rel4 Login OUT Relay 4 in Login state 3495 Rel5 Login OUT Relay 5 in Login state 3496 Rel6 Login OUT Relay 6 in Login state No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 89: ...s current flows into one side of the considered zone and leaves it again on the other side A difference in current is a clear indication of a fault within this line section If the actual current transformation ratios are the same the secondary windings of the current transformers CT1 and CT2 at the line ends can be connected to form a closed electric circuit with a secondary current I a measuring ...

Page 90: ...tween protection devices is called the protection data interface As a result the currents can be added up a processed in each device Figure 2 16 Differential protection for a line with two ends In case of more than two ends a communication chain is built up by which each device is informed about the total sum of the currents flowing into the protected object Figure 2 17 shows an example for three ...

Page 91: ...d pre processes the associated currents of the current transformers with its own random processor pulse If the currents of two or more line ends are to be compared it is necessary however to process all currents with the same time base All devices which belong together exchange their time with each telegram The device with index 1 functions as a timing master thus determining the time base The oth...

Page 92: ...al jitters can also cause deviations of the measured quantities As a result of all these influences the total sum of all currents processed in the devices in healthy operation is not exactly zero Therefore the differential protection is restrained against these in fluences Charging Current Compensation Charging current compensation is an ancillary function of the differential protection It allows ...

Page 93: ...ed for restraint Figure 2 19 Approximation of the current transformer errors FurtherInfluences Further measuring errors which may arise in the device itself by hardware tolerances calculation tolerances deviations in time or due to the quality of the measured quan tities such as harmonics and deviations in frequency are also estimated by the device and increase the local self restraining quantity ...

Page 94: ...ximal sensitivity of the differential protection consists of an optical fibre connection InrushRestraint If the protected area includes a power transformer a high inrush current can be ex pected when connecting the transformer This inrush current flows into the protected zone but does not leave it again The inrush current can amount to a multiple of the nominal current and is character ised by a c...

Page 95: ...tection system In the ideal case it is equal to the fault current value In a healthy system the differential current value is low and in a first ap proximation equal to the charging current With charging current compensation it is very low The restraining current counteracts the differential current It is the total of the maximum measured errors at the ends of the protected object and is calculate...

Page 96: ...eriod 1 4 The calculated charge Q is a scalar value which is faster to determine and to transmit than a complex phasor The charges of all ends of the protected object are added in the same way as done with the current phasors of the differential protection Thus the total of the charges is available at all ends of the protected zone Right after a fault occurrence within the protected zone a charge ...

Page 97: ... is as aforesaid a function suited to com plete the differential protection ensuring a fast tripping for high current short circuits Normally the charge comparison is set higher than the nominal current For charge comparison it is irrelevant whether the charging current compensation is activated or not Blocking Inter blocking The distance protection provided that it is available and configured aut...

Page 98: ... protection function itself this pickup signal is of no concern since the tripping conditions are available at the same time This signal how ever is necessary for the initiation of internal or external supplementary functions e g fault recording automatic reclosure Tripping Logic of the Differential Protection The tripping logic of the differential protection combines all decisions of the differen...

Page 99: ...ion of measured values becomes impossible The entire differential protection of all ends is then blocked if the distance protection is available and configured it repre sents the main protection function Pickup Value of the DifferentialCurrent The current sensitivity is set with address 1210 I DIFF It is determined by the entire current flowing into a protected zone in case of a fault This is the ...

Page 100: ...o that the current set by it is 2 to 3 times or IcSTAB IcN I DIFF of the determined charging current If setting is performed from a personal computer using DIGSI the parameters can be set either as primary or as secondary quantities If secondary quantities are set all currents must be converted to the secondary side of the current transformers Calculation Example 110 kV single conductor oil filled...

Page 101: ...arge resonant earthed systems the time delay should be increased By setting the address to the single phase tripping is totally suppressed Please note that the parameter T3I0 1PHAS is also used by the distance protection function The settings that you make here also affect the distance protection see Section 2 5 1 4 under margin heading Earth Fault Detection Pickup Value of Charge Compari son Stag...

Page 102: ...rtion to avoid spurious tripping of the protec tion Address 1224 IcSTAB IcN allows you to determine the charging current re straint factor Since in the latter descriptions the charging current was already consid ered using setting 1210 I DIFF 1 IcN the additional restraint value of the device is calculated as follows IcSTAB IcN 1 I DIFF divided by the number of de vices This value is added to the ...

Page 103: ... 10 20 00 A 0 30 A I DIFF Pickup value 5A 0 50 100 00 A 1 50 A 1213 I DIF SWITCH ON 1A 0 10 20 00 A 0 30 A I DIFF Value under switch on condition 5A 0 50 100 00 A 1 50 A 1217A T DELAY I DIFF 0 00 60 00 sec 0 00 sec I DIFF Trip time delay 1218 T3I0 1PHAS 0 00 0 50 sec 0 04 sec Delay 1ph faults comp isol star point 1221 Ic comp OFF ON OFF Charging current compen sation 1224 IcSTAB IcN 2 0 4 0 2 5 Ic...

Page 104: ...blocked 3149 Diff OFF OUT Diff Diff protection is switched off 3176 Diff Flt 1p L1 OUT Diff Fault detection L1 only 3177 Diff Flt L1E OUT Diff Fault detection L1E 3178 Diff Flt 1p L2 OUT Diff Fault detection L2 only 3179 Diff Flt L2E OUT Diff Fault detection L2E 3180 Diff Flt L12 OUT Diff Fault detection L12 3181 Diff Flt L12E OUT Diff Fault detection L12E 3182 Diff Flt 1p L3 OUT Diff Fault detect...

Page 105: ... C53000 G1176 C169 1 3528 Diffblk sen PI1 OUT Differential blocking sending via PI1 3529 Diffblk sen PI2 OUT Differential blocking sending via PI2 No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 106: ... breakers are designed for single pole tripping 2 4 1 Functional Description Transmission Circuit The transmission signal can originate from two different sources Figure 2 25 If the parameter I TRIP SEND is set to YES each tripping command of the differential pro tection is routed immediately to the transmission function I Trip SendL1 to L3 in tertrip and transmitted via the protection data interf...

Page 107: ...device see also Section 2 23 1 ensures if necessary that the conditions for single pole tripping are fulfilled e g single pole tripping permissible auto reclosure function ready Figure 2 26 Logic diagram of the intertrip receiving circuit Ancillary Functions Since the signals for remote tripping can be set to cause only an alarm any other desired signals can be transmitted in this way as well Afte...

Page 108: ...ignal after it has been effec tively injected from an external source The reaction of a device when receiving an intertrip remote tripping signal is set in address 1302 I TRIP RECEIVE If it is supposed to cause tripping set the value Trip If the received signal however is supposed to cause an alarm only Alarm only must be set even if this annunciation is to be further processed externally The sett...

Page 109: ...11 ITrp sen PI1 L1 OUT I Trip Sending at Prot Interface 1 L1 3512 ITrp sen PI1 L2 OUT I Trip Sending at Prot Interface 1 L2 3513 ITrp sen PI1 L3 OUT I Trip Sending at Prot Interface 1 L3 3514 ITrp sen PI2 L1 OUT I Trip Sending at Prot Interface 2 L1 3515 ITrp sen PI2 L2 OUT I Trip Sending at Prot Interface 2 L2 3516 ITrp sen PI2 L3 OUT I Trip Sending at Prot Interface 2 L3 3517 ITrp Gen TRIP OUT I...

Page 110: ...ther the fault at hand is an earth fault or not The 7SD5 has a stabilized earth current measurement a zero sequence current negative sequence current comparison as well as a displace ment voltage measurement Furthermore special measures are taken to avoid a pickup for single earth faults in an isolated or resonant earthed system Earth Current 3I0 For earth current measurement the fundamental sum o...

Page 111: ... reset threshold is approximately 95 of the pickup threshold In earthed systems 3U0 Threshold it can be used as an additional cri terion for earth faults For earthed systems the U0 criterion may be disabled by ap plying the setting Logical Combina tion for Earthed Systems The current and voltage criteria supplement each other as the displacement voltage increases when the zero sequence to positive...

Page 112: ...en condition Logical Combina tion for Non earthed Systems In non earthed systems isolated system starpoint or resonant earthed by means of a Peterson coil the measured displacement voltage is not used for fault detection Fur thermore in these systems a simple earth fault is assumed initially in case of a single phase fault and the fault detection is suppressed in order to avoid an erroneous pickup...

Page 113: ...onal final stages Determination of the faulted loop s Enabling of impedance calculation and direction determination Enabling of tripping command Initiation of supplementary functions Indication output of the faulted conductor s The type of fault detection selected with address 117 Dis PICKUP Z quadrilat works implicitly i e the above mentioned operations are executed automatically as soon as a fau...

Page 114: ...se phase loops both relevant phase currents have to exceed this value Above this current the current pickup is voltage dependent with the slope being determined by the settings U I and U I For short circuits with large currents the overcurrent pickup Iph is su perimposed The bold dots in Figure 2 31 mark the settings which determine the ge ometry of the current voltage characteristic The phases th...

Page 115: ...Loops and phase indications for single phase overcurrent pickup U I Phase to earth voltages program 1 only active for earthed power systems When evaluating phase phase loops the sensitivity towards phase phase faults is particularly high In extensive compensated networks this selection is advantageous because it excludes pickup as a result of single earth faults on principle With two and three pha...

Page 116: ...he pickup signals of the loops are converted into phase signals so that the faulted phase s can be indicated If an earth fault has been detected it will also be alarmed Voltage and Angle dependent Current Pickup U I ϕ Phase angle controlled U I pickup can be applied when the U I characteristic criteria can no longer distinguish reliably between load and short circuit conditions This is the case wi...

Page 117: ...t voltage characteristic shown in Figure 2 32 Initially it is shaped like the U I pickup character istic Figure 2 31 For angles in the range of large phase difference i e in the short circuit angle area above the threshold angle ϕ the characteristic between U I and U Iϕ also takes effect it is cut off by the overcurrent stage Iϕ The bold dots in Figure 2 32 mark the settings which determine the ge...

Page 118: ...m Iph A jump detector synchronizes all the calculations with the fault inception If a further fault occurs during the evaluation the new measured values are immediately used for the calculation The fault evaluation is therefore always done with the measured values of the current fault condition Phase Phase Loops To calculate the phase phase loop for instance during a two phase short circuit L1 L2 ...

Page 119: ...e phase measuring system is shown in Figure 2 34 Figure 2 34 Logic for a phase phase measuring unit Phase Earth Loops For the calculation of the phase earth loop for example during a L3 E Figure 2 35 it must be noted that the impedance of the earth return path does not correspond to the impedance of the phase In the loop equation IL3 ZL IE ZE UL3 E ZE is replaced by ZE ZL ZL yielding From this the...

Page 120: ...dance of the faulted loop because the unfaulted loop only carries a part of the fault current and always has a larger voltage than the faulted loop For the selec tivity of the zones they are usually of no consequence Apart from the zone selectivity the phase selectivity is also important to achieve correct identification of the faulted phases required to alarm the faulted phase and es pecially to ...

Page 121: ...ck lagging Ø All the affected loops can also be evaluated Parameter 2Ph E faults All loops or only the phase phase loop Parameter 2Ph E faults Ø Ø loops only or only the phase earth loops Parameter 2Ph E faults Ø E loops only A prerequisite for these restrictions is that the relevant loops indicate fault locations which are close together and within the reach of the first zone Z1 The loops are con...

Page 122: ... can appear that may evoke the earth current pickup In case of an overcurrent pickup there may also be a phase current pickup 7SD5 provides special measures against such undesirable pickups With the occurrence of a double earth fault in isolated or resonant earthed systems it is sufficient to switch off one of the faults The second fault may remain in the system as a simple earth fault Which of th...

Page 123: ...ne is taken into consideration by the line equation and thereby allows for compensation of the coupling influence The earth current of the parallel line must be connected to the device for this purpose The loop equation is then modified as shown below refer also to Figure 2 35 Cyclic L1 before L3 before L2 before L1 L1 L3 CYCLIC All loops are measured All loops Loop pickup Evaluated loop s Setting...

Page 124: ...n may not be carried out as this would cause severe overreach The relay located in position II in Figure 2 38 may therefore not be compensated Earth current balance is therefore additionally provided in the device which carries out a cross comparison of the earth currents in the two lines The compensation is only applied to the line end where the earth current of the parallel line is not substanti...

Page 125: ...aults please make sure that in conjunction with the configured MHO characteristic the instantaneous tripping function is always enabled 2 5 1 4 Setting Notes At address 1501 FCT Distance the distance protection function can be switched ON or OFF Minimum Current The minimum current for fault detection Minimum Iph address 1502 in case of impedance pickup is set somewhat approx 10 below the minimum s...

Page 126: ...8 T3I0 1PHAS Set parameter T3I0 1PHAS to if the earth current threshold can also be exceeded during steady state conditions Then even with high earth current no single phase pickup is possible any more Double earth faults are however correctly detected and measured according to the preference program also see Section 2 5 1 at margin heading Double Earth Faults in Non earthed Systems Please note th...

Page 127: ...ially in conjunction with large earth fault resistance In certain cases fault resistance phase phase larger than phase earth the setting Block lagging Ø blocking of the lagging phase may be more favourable The evaluation of all affected loops with the setting All loops allows a maximum degree of redundancy It is also possible to evaluate as loop Ø Ø loops only This ensures the most accuracy for tw...

Page 128: ...ation failure With address 1533 Z1 blkd by diff set to NO zone Z1 operates independently of the differential protection Zone Z1 can also be blocked by the binary input 3610 BLOCK Z1 Trip This binary input allows for instance to specify further blocking conditions relating to the interaction with the differential protection using CFC The effect of the binary input does not depend on the status of t...

Page 129: ...configuration of the protection functions Section 2 1 1 3 you have selected as pickup type Dis PICKUP Z quadrilat address 117 the mentioned settings are not relevant and cannot be accessed Available pickup modes are described in Section 2 5 1 in detail If the device has several alternative pickup modes one option has been selected when configuring in address 117 Below parameters are given and disc...

Page 130: ...crucial for the setting of over current pick up Pickup due to overload must be ruled out Therefore the pickup value Iph address 1910 must be set above the maximum over load current that is expected approx 1 2 times In this case it must be ensured that the minimum fault current is above this value If this is not the case U I pickup is required Calculation Example Maximum operational current incl ov...

Page 131: ...ge at the maximum expected load current If in doubt check the pickup conditions in accordance with the U I characteristic Angular Dependence If a distinction between short circuit and load conditions is not always possible using the U I characteristic which is independent of the phase angle the angular dependent section d e can additionally be used This is required for long lines and section of li...

Page 132: ...e power see above The upper threshold angle ϕ address 1921 is not critical 100 to 120 should be sufficient in all cases Angular dependence i e increasing the sensitivity for a large short circuit angle with section d and e in the characteristic can be limited to the forward direction line direc tion using address 1919 EFFECT ϕ In this case EFFECT ϕ is set to Forward Oth erwise EFFECT ϕ forward rev...

Page 133: ... blocked by diff active 1540 Distance Angle 30 90 85 Angle of inclination dis tance charact 1541 R load Ø E 1A 0 100 600 000 Ω Ω R load minimum Load Im pedance ph e 5A 0 020 120 000 Ω Ω 1542 ϕ load Ø E 20 60 45 PHI load maximum Load Angle ph e 1543 R load Ø Ø 1A 0 100 600 000 Ω Ω R load minimum Load Im pedance ph ph 5A 0 020 120 000 Ω Ω 1544 ϕ load Ø Ø 20 60 45 PHI load maximum Load Angle ph ph 16...

Page 134: ...Iph 1A 0 10 4 00 A 0 20 A Iph Pickup minimum cur rent 5A 0 50 20 00 A 1 00 A 1912 Uph e I 20 70 V 48 V Undervoltage ph e at Iph 1913 Uph e I 20 70 V 48 V Undervoltage ph e at Iph 1914 Uph ph I 40 130 V 80 V Undervoltage ph ph at Iph 1915 Uph ph I 40 130 V 80 V Undervoltage ph ph at Iph 1916 Iphi 1A 0 10 8 00 A 0 50 A Iphi Pickup minimum current at phi 5A 0 50 40 00 A 2 50 A 1917 Uph e Iphi 20 70 V...

Page 135: ...ickup Phase L2 only 3684 Dis Pickup L2E OUT Distance Pickup L2E 3685 Dis Pickup L12 OUT Distance Pickup L12 3686 Dis Pickup L12E OUT Distance Pickup L12E 3687 Dis Pickup 1pL3 OUT Distance Pickup Phase L3 only 3688 Dis Pickup L3E OUT Distance Pickup L3E 3689 Dis Pickup L31 OUT Distance Pickup L31 3690 Dis Pickup L31E OUT Distance Pickup L31E 3691 Dis Pickup L23 OUT Distance Pickup L23 3692 Dis Pick...

Page 136: ...2 3751 Dis Z1B L23 OUT Distance Pickup Z1B Loop L23 3752 Dis Z1B L31 OUT Distance Pickup Z1B Loop L31 3755 Dis Pickup Z2 OUT Distance Pickup Z2 3758 Dis Pickup Z3 OUT Distance Pickup Z3 3759 Dis Pickup Z4 OUT Distance Pickup Z4 3760 Dis Pickup Z5 OUT Distance Pickup Z5 3771 Dis Time Out T1 OUT DistanceTime Out T1 3774 Dis Time Out T2 OUT DistanceTime Out T2 3777 Dis Time Out T3 OUT DistanceTime Ou...

Page 137: ...R X coordinate system the directional characteristic however limits the tripping range to the desired quadrants refer to Determination of Direction below The R reach may be set separately for the phase phase faults and the phase earth faults to achieve a larger fault resistance coverage for earth faults if this is desired For the first zone Z1 an additional settable tilt α exists which may be used...

Page 138: ...d by transients The voltage memorized prior to fault inception is therefore used in this situation If the steady state short circuit voltage during a close in fault is even too small for direction determination an unfaulted voltage is used This voltage is in theory quadrilateral to the actual short circuit voltage for both phase earth loops as well as for phase phase loops refer to Figure 2 42 Thi...

Page 139: ...gure 2 43 shows the theoretical steady state characteristic In practice the position of the directional characteristic when using memorized voltages is dependent on both the source impedance as well as the load transferred across the line prior to fault in ception Accordingly the directional characteristic includes a safety margin with respect to the limits of the first quadrant in the R X diagram...

Page 140: ...rature or memorized voltage as well as taking the source impedance into account no load transfer As these voltages are equal to the corresponding generator voltage E and they do not change after fault inception the directional characteristic is shifted in the impedance diagram by the source impedance ZS1 E1 I1 For the fault location F1 Figure 2 44a the short circuit location is in the forward dire...

Page 141: ...ed up see Figure 2 45 Figure 2 45 Voltage characteristic while a fault occurs after a series capacitor a without pickup of the protective spark gap b with pickup of the protective spark gap The distance protection function would thus detect a wrong fault direction The use of memorized voltages however ensures that the direction is correctly detected see Figure 2 46a Since the voltage prior to the ...

Page 142: ...verted to phase segregated information Using the impedance pickup the calculated loop impedances are also assigned to the zone characteristics set for the distance protection but without a query of an explicit fault detection scheme The pickup range of the distance protection is determined from the thresholds of the largest set polygon taking into consideration the respective direction Here the lo...

Page 143: ...nded to initially create a grading coordination chart for the entire galvan ically interconnected system This diagram should reflect the line lengths with their primary reactances X in Ω km For the reach of the distance zones the reactances X are the deciding quantity The first zone Z1 is usually set to cover 85 of the protected line without any trip time delay i e T1 0 00 s The protection clears ...

Page 144: ... of 85 of the line length should be applied which results in primary X1prim 0 85 XL 0 85 14 70 Ω 12 49 Ω or secondary Resistance Tolerance The resistance setting R allows a reserve for fault resistance which appears as an ad ditional resistance at the fault location and is added to the impedance of the line con ductors It comprises for example the resistance in arcs the earth distribution resis ta...

Page 145: ...east favourable condition was assumed whereby the earth current does not return via the measuring point If all the earth current or a portion of the earth current flows via the measuring point the measured resistance decreases When there is an infeed from the remote end the measured resistance may be increased Independent Zones Z1 up to Z5 By means of the parameter MODE Forward or Reverse or Non D...

Page 146: ...pole tripping usually applies to single phase faults in Z1 if the remaining conditions for single pole tripping are satis fied this may also be selected for the second zone with address 1617 Trip 1pole Z2 Single pole tripping in zone 2 is only possible if this address is set to YES The default setting is NO Note For instantaneous tripping undelayed in the forward direction the first zone Z1 should...

Page 147: ...tion with teleprotection comparison schemes the dependence on the fault detection must be considered refer to margin heading Distance Protection Prerequisites in Section 2 7 14 If the distance protection is used in conjunction with an automatic recloser it can be determined in address 1657 1st AR Z1B which distance zones are released prior to a rapid automatic reclosure Usually the overreaching zo...

Page 148: ...2 1phase delay for single phase faults 1616 T2 multi phase 0 00 30 00 sec 0 30 sec T2multi ph delay for multi phase faults 1617A Trip 1pole Z2 NO YES NO Single pole trip for faults in Z2 1621 Op mode Z3 Forward Reverse Non Directional Inactive Reverse Operating mode Z3 1622 R Z3 Ø Ø 1A 0 050 600 000 Ω 5 000 Ω R Z3 Resistance for ph ph faults 5A 0 010 120 000 Ω 1 000 Ω 1623 X Z3 1A 0 050 600 000 Ω ...

Page 149: ...c T5 delay 1646 X Z5 1A 0 050 600 000 Ω 4 000 Ω X Z5 Reactance for Reverse direction 5A 0 010 120 000 Ω 0 800 Ω 1651 Op mode Z1B Forward Reverse Non Directional Inactive Forward Operating mode Z1B overrreach zone 1652 R Z1B Ø Ø 1A 0 050 600 000 Ω 1 500 Ω R Z1B Resistance for ph ph faults 5A 0 010 120 000 Ω 0 300 Ω 1653 X Z1B 1A 0 050 600 000 Ω 3 000 Ω X Z1B Reactance 5A 0 010 120 000 Ω 0 600 Ω 165...

Page 150: ... each fault impedance loop The basic shape of a MHO characteristic for one zone is shown in Figure 2 48 as an example The MHO characteristic is defined by the line of its diameter which intersects the origin of the coordinate system and the magnitude of the diameter which corresponds to the impedance Zr which determines the reach and by the angle of inclination The angle of inclination is set in a...

Page 151: ...determined by the reach setting Zr remains unchanged Imme diately after fault inception the short circuit voltage is disturbed by transients the voltage memorized prior to fault inception is therefore used for polarization This causes a displacement of the lower zenith by an impedance corresponding to the memorized voltage refer to Figure 2 49 When the memorized short circuit voltage is too small ...

Page 152: ...ircuit location is in the forward direction and the source impedance is in the reverse direction All fault locations right up to the device mounting location current transformers are clearly inside the MHO character istic Figure 2 50b If the current is reversed the zenith of the circle diameter changes abruptly Figure 2 50c A reversed current I2 now flows via the measuring location current transfo...

Page 153: ... general the factor is set to 15 The memory polarization is only per formed if the RMS value of the corresponding memorized voltage for Ph E loops is greater than a 40 of the nominal voltage UN address 204 and greater than a 70 of UN for Ph Ph loops If there is no prefault voltage due to a sequential fault or energization onto a fault the memorized voltage can only be used for a limited time For s...

Page 154: ...ver reverses its direction until the protective spark gap has picked up see Figure 2 51 Figure 2 51 Voltage characteristic for a short circuit after a series capacitor a without pickup of the protective spark gap b with pickup of the protective spark gap The distance protection function would thus detect a wrong fault direction However even in this case pickup of the correct directional MHO charac...

Page 155: ...ic is done for each zone by determining the angles between two differential phasors Z1 and Z2 Figure 2 53 These phasors result from the difference between the two zeniths of the circle diameter and the fault impedance The zenith Zr corresponds to the set value for the zone under consideration Zr and ϕMHO as shown in Figure 2 48 the zenith kZV corresponds to the polarizing magnitude Therefore the d...

Page 156: ...fidently measured inside the MHO characteristic of a distance zone the affected loop is designated as picked up The loop information is also converted to phase segregated information Further conditions for the pickup of a zone is that the zone may not be blocked by the power swing blocking Furthermore the distance protection may not be blocked or switched off completely Figure 2 54 shows these con...

Page 157: ...dinationChart It is recommended to initially create a grading coordination chart for the entire galvan ically interconnected system This diagram should reflect the line lengths with their primary impedances Z in Ω km For the reach of the distance zones the impedances Z are the deciding quantities The first zone Z1 is usually set to cover 85 of the protected line without any trip time delay i e T1 ...

Page 158: ...ing data s length 35 km R1 s 0 19 Ω km X1 s 0 42 Ω km R0 s 0 53 Ω km X0 s 1 19 Ω km Current Transformer 600 A 5 A Voltage Transformer 110 kV 0 1 kV The following line data is calculated RL 0 19 Ω km 35 km 6 65 Ω XL 0 42 Ω km 35 km 14 70 Ω For the first zone a setting of 85 of the line length should be applied which results in primary X1prim 0 85 XL 0 85 14 70 Ω 12 49 Ω or secondary Independent Zon...

Page 159: ...ole tripping are satis fied this may also be selected for the second zone with address 1617 Trip 1pole Z2 Single pole tripping in zone 2 is only possible if this address is set to Yes The pre setting is No Note For instantaneous tripping undelayed in the forward direction the first zone Z1 should always be used as only the Z1 and Z1B are guaranteed to trip with the shortest operating time of the d...

Page 160: ...n with teleprotection comparison schemes the dependence on the fault detection must be considered refer to margin heading Distance Protection Prerequisites in Section 2 7 14 If the distance protection is used in conjunction with an automatic recloser it may be determined in address 1657 1st AR Z1B which distance zones are released prior to a rapid automatic reclosure Usually the overreaching zone ...

Page 161: ... 0 00 30 00 sec 0 00 sec T1B multi ph delay for multi ph faults 1657 1st AR Z1B NO YES YES Z1B enabled before 1st AR int or ext 1701 Op mode Z1 Forward Reverse Inactive Forward Operating mode Z1 1702 ZR Z1 1A 0 050 200 000 Ω 2 500 Ω ZR Z1 Impedance Reach 5A 0 010 40 000 Ω 0 500 Ω 1711 Op mode Z2 Forward Reverse Inactive Forward Operating mode Z2 1712 ZR Z2 1A 0 050 200 000 Ω 5 000 Ω ZR Z2 Impedanc...

Page 162: ...to run together even if the type of fault or the selected measuring loop changes e g because an intermediate infeed is switched off This is also the pre ferred setting in the case of other distance protection relays in the power system working with this start timing Where grading of the delay times is especially important for instance if the fault location shifts from zone Z3 to zone Z2 the settin...

Page 163: ...lly always set without delay can be bypassed The grading times are started either via zone pickup or general pickup of the distance protection function The undelayed release results from the line energization logic which may be externally initiated via the circuit breaker close signal derived from the circuit breaker control switch or from an internal line en ergization detection Zones Z4 and Z5 m...

Page 164: ...C53000 G1176 C169 1 Figure 2 56 Tripping logic for the 2nd zone Figure 2 57 Tripping logic for the 3rd zone Figure 2 58 Tripping logic for the 4th and 5th zone shown is zone Z4 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 165: ... reclosure device In addi tion it is possible to use the zone Z1B as a rapid autoclosure stage that only operates for single pole faults for example if only single pole automatic reclose cycles are ex ecuted It is possible for the 7SD5 to trip single pole during two phase faults without earth con nection in the overreaching zone when single pole automatic reclosure is used As the device has an int...

Page 166: ...2 Functions 166 7SD5 Manual C53000 G1176 C169 1 Figure 2 59 Tripping logic for the controlled zone Z1B w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 167: ...if single pole tripping is possible this is also alarmed as shown in the zone logic diagrams Figures 2 55 up to 2 59 The actual generation of the commands for the tripping output relay is executed within the trip ping logic of the entire device 2 5 4 2 Setting Notes The trip delay times of the distance stages and intervention options which are also pro cessed in the tripping logic of the distance ...

Page 168: ...urrents apparently imply small impedances which again could lead to tripping by the distance protection In expansive networks with large transferred power even the stability of the energy transfer could be endangered by such power swings Figure 2 60 Power swing Note The power swing supplement works together with the impedance pickup and is only available in this combination System power swings are...

Page 169: ...tion range APOL 2 It is also possible that a power swing vector will enter the area of the power swing range and leave it again without coming into contact with the fault detection range 3 If the vector enters the power swing polygon and passes through it leaving on the opposite side then the sections of the network seen from the relay location have lost synchronism 4 the power transfer is unstabl...

Page 170: ...he differentiation between faults and power swing conditions This is shown in Figure 2 63 During the power swing the measured impedance from one sample to the next has a defined change in R and X referred to as dR k and dX k Important is also the fact that from one sample to the next the difference is small i e dR k dR k 1 threshold During a fault entry there is a rapid change that will not cause ...

Page 171: ...asured X value is less than this value Figure 2 64 Steady state instability range Trajectory Symmetry In addition to these measures a comparison of the three phases is done to ensure that they are symmetrical During a power swing condition in the single pole open condi tion only two of the three phases will have an impedance trajectory In this case only these 2 remaining phase trajectories are che...

Page 172: ... symmetry The trajectory of each phase is evaluated If no fault is present these 3 trajectories must be symmetrical During single pole open conditions the remaining 2 tra jectories must be symmetrical Trajectory stability When the impedance trajectory enters the PPOL during a swing condition the system must be in the area of steady state instability In Figure 2 64 this cor responds to the lower ha...

Page 173: ...tes e g switching opera tions are compensated which occur during a power swing and cause a jump in the measured quantities It is possible with No 4160 Pow Swing BLK to block the power swing detection via a binary input Power Swing Tripping If tripping in the event of an unstable power swing out of step condition is desired the parameter PowerSwing trip YES is set If the criteria for power swing de...

Page 174: ...g blocking to avoid premature tripping by the distance protection The tripping delay after power swing blocking can be set in address 2007 Trip DELAY P S 2 6 3 Settings 2 6 4 Information List Addr Parameter Setting Options Default Setting Comments 2002 P S Op mode All zones block Z1 Z1B block Z2 to Z5 block Z1 Z1B Z2 block All zones block Power Swing Operating mode 2006 PowerSwing trip NO YES NO P...

Page 175: ...p command 7SD5 allows PUTT Pickup Permissive Underreach Transfer Trip with Zone Acceleration Z1B PUTT Direct Underreach Transfer Trip In overreach schemes the protection works from the start with a fast overreaching zone This zone however can only cause a trip if the opposite end also detects a fault in the overreaching zone A release unblock signal or a block signal can be transmit ted The follow...

Page 176: ...rections During disturbances in the transmission path the teleprotection supplement may be blocked without affecting the normal time graded distance protection The measuring reach control enable zone Z1B can be transmitted from the internal automatic reclose function or via the binary input Enable ARzones from an external reclo sure device With conventional signal transmission schemes the disturba...

Page 177: ...he overreach zone Z1B is without consequence for the teleprotection scheme in this operating mode It may however be controlled by the automatic reclosing function see also section 2 10 1 Figure 2 67 Operation scheme of the permissive underreach transfer trip with pickup Sequence The permissive transfer trip should only send for faults in the Forward direction Ac cordingly the first zone Z1 of the ...

Page 178: ... that the distance protection does not pick up the circuit breaker can still be tripped This Weak infeed tripping is referred to in Section 2 10 1 Figure 2 68 Logic diagram of the permissive underreach transfer trip PUTT with pickup one line end w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 179: ...ssible differences in the pickup time at the two line ends The distance protection is set such that the first zone reaches up to approximately 85 of the line length the overreaching zone however is set to reach beyond the opposite substation approximately 120 of the line length On three terminal lines Z1 is also set to approximately 85 of the shorter line section but at least beyond the tee off po...

Page 180: ...o Z5 On two terminal lines the signal transmission may be phase segregated Send and receive circuits in this case are built up for each phase On three terminal lines the transmit signal is sent to both opposite line ends The receive signals are then com bined with an OR logic function With the parameter Type of Line address 2102 the device is informed as to whether it has one or two opposite line ...

Page 181: ...e Z1B is not required here It may however be activated by internal automatic reclosure or external criteria via the binary input Enable ARzones The advantage compared to the permissive underreach transfer trip with zone accel eration lies in the fact that both line ends are tripped without the necessity for any further measures even if one line end has no infeed There is however no further su perv...

Page 182: ...ide Z1B in the forward direction at both line ends The distance protection is set such that the overreaching zone Z1B reaches beyond the opposite station approximately 120 of line length On three ter minal lines Z1B must be set to reliably reach beyond the longer line section even if there is an additional infeed via the tee point The first zone is set in accordance with the usual grading scheme i...

Page 183: ...transmission path the overreaching zone Z1B may be activated by an automatic reclosure internal or external via the binary input Enable ARzones The occurrence of erroneous signals resulting from transients during clearance of ex ternal faults or from direction reversal resulting during the clearance of faults on par allel lines is neutralized by the Transient Blocking On feeders with single sided ...

Page 184: ...2 Functions 184 7SD5 Manual C53000 G1176 C169 1 Figure 2 73 Logic diagram of the permissive overreach transfer trip POTT scheme one line end w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 185: ... effect if the protec tion has already issued a trip command This ensures release of the opposite line end even when the short circuit has been switched off rapidly by the independent zone Z1 Sequence Figure 2 75 shows the logic diagram of the directional comparison scheme for one line end On two terminal lines the signal transmission may be phase segregated Send and receive circuits in this case ...

Page 186: ...m the opposite line end in the case of three terminal lines from at least one of the opposite line ends without the device having detected a fault The circuit breaker can also be tripped at the line end with no or only weak infeed This Weak infeed tripping is referred to in Section 2 10 1 Figure 2 75 Logic diagram of the directional comparison scheme one line end w w w E l e c t r i c a l P a r t ...

Page 187: ...ault inside the overreaching zone Z1B it initiates the transmission of the unblock frequency fU During the quiescent state or during a fault outside Z1B or in the reverse direction the monitoring frequency f0 is transmitted If the release frequency is received from the opposite end a trip signal is forwarded to the trip logic Accordingly it is a prerequisite for fast tripping that the fault is rec...

Page 188: ...e device is informed as to whether it has one or two opposite line ends An unblock logic is inserted before the receive logic which in essence corresponds to that of the permissive overreach transfer scheme see Figure 2 78 If an interference free unblock signal is received a receive signal e g Dis T UB ub 1 appears and the blocking signal e g Dis T UB bl 1 disappears The internal signal Un block 1...

Page 189: ...resulting from transients during clearance of ex ternal faults or from direction reversal resulting during the clearance of faults on par allel lines is neutralized by the Transient Blocking On feeders with single sided infeed the line end with no infeed cannot generate a release signal as no fault detection occurs there To achieve tripping by the permis sive overreach transfer scheme even in this...

Page 190: ...ircuit breaker can also be tripped at the line end with no or only weak infeed This Weak infeed tripping is referred to in Section 2 10 1 Figure 2 77 Logic diagram of the unblocking scheme one line end w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 191: ...2 7 Teleprotection for Distance Protection optional 191 7SD5 Manual C53000 G1176 C169 1 Figure 2 78 Unblock logic w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 192: ...s when the signal must be transmitted across the protected line by means of power line carrier PLC and the attenuation of the transmitted signal at the fault location may be so severe that reception at the other line cannot necessarily be guaranteed The scheme functionality is shown in Figure 2 79 Faults inside the overreaching zone Z1B which is set to approximately 120 of the line length will ini...

Page 193: ...wo terminal lines the signal transmission may be phase segregated Send and receive circuits in this case are built up for each phase On three terminal lines the transmit signals are sent to both opposite line ends The receive signals are then com bined with a logical OR gate as no blocking signal must be received from any line end during an internal fault With the setting parameter Type of Line ad...

Page 194: ...2 Functions 194 7SD5 Manual C53000 G1176 C169 1 Figure 2 80 Logic diagram of the blocking scheme one line end w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 195: ... measures as the non feeding end cannot gen erate a blocking signal 2 7 10 Pilot Wire Comparison In the pilot wire comparison the overreaching zone Z1B functions as instantaneous zone at both ends of the protected line Zone Z1B is set to reach beyond the next sta tion The pilot wire comparison avoids non selective tripping The information exchange between both line ends is carried out via a closed...

Page 196: ... an unwanted release This must also be taken into consideration for the delay of T1B The quiescent state loop ensures a steady check of the pilot wire connections against interruptions Since the loop is interrupted during each fault the signal for pilot wire failure is delayed by 10 s The pilot wire comparison supplement is then blocked It does not need to be blocked from external as the pilot wir...

Page 197: ...t In the event of an earth fault the induced longitudinal voltage must neither exceed 60 of the isolation voltage of the pilot wires nor 60 of the isolation of the device The pilot wire comparison is therefore only suited for short lines 2 7 11 Reverse Interlocking If the distance protection function of the 7SD5 is used as backup protection in single end fed transformer feeders the reverse interlo...

Page 198: ...2 84 via the receive input 4006 DisTel Rec Ch1 of the distance protection If no signal is received this zone guarantees fast tripping of the busbar for faults on the busbar such as for example in F1 failure of the line protection during a fault such as for example in F2 The reverse interlocking of the distance protection is performed by specific release or blocking of the overreach zone Z1B It can...

Page 199: ...Figure 2 85 shows the principle of the transient blocking for a directional comparison and for a permissive scheme If following fault detection a non directional fault or a fault in the reverse direction is determined within the waiting time TrBlk Wait Time address 2109 the transmit circuit and the release of the overreaching zone Z1B are prevented This blocking is maintained for the duration of t...

Page 200: ...d for the earth fault protection If there is no fault detection the echo function causes the received signal to be sent back to the other line end as an echo where it is used to initiate permissive tripping The detection of the weak infeed condition and accordingly the requirement for an echo are combined in a central AND gate The distance protection must neither be switched off nor blocked as it ...

Page 201: ...little later due to unfavourable short circuit current distribution If however the circuit breaker at the non feeding line end is open this delay of the echo signal is not required The echo delay time may then be bypassed The circuit breaker position is provided by the central information control functions refer to Section 2 23 1 The echo impulse is then transmitted alarm output ECHO SIGNAL the du...

Page 202: ...arameters which are applicable to the selected mode appear here If the teleprotection supplement is not required the address 121 is set to Teleprot Dist Disabled The following modes are possible with conventional transmission links as described in Section 2 7 Direct Underreach Transfer Trip Remote trip without any pickup PUTT Pickup PUTT Pickup PUTT Z1B Permissive Underreach Transfer Trip with Zon...

Page 203: ...a in the left section of the picture this fault would be in zone Z1B of the protection at B as zone Z1B is set incorrectly The distance protection at A would not pick up and therefore the pro tection in B would interpret this as a fault with single end infeed from B echo from A or no block signal at A This would result in a false trip The blocking scheme needs furthermore a fast reverse stage to g...

Page 204: ...nal short circuits The send signal is delayed by this time with the permissive overreach schemes POTT and UNBLOCKING if the protection had initially detected a reverse fault In the case of the blocking scheme BLOCKING the received blocking signal is prolonged by this time This setting is only possible via DIGSI at Additional Settings The preset value should be sufficient in most cases Echo Functio...

Page 205: ...nals of the transmis sion functions The echo function settings are common to all weak infeed measures and summarized in tabular form in Section 2 10 1 2 7 15 Settings Addresses which have an appended A can only be changed with DIGSI under Ad ditional Settings 2 7 16 Information List Addr Parameter Setting Options Default Setting Comments 2101 FCT Telep Dis ON OFF ON Teleprotection for Distance pro...

Page 206: ...off BI IntSP Dis Teleprotection ON OFF via BI 4052 Dis Telep OFF OUT Dis Teleprotection is switched OFF 4054 Dis T Carr rec OUT Dis Telep Carrier signal received 4055 Dis T Carr Fail OUT Dis Telep Carrier CHANNEL FAILURE 4056 Dis T SEND OUT Dis Telep Carrier SEND signal 4057 Dis T SEND L1 OUT Dis Telep Carrier SEND signal L1 4058 Dis T SEND L2 OUT Dis Telep Carrier SEND signal L2 4059 Dis T SEND L...

Page 207: ...th high fault resistances the fault detection of the distance protection often does not pick up because the measured impedance is outside the fault detection characteristic of the distance protection High fault resistances can be found for instance in overhead lines without earth wire or in sandy soil 2 8 1 Method of Operation Measured Quantities The zero sequence current is used as measured varia...

Page 208: ... Current Stage 3I0 The triple zero sequence current 3 I0 is passed through a numerical filter and then compared with the set value 3I0 If this value is exceeded an alarm is issued After the corresponding delay time T 3I0 has expired a trip command is issued which is also alarmed The reset threshold is approximately 95 of the pickup thresh old Figure 2 88 shows the logic diagram of the 3I0 stage Th...

Page 209: ...l filter that completely suppresses all harmonic components beginning with the 2nd harmon ic Therefore it is particularly suited for a highly sensitive earth fault detection A fourth definite time stage can be implemented by setting the inverse time stage refer to the next paragraph to a definite time stage Inverse Time Over current Stage 3I0P The logic of the stages with inverse time delay functi...

Page 210: ...n in the Technical Data Fig 2 89 shows the logic diagram The setting addresses of the IEC characteristics are shown by way of an example In the setting information the different setting ad dresses are described in detail It is also possible to implement this stage equally with a definite time delay In this case 3I0p PICKUP is the pickup threshold and Add T DELAY the definite time delay The inverse...

Page 211: ... the Technical Data Figure 2 90 shows the logic diagram In addition to the curve parameters a minimum time 3I0p MinT DELAY can be determined below this time no tripping can occur Below a current factor of 3I0p Startpoint which is set as a multiple of the basic setting 3I0p PICKUP no tripping can take place Further information regarding the effect of the various parameters can be found in the setti...

Page 212: ...id for t and in time direction by a deter mined constant time T forw U0inv The characteristics are shown in the Tech nical Data Figure 2 91 shows the logic diagram The tripping time depends on the level of the zero sequence voltage U0 For meshed earthed systems the zero sequence voltage increases towards the earth fault location The inverse characteristic results in the shortest command time for t...

Page 213: ...direction of a configurable compensation angle ϕcomp which is also referred to as compensated zero sequence power i e Sr 3I0 3U0 cos ϕ ϕComp where ϕ U0 I0 ϕComp thus determines the direction of the maximum sensitivity cos ϕ ϕComp 1 if ϕ ϕComp Due to its sign information the power calculation au tomatically includes the direction The power for the reverse direction can be deter mined by reversing t...

Page 214: ...rrent This zero sequence current could cause faulty pickup of the earth current stages if low pickup thresholds are set To avoid this the earth current stages are stabilized by the phase current as the phase currents increase the pickup thresholds are increased Figure 2 93 The sta bilization factor slope may be changed by means of the parameter Iph STAB Slope address 3104 It applies to all stages ...

Page 215: ...locked Inrush blocking is not effective below a certain current threshold This threshold is 22 mA on the secondary side for devices with sensitive earth current transformer and 0 41 IN for devices with normal earth current transformer Direction Determi nation with Zero Sequence System The direction determination is carried out with the measured current IE 3 I0 which is compared to a reference volt...

Page 216: ...s 3 I2 and 3 U2 are simply used for the measurement These signals must also have a minimum magnitude of 3I2 or 3U2 It is also possible to determine the direction with a zero sequence system or a negative sequence system In this case the device determines whether the zero sequence quantity UP according to Figure 2 94 is larger or the negative sequence voltage The direction is determined by the larg...

Page 217: ...tra functions or external devices via binary input e g reclosing device The phase selector evaluates the phase to earth voltages the phase currents and the symmetrical components of the currents If a single phase fault can be detected with certainty due to a considerable voltage collapse or a high overcurrent the trip is initi ated in the concerned phase Three pole tripping is initiated accordingl...

Page 218: ... pole tripping allowed Figure 2 96 Logic diagram of single pole tripping with phase selector Blocking The earth fault protection can be blocked by the distance protection If in this case a fault is detected by the distance protection the earth fault protection will not trip This gives the selective fault clearance by the distance protection preference over tripping by the earth fault protection Th...

Page 219: ...the available characteristics ac cording to the selected configuration and the version of the device are accessible in the procedures described below Parameter 3101 FCT EarthFltO C can be used to switch the earth fault protection ON or OFF This refers to all stages of the earth fault protection If not required each of the four stages can be deactivated by setting its MODE to Inactive see below Blo...

Page 220: ...p mode 3I0 address 3120 Op mode 3I0 and address 3130 Op mode 3I0 Each stage can be set to operate Forward usually towards line Reverse usually towards busbar or Non Directional in both directions If a single stage is not required set its mode to Inactive The definite time stages 3I0 address 3111 3I0 address 3121 and 3I0 address 3131 can be used for a three stage definite time overcurrent protectio...

Page 221: ...ust be noted that a safety margin between the pickup threshold and the set value has already been incorporat ed Pickup only occurs at a current which is approximately 10 above the set value The time multiplier setting 3I0p Time Dial address 3143 is derived from the grading coordination chart which was set up for earth faults in the system In addition to the inverse current dependant time delay a c...

Page 222: ...ode is initially set address 3140 Op mode 3I0p The stage can be set to operate Forward usually towards line Reverse usually towards busbar or Non Directional in both directions If the stage is not required set its mode to Inactive For the logarithmic inverse characteristic address 131 Earth Fault O C TOC Logarithm the setting of address is 3153 ANSI Curve Log inverse The characteristics and equati...

Page 223: ... the actual zero sequence voltage U0 min is the setting value U0inv minimum address 3183 Please take into consideration that the formula is based on the zero sequence voltage U0 not on 3U0 The function is illustrated in the Technical Data Figure 2 98 shows the most important parameters U0inv minimum displaces the voltage controlled characteristic in direction of 3U0 The set value is the asymptote ...

Page 224: ...e The zero sequence power Sr is calculated according to the formula Sr 3I0 3U0 cos ϕ ϕComp The angle ϕComp is set as maximum sensitivity angle at address 3168 PHI comp It refers to the zero sequence voltage in relation to the zero sequence current The default setting 255 thus corresponds to a zero sequence impedance angle of 75 255 180 Refer also to margin heading Zero Sequence Power Protection Th...

Page 225: ...rence signal apply the setting with IY only This makes sense if a reliable transformer starpoint current IY is always available at the device input I4 The direction determination is then not influenced by disturbances in the secondary circuit of the voltage transformers This presupposes that the device is equipped with a current input I4 of normal sensi tivity and that the current from the transfo...

Page 226: ...characteristic by means of the compensation angle PHI comp address 3168 which indicates the symmetry axis of the directional characteristic This value is also not critical for direction determination For information on the angle definition refer to margin heading Direction Determination with Zero Sequence Power This angle determines at the same time the maximum sensitivity of the zero sequence pow...

Page 227: ...be checked PICKUP DIRECT or not PICKUP before a switch onto fault tripping is generated It is the direction setting for each stage that applies for this direction check Phase Current Re straint To avoid a spurious pickup of the stages in the case of asymmetrical load conditions or varying current transformer measuring errors in earth systems the earth current stages are restrained by the phase cur...

Page 228: ...ead time 3104A Iph STAB Slope 0 30 10 Stabilisation Slope with Iphase 3105 3IoMin Teleprot 1A 0 01 1 00 A 0 50 A 3Io Min threshold for Tele prot schemes 5A 0 05 5 00 A 2 50 A 3105 3IoMin Teleprot 1A 0 003 1 000 A 0 500 A 3Io Min threshold for Tele prot schemes 5A 0 015 5 000 A 2 500 A 3109 Trip 1pole E F YES NO YES Single pole trip with earth flt prot 3110 Op mode 3I0 Forward Reverse Non Direction...

Page 229: ... InrushBlk NO YES NO Inrush Blocking 3140 Op mode 3I0p Forward Reverse Non Directional Inactive Inactive Operating mode 3141 3I0p PICKUP 1A 0 05 25 00 A 1 00 A 3I0p Pickup 5A 0 25 125 00 A 5 00 A 3141 3I0p PICKUP 1A 0 003 25 000 A 1 000 A 3I0p Pickup 5A 0 015 125 000 A 5 000 A 3142 3I0p MinT DELAY 0 00 30 00 sec 1 20 sec 3I0p Minimum Time Delay 3143 3I0p Time Dial 0 05 3 00 sec 0 50 sec 3I0p Time ...

Page 230: ...er angle for forward direction 3164 3U0 0 5 10 0 V 0 5 V Min zero seq voltage 3U0 for polarizing 3165 IY 1A 0 05 1 00 A 0 05 A Min earth current IY for polarizing 5A 0 25 5 00 A 0 25 A 3166 3U2 0 5 10 0 V 0 5 V Min neg seq polarizing voltage 3U2 3167 3I2 1A 0 05 1 00 A 0 05 A Min neg seq polarizing current 3I2 5A 0 25 5 00 A 0 25 A 3168 PHI comp 0 360 255 Compensation angle PHI comp for Sr 3169 S ...

Page 231: ...lt protection is ACTIVE 1335 EF TRIP BLOCK OUT Earth fault protection Trip is blocked 1336 E F L1 selec OUT E F phase selector L1 selected 1337 E F L2 selec OUT E F phase selector L2 selected 1338 E F L3 selec OUT E F phase selector L3 selected 1345 EF Pickup OUT Earth fault protection PICKED UP 1354 EF 3I0 Pickup OUT E F 3I0 PICKED UP 1355 EF 3I0 Pickup OUT E F 3I0 PICKED UP 1356 EF 3I0 Pickup OU...

Page 232: ...a digital communication lines via a protec tion data interface For example fibre optic cables communication networks or dedi cated cables control cable or twisted phone wire The send and receive signals must in this case be assigned to fast command channels of the protection data interface DIGSI matrix The direction comparison scheme is suited for these kinds of transmis sion 7SD5 allows also the ...

Page 233: ...cedure is suited for both conventional and digital transmission media Principle The directional comparison scheme is a permissive scheme The scheme functionality is shown in Figure 2 100 When the earth fault protection recognizes a fault in the forward direction it initially sends a permissive signal to the opposite line end If a permissive signal is also re ceived from the opposite end a trip sig...

Page 234: ...l fault With the setting parameter Line Config address 3202 the device is informed as to whether it has one or two opposite line ends The occurrence of erroneous signals resulting from transients during clearance of ex ternal faults or from direction reversal resulting during the clearance of faults on par allel lines is neutralized by the Transient Blocking see margin heading Transient Blocking O...

Page 235: ...76 C169 1 The circuit breaker can also be tripped at the line end with no or only weak infeed This Weak infeed tripping is referred to in Section 2 10 1 Figure 2 101 Logic diagram of the directional comparison scheme one line end w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 236: ...ates the transmission of the unblock frequency fU During the quiescent state or during an earth fault in the reverse direction the monitoring frequency f0 is transmitted If the unblock frequency is received from the opposite end a signal is routed to the trip logic A pre condition for fast fault clearance is therefore that the earth fault is recog nized in the forward direction at both line ends T...

Page 237: ...is issued after a security delay time of 20 ms and passed onto the receive logic This release is however removed after a further 100 ms via the timer stage 100 100 ms When the transmission is functional again one of the two receive signals must appear again either EF UB ub 1 or EF UB bl 1 after a further 100 ms dropout delay of the timer stage 100 100 ms the quiescent state is reached again i e th...

Page 238: ...rcuit breaker can also be tripped at the line end with no or only weak infeed This Weak infeed tripping is referred to in Section 2 10 1 Figure 2 103 Logic diagram of the unblocking scheme one line end w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 239: ...y after fault incep tion jump detector above dotted line and stopped immediately as soon as the dis tance protection detects a fault in the forward direction alternatively the signal is only sent when the distance protection detects the fault in the reverse direction It is stopped immediately as soon as the earth fault protection detects an earth fault in forward direction Tripping is possible wit...

Page 240: ...prolonged by the settable time TS once it has been initiated Figure 2 105 Operation scheme of the directional blocking method Sequence Figure 2 106 shows the logic diagram of the blocking scheme for one line end The stage to be blocked must be set to Forward 3I0 DIRECTION refer also to Section 2 8 under margin heading Teleprotection with Earth Fault Protection On two terminal lines the signal tran...

Page 241: ... Teleprotection for Earth Fault Protection optional 241 7SD5 Manual C53000 G1176 C169 1 Figure 2 106 Logic diagram of the blocking scheme one line end w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 242: ...scheme that single end fed short circuits can also be tripped rapidly without any special measures as the non feeding end cannot gen erate a blocking signal 2 9 5 Transient Blocking Transient blocking provides additional security against erroneous signals due to tran sients caused by clearance of an external fault or by fault direction reversal during clearance of a fault on a parallel line The pr...

Page 243: ...an echo are combined in a central AND gate The earth fault protection must neither be switched off nor blocked as it would otherwise always produce an echo due to the missing fault detection The essential condition for an echo is the absence of an earth current current stage 3IoMin Teleprot with simultaneous receive signal from the teleprotection scheme logic as shown in the corresponding logic di...

Page 244: ... which are applicable to the selected mode appear here If the teleprotection supplement is not required the address 132 is set to Teleprot E F Disabled The following modes are possible with conventional transmission links as described in Section 2 9 Dir Comp Pickup Directional Comparison Pickup UNBLOCKING Directional Unblocking Scheme BLOCKING Directional Blocking Scheme At address 3201 FCT Telep ...

Page 245: ...the smaller this stage must be set On overhead lines a setting equal to 70 to 80 of the earth current stage is usually adequate On cables or very long lines where the ca pacitive currents in the event of an earth fault are of the same order of magnitude as the earth fault currents the echo function should not be used or restricted to the case where the circuit breaker is open the blocking scheme s...

Page 246: ...required for the blocking scheme BLOCKING to allow sufficient transmission time for the blocking signal during external faults This delay only has an effect on the receive circuit of the teleprotection Conversely tripping by the comparison protection is not delayed by the set time delay of the directional stage Transient Blocking The setting parameters TrBlk Wait Time and TrBlk BlockTime are for t...

Page 247: ...o ensure that the receive signal is recognized even with different pickup times by the protection devices at the two line ends and different response times of the transmis sion equipment In most cases approx 50 ms presetting is sufficient This parameter can only be altered with DIGSI under Additional Settings An endless echo signal between the line ends can be avoided e g interference cou pling in...

Page 248: ... Channel 1 1319 EF Rec Ch2 SP E F Carrier RECEPTION Channel 2 1320 EF UB ub 1 SP E F Unblocking UNBLOCK Channel 1 1321 EF UB bl 1 SP E F Unblocking BLOCK Channel 1 1322 EF UB ub 2 SP E F Unblocking UNBLOCK Channel 2 1323 EF UB bl 2 SP E F Unblocking BLOCK Channel 2 1324 EF BlkEcho SP E F BLOCK Echo Signal 1325 EF Rec Ch1 L1 SP E F Carrier RECEPTION Channel 1 Ph L1 1326 EF Rec Ch1 L2 SP E F Carrier...

Page 249: ...ep Transient Blocking 1387 EF TeleUB Fail1 OUT E F Telep Unblocking FAILURE Channel 1 1388 EF TeleUB Fail2 OUT E F Telep Unblocking FAILURE Channel 2 1389 EF Tele BL STOP OUT E F Telep Blocking carrier STOP signal 1390 EF Tele BL Jump OUT E F Tele Blocking Send signal with jump No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 250: ...cated trip command Pickup with Undervoltage In Figure 2 111 the logic diagram of the weak infeed tripping is shown The function can be activated ECHO and TRIP or deactivated OFF in address 2501 FCT Weak Infeed Weak Infeed FunCTion If this switch is set to ECHO only the tripping is also disabled however the echo function to release the infeeding line end is activated refer also to Section 2 7 and 2...

Page 251: ...ty pickup of the weak infeed function following tripping of the line and reset of the fault detection the function cannot pick up anymore once a fault detection in the affected phase was present RS flip flop in Figure 2 111 In the case of the earth fault protection the release signal is routed via the phase seg regated logic modules Single phase tripping is therefore also possible if both distance...

Page 252: ...2 Functions 252 7SD5 Manual C53000 G1176 C169 1 Figure 2 111 Logic diagram of the weak infeed tripping w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 253: ...guration The associated parameters are then not accessible The undervoltage setting value UNDERVOLTAGE address 2505 must in any event be set below the minimum expected operational phase earth voltage The lower limit for this setting is given by the maximum expected voltage drop at the relay location on the weak infeed side during a short circuit on the protected feeder for which the distance prote...

Page 254: ...2 Functions 254 7SD5 Manual C53000 G1176 C169 1 Non delayed Trip ping Figure 2 112 Logic diagram for non delayed tripping w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 255: ...2 10 Weak infeed Tripping optional 255 7SD5 Manual C53000 G1176 C169 1 Trip with Delay Figure 2 113 Logic diagram for delayed tripping w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 256: ...in this phase Figure 2 114 Undervoltage detection for UL1 E Non delayed Tripping A non delayed TRIP command is issued if a receive signal WI reception is present and an undervoltage condition is detected simultaneously If another protec tion function capable to detect faults has picked up in the relay the corresponding phases in the weak infeed function are blocked The receive signal is prolonged ...

Page 257: ...ping stage is implemented to allow tripping the dedicated line end in case the transmission channel is faulted When undervoltage conditions have been detected this stage picks up in one or more phases and after a configured time ad dress 2515 TM and address 2516 TT has elapsed it trips without delay Address 2531 WI delayed allows to set delayed tripping as operating mode With ON this stage is perm...

Page 258: ...e pole WI trip allowed 2520 T 3I0 alarm 0 00 30 00 sec 10 00 sec 3I0 exceeded delay for alarm 2530 WI non delayed ON OFF ON WI non delayed 2531 WI delayed ON by receive fail by receive fail WI delayed No Information Type of In formation Comments 4203 BLOCK Weak Inf SP BLOCK Weak Infeed 4204 BLOCK del WI SP BLOCK delayed Weak Infeed stage 4205 WI rec OK SP Reception channel for Weak Infeed OK 4206 ...

Page 259: ...Infeed General TRIP command 4242 Weak TRIP 1p L1 OUT Weak Infeed TRIP command Only L1 4243 Weak TRIP 1p L2 OUT Weak Infeed TRIP command Only L2 4244 Weak TRIP 1p L3 OUT Weak Infeed TRIP command Only L3 4245 Weak TRIP L123 OUT Weak Infeed TRIP command L123 4246 ECHO SIGNAL OUT ECHO Send SIGNAL No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 260: ... Line End On conventional transmission paths one transmission channel per desired transmis sion direction is required for remote tripping at the remote end For example fibre optic connections or voice frequency modulated high frequency channels via pilot cables power line carrier or microwave radio links can be used for this purpose in the following ways If the trip command of the distance protect...

Page 261: ...ng signal pulse is very short 2 11 3 Settings 2 11 4 Information List Addr Parameter Setting Options Default Setting Comments 2201 FCT Direct Trip ON OFF OFF Direct Transfer Trip DTT 2202 Trip Time DELAY 0 00 30 00 sec 0 01 sec Trip Time Delay No Information Type of In formation Comments 4403 BLOCK DTT SP BLOCK Direct Transfer Trip function 4412 DTT Trip L1 SP Direct Transfer Trip INPUT Phase L1 4...

Page 262: ...ther ends and can be processed at each receiving side with the output functions RemoteTrip1 rec to RemoteTrip4 rec The other 24 items of information reach the device via the binary inputs Rem Signal 1 to Rem Signal24 and are available under Rem Sig 1recv etc at the receiving side When allocating the binary inputs and outputs with DIGSI you can provide the infor mation to be transmitted with your o...

Page 263: ...al 11 input 3560 Rem Signal12 SP Remote Signal 12 input 3561 Rem Signal13 SP Remote Signal 13 input 3562 Rem Signal14 SP Remote Signal 14 input 3563 Rem Signal15 SP Remote Signal 15 input 3564 Rem Signal16 SP Remote Signal 16 input 3565 Rem Signal17 SP Remote Signal 17 input 3566 Rem Signal18 SP Remote Signal 18 input 3567 Rem Signal19 SP Remote Signal 19 input 3568 Rem Signal20 SP Remote Signal 2...

Page 264: ... Remote signal 17 received 3590 Rem Sig18recv OUT Remote signal 18 received 3591 Rem Sig19recv OUT Remote signal 19 received 3592 Rem Sig20recv OUT Remote signal 20 received 3593 Rem Sig21recv OUT Remote signal 21 received 3594 Rem Sig22recv OUT Remote signal 22 received 3595 Rem Sig23recv OUT Remote signal 23 received 3596 Rem Sig24recv OUT Remote signal 24 received No Information Type of In form...

Page 265: ...ffective An indispensable precondition for the functioning of the I STUB stage is that the auxiliary contacts of the circuit breakers are connected at all ends of the protected object and allocated to the relevant binary inputs If this is not the case this stage is not effective The central function control communicates the information of the circuit breaker position to the high current instantane...

Page 266: ...oose a value which is high enough for the protection not to pick up on the RMS value of the inrush current produced during the connection of the protected object On the other hand fault currents flowing through the protected object need not be considered When using a PC and DIGSI to apply the settings these can be optionally entered as primary or secondary values If secondary quantities are used a...

Page 267: ...ed Z1 s 0 192 0 422 Ω km 0 46 Ω km ZL 0 46 Ω km 60 km 27 66 Ω The three phase short circuit current at line end is I sc end with source voltage 1 1 UN With a safety factor of 10 the following primary setting value results Setting value I 1 1 2245 A 2470 A Or the secondary setting value i e in case of fault currents exceeding 2470 A primary or 20 6 A secondary you can be sure that a short circuit h...

Page 268: ...KUP OUT SOTF O C PICKED UP 4282 SOF O CpickupL1 OUT SOTF O C Pickup L1 4283 SOF O CpickupL2 OUT SOTF O C Pickup L2 4284 SOF O CpickupL3 OUT SOTF O C Pickup L3 4285 I O C p upL1 OUT High Speed O C Pickup I L1 4286 I O C p upL2 OUT High Speed O C Pickup I L2 4287 I O C p upL3 OUT High Speed O C Pickup I L3 4289 HS SOF TRIP1pL1 OUT High Speed SOTF O C TRIP Only L1 4290 HS SOF TRIP1pL2 OUT High Speed ...

Page 269: ...rmer mcb tripped signal is received via binary input indicating that the measured voltage signal is lost or One of the internal monitoring functions e g current sum wire break or Fuse Failure Monitor is activated see Section 2 22 1 3 For the overcurrent protection there are in total four stages for the phase currents and four stages for the earth currents as follows Two overcurrent stages with a d...

Page 270: ...gram of the I stages The stages can be blocked via a binary input BLOCK O C I In addition the earth current stage can be blocked separately via the binary input BLOCK O CIe e g during a single pole dead time before reclosure in order to avoid a spurious tripping with the zero phase sequence system which is present then Binary inputs O C InstTRIP and the function block switch onto fault are common ...

Page 271: ...ph or 3I0 PICKUP with 3I0 In all other respects Figure 2 117 applies Inverse Time Over current Stage IP The logic of the inverse overcurrent stage also operates chiefly in the same way as the remaining stages However the time delay is calculated here based on the type of the set characteristic the intensity of the current and a time multiplier following fig ure A pre selection of the available cha...

Page 272: ...c Additional Stage I The additional definite time or instantaneous overcurrent stage I STUB has an extra enable input Figure 2 119 It is therefore also suitable e g as an emergency stage The enable input I STUB ENABLE can be assigned to the output signal Emer mode either via binary outputs and inputs or via the user definable logic CFC func tions The stage is then automatically active when the dif...

Page 273: ...iagram of the I stage Instantaneous Trip ping before Auto matic Reclosure Automatic reclosure is applied in order to instantaneously remove the fault before au tomatic reclosure A release signal from an external automatic reclosure device can be injected via binary input O C InstTRIP The internal automatic reclosure if available is also effected by this command Any stage of the overcurrent protect...

Page 274: ...are indicated Table 2 12 In case of trip signals the stage which resulted in the trip command is also indicated For single pole tripping the pole is identified see also Section 2 23 1 Pickup Logic of the Entire Device Table 2 12 Pickup signals of the single phases Internal Indication Display Output Indication No I PU L1 I PU L1 Ip PU L1 I PU L1 2 117 2 118 2 119 O C Pickup L1 7162 I PU L2 I PU L2 ...

Page 275: ...c tion has been set to Only Emer prot and I STUB ENABLE is released One or several stages can be set as instantaneous tripping stages when switching onto a fault This is chosen during the setting of the individual stages see below To avoid a spurious pickup due to transient overcurrents the delay SOTF Time DELAY address 2680 can be set Typically the presetting of 0 is correct A short delay can be ...

Page 276: ...rcurrent protection Note the calculation was carried out with absolute values which is sufficiently precise for overhead lines If the angles of the source impedance and the line impedance vary considerably a complex calculation must be carried out A similar calculation must be carried out for earth faults with the maximum earth current occurring at the line end during a short circuit being decisiv...

Page 277: ... used all currents must be converted to the secondary side of the current transformers Calculation Example 110 kV overhead line 150 mm2 maximum transmittable power Pmax 120 MVA corresponding to Imax 630 A Current Transformer 600 A 5 A Safety factor 1 1 With settings in primary quantities the following setting value is calculated Set value I 1 1 630 A 693 A With settings in secondary quantities the...

Page 278: ...eInverse longtime type B according to IEC 60255 3 The characteristics and equations they are based on are listed in the Technical Data For the setting of the current thresholds Ip address 2640 and 3I0p PICKUP ad dress 2650 the same considerations as for the overcurrent stages of the definite time protection see above apply In this case it must be noted that a safety margin between the pickup thres...

Page 279: ...dress 126 With the ANSI characteristics address 126 Back Up O C TOC ANSI the follow ing options are available at address 2661 ANSI Curve Inverse Short Inverse Long Inverse Moderately Inv Very Inverse Extremely Inv and Definite Inv The characteristics and equations they are based on are listed in the Technical Data For the setting of the current thresholds Ip address 2640 and 3I0p PICKUP ad dress 2...

Page 280: ...ently via a binary input or CFC Since the I STUB stage has an additional enable input it is also suitable e g as an emergency stage if the remaining stages are used as backup stages The release input I STUB ENABLE No 7131 can be assigned the output signal Emer mode No 2054 either via binary outputs and inputs or via the user definable logic CFC functions The considerations for the use of the I STU...

Page 281: ...c T 3I0 Time delay 2614 I Telep BI NO YES YES Instantaneous trip via Tele prot BI 2615 I SOTF NO YES NO Instantaneous trip after SwitchOnToFault 2620 Iph 1A 0 10 25 00 A 1 50 A Iph Pickup 5A 0 50 125 00 A 7 50 A 2621 T Iph 0 00 30 00 sec 0 50 sec T Iph Time delay 2622 3I0 1A 0 05 25 00 A 0 20 A 3I0 Pickup 5A 0 25 125 00 A 1 00 A 2623 T 3I0 0 00 30 00 sec 2 00 sec T 3I0 Time delay 2624 I Telep BI N...

Page 282: ...e 2670 I 3I0 p Tele BI NO YES NO Instantaneous trip via Tele prot BI 2671 I 3I0 p SOTF NO YES NO Instantaneous trip after SwitchOnToFault 2680 SOTF Time DELAY 0 00 30 00 sec 0 00 sec Trip time delay after SOTF No Information Type of In formation Comments 7104 BLOCK O C I SP BLOCK Backup OverCurrent I 7105 BLOCK O C I SP BLOCK Backup OverCurrent I 7106 BLOCK O C Ip SP BLOCK Backup OverCurrent Ip 71...

Page 283: ...up L31 OUT Backup O C Pickup L31 7181 O C Pickup L31E OUT Backup O C Pickup L31E 7182 O C Pickup L23 OUT Backup O C Pickup L23 7183 O C Pickup L23E OUT Backup O C Pickup L23E 7184 O C Pickup L123 OUT Backup O C Pickup L123 7185 O C PickupL123E OUT Backup O C Pickup L123E 7191 O C PICKUP I OUT Backup O C Pickup I 7192 O C PICKUP I OUT Backup O C Pickup I 7193 O C PICKUP Ip OUT Backup O C Pickup Ip ...

Page 284: ...le auto reclosure for multiple phase faults in the network with earthed system starpoint If the fault still exists after automatic reclosure arc has not disappeared there is a metallic fault then the pro tective elements will re trip the circuit breaker In some systems several reclosing at tempts are performed In a model with single pole tripping the 7SD5 allows phase selective single pole trip pi...

Page 285: ...he parameters of the fourth cycle also apply for the fifth cycle and onwards Activation and De activation The automatic reclosure function can be switched on and off by means of the param eter 3401 AUTO RECLOSE or via the system interface if available and via binary input if this is allocated The switched state is saved internally refer to Figure 2 121 and secured against loss of auxiliary supply ...

Page 286: ... here because a reclosure will be performed in any case The normal stages of the distance protection Z1 Z2 etc and the normal grading of the other short circuit functions are independent of the automatic reclosure function Figure 2 122 Reach control before first reclosure using distance protection If the distance protection is operated with one of the signal transmission methods de scribed in Sect...

Page 287: ...itiation Starting the automatic reclosure function means storing the first trip signal during a network fault that was generated by a protection function which operates with the au tomatic reclose function In case of multiple reclosure initiation therefore only takes place once with the first trip command The detection of the actual circuit breaker po sition is necessary for the correct functional...

Page 288: ... cycle would then become active but the time overcurrent protection would not trip in this example until after 1s according to its grading time Since the action time for the second cycle was exceeded here it is blocked The 3rd cycle with its parameters is therefore carried out now If the trip command only appeared more than 1 2s after the 1st reclosure there would have been no further reclosure Ex...

Page 289: ...e reclaim time is treated as a new fault in the network Re tripping by a protection function during the reclaim time initiates the next reclose cycle in the case of multiple reclosure if no further reclosure is permitted the last reclosure cycle is declared as unsuccessful if re tripping within the reclaim time takes place The automatic reclosure is blocked dy namically The dynamic lock out locks ...

Page 290: ...n of the normally open contacts is closed binary input CB1 3p Closed No 410 If none of these input messages is active it is assumed that the breaker is open at one pole even if this condition also exists theoretically when two poles are open The device continuously checks the switching state of the circuit breaker as long as the auxiliary contacts indicate that the CB is not closed three pole the ...

Page 291: ...hort circuit protection trips single pole for all single phase faults inside the stage selected for reclosure Under the general settings address 1156 Trip2phFlt see also Section 2 1 4 1 it can also be select ed that single pole tripping takes place for two phase faults without earth Single pole tripping is of course only possible with short circuit protection functions that can deter mine the faul...

Page 292: ...rt circuit protection initiates a final three pole trip with the protection stage that is valid selected when reclosure is not ready All faults during the reclaim time also lead to the issue of a final three pole trip After unsuccessful reclosure final tripping the automatic reclosure is blocked dy namically see also margin heading Reclose Block above The sequence above applies for single reclosur...

Page 293: ...ential fault after the dead time the circuit breaker receives a close command The further sequence is the same as for single and three pole cycles The complete dead time in this case consists of the portion of the single pole dead time up to clearance of the sequential fault plus the dead time for the sequential fault This makes sense because the duration of the three pole dead time is most import...

Page 294: ...nly and to configure the adaptive dead time at the other end or ends This can be done provided that the voltage transformers are located on the line side of the circuit breaker or that facilities for transfer of a close command to the remote line end exists Figure 2 123 shows an example with voltage measurement It is assumed that the device I is operating with defined dead times whereas the adapti...

Page 295: ... one line end The other or the others in lines with more than two ends are set to Adaptive Dead Time ADT The latter only react to the received close commands from the transmitting end An adaptive dead time is thus possible even without a voltage At the sending line end the trasmission of the close command is delayed until it is sure that the local reclosure was successful This means that after rec...

Page 296: ...tection functions trip three pole for all faults If the external re closure device cannot supply this signal but supplies a three pole coupling signal instead this must be taken into account in the allocation of the binary inputs the signal must be inverted in this case L active active without voltage Binary outputs 501 Relay PICKUP Start of protection device general if required by exter nal reclo...

Page 297: ... for example on line ends with redundant protection or additional back up protection when the second protection is used for the same line end and has to work with the automatic reclosure function integrated in the 7SD5 The binary inputs and outputs provided for this functionality must be considered in this case It must be decided whether the internal auto reclosure is to be controlled by the start...

Page 298: ... 1 CycZoneRel Internal automatic reclosure function ready for the first reclose cycle i e releases the stage of the external protection device for reclosure the corresponding outputs can be used for other cycles This output can be omitted if the external protection does not require an overreaching stage e g differential protection or comparison mode with distance protection 2820 AR Program1pole In...

Page 299: ...reclosure AR control mode with TRIP But if the internal automatic reclose function is controlled by the pickup only possible for three pole tripping 110 Trip mode 3pole only the phase dedicated pickup signals of the external protection must be connected if distinction shall be made between different types of fault The general trip command then suffices for tripping No 2746 Figure 2 128 shows a con...

Page 300: ...gnal exchange between the two combinations is necessary The connection example in Figure 2 129 shows the necessary cross connections If phase segregated auxiliary contacts of the circuit breaker are connected a three pole coupling by the 7SD5 is guaranteed when more than one CB pole is tripped This requires activation of the forced three pole trip see Section 2 15 2 at margin heading Forced Three ...

Page 301: ...nals regarding the auto reclose function are gener ated and the binary inputs for the auto reclose function are ignored All parameters for setting the auto reclose function are inaccessible and of no significance If on the other hand the internal automatic reclosure function is to be used the type of reclosure must be selected during the configuration of the functions see Section 2 1 1 3 in addres...

Page 302: ...ly be altered with DIGSI under Additional Set tings Remember that longer dead times are only permissible after three pole tripping when no stability problems arise or when a synchro check takes place before reclo sure The blocking time T RECLAIM address 3403 defines the time that must elapse after a successful reclosing attempt before the automatic reclosing function is reset Re tripping of a prot...

Page 303: ...e circuit breaker auxiliary contact or the disappear ance of the trip command If a circuit breaker failure protection internal or external is used on the feeder this time should be shorter than the delay time of the circuit breaker failure protection so that no reclosure takes place if the circuit breaker fails If the reclosure command is transmitted to the opposite end this transmission can be de...

Page 304: ...440 is irrelevant here Adaptive Dead Time ADT When operating with adaptive dead time it must be ensured in advance that one end per line operates with defined dead times and has an infeed The other or the others in multi branch lines may operate with adaptive dead time It is essential that the voltage transformers are located on the line side of the circuit breaker Details about this function can ...

Page 305: ... In this case the volt ages from line and busbar are checked after a three pole trip and before reclosure to determine if sufficient synchronism exists This is only done on condition that either the internal synchronism and voltage check functions are available or that an external device is available for synchronism check If only single pole reclose cycles are exe cuted or no stability problems ar...

Page 306: ...surrounding air to be de ionized so that the reclosure promises to be successful The longer the line the longer is this time due to the charging of the conductor capacitances Con ventional values are 0 9 s to 1 5 s For three pole tripping address 3457 1 AR Tdead3Trip the stability of the network is the main concern Since the de energized line cannot transfer synchroniz ing energy only short dead t...

Page 307: ...eclo sure Cycle If several cycles have been set in the configuration of the scope of protection func tions you can set individual reclosure parameters for the 2nd to 4th cycles The same options are available as for the first cycle Again only some of the parameters shown below will be available depending on the selections made during configuration of the scope of protection functions For the 2nd cy...

Page 308: ...al protection functions can use this information to release accelerated or overreaching trip stages prior to the cor responding reclose cycle AR is blocked No 2783 The automatic reclosure is blocked e g circuit breaker not ready This information indicates to the operational information system that in the event of an upcoming system fault there will be a final trip i e without reclosure If the auto...

Page 309: ...by the output information AR Sync Request No 2865 2 15 3 Settings Addresses which have an appended A can only be changed with DIGSI under Ad ditional Settings Addr Parameter Setting Options Default Setting Comments 3401 AUTO RECLOSE OFF ON ON Auto Reclose Function 3402 CB 1 TRIP YES NO NO CB ready interrogation at 1st trip 3403 T RECLAIM 0 50 300 00 sec 3 00 sec Reclaim time after successful AR cy...

Page 310: ...e 0 10 30 00 sec 0 10 sec Supervision time for dead live voltage 3440 U live 30 90 V 48 V Voltage threshold for live line or bus 3441 U dead 2 70 V 30 V Voltage threshold for dead line or bus 3450 1 AR START YES NO YES Start of AR allowed in this cycle 3451 1 AR T ACTION 0 01 300 00 sec 0 20 sec Action time 3453 1 AR Tdead 1Flt 0 01 1800 00 sec 1 20 sec Dead time after 1phase faults 3454 1 AR Tdea...

Page 311: ...3477 3 AR Tdead 3Flt 0 01 1800 00 sec 0 50 sec Dead time after 3phase faults 3478 3 AR Tdead1Trip 0 01 1800 00 sec sec Dead time after 1pole trip 3479 3 AR Tdead3Trip 0 01 1800 00 sec 0 50 sec Dead time after 3pole trip 3480 3 AR Tdead EV 0 01 1800 00 sec 1 20 sec Dead time after evolving fault 3481 3 AR CB CLOSE YES NO NO CB ready interrogation before re closing 3482 3 AR SynRequest YES NO NO Req...

Page 312: ...d higher AR cycles 2746 Trip for AR SP AR External Trip for AR start 2747 Pickup L1 AR SP AR External pickup L1 for AR start 2748 Pickup L2 AR SP AR External pickup L2 for AR start 2749 Pickup L3 AR SP AR External pickup L3 for AR start 2750 Pickup 1ph AR SP AR External pickup 1phase for AR start 2751 Pickup 2ph AR SP AR External pickup 2phase for AR start 2752 Pickup 3ph AR SP AR External pickup ...

Page 313: ...st cycle 2854 AR Close 2 Cyc OUT AR Close command 2nd cycle and higher 2861 AR T Recl run OUT AR Reclaim time is running 2862 AR successful OUT AR successful 2863 Definitive Trip OUT Definitive TRIP 2864 AR 1p Trip Perm OUT AR 1pole trip permitted by internal AR 2865 AR Sync Request OUT AR Synchro check request 2871 AR TRIP 3pole OUT AR TRIP command 3pole 2889 AR 1 CycZoneRel OUT AR 1st cycle zone...

Page 314: ...anual closure Synchronism check is also possible without external matching transformers if a power transformer is located between the measuring points Closing is released for synchronous or asynchronous system conditions In the latter case the device determines the time for issuing the close command such that the volt ages are identical the instant the breaker poles make contact 2 16 1 Method of O...

Page 315: ...iff such that the voltages on the busbar and the feeder circuit have exactly the same phase relationship at the instant that the circuit breaker primary contacts close For this purpose the device must be informed on the operating time of the circuit breaker for closing Differ ent frequency limit thresholds apply to switching under synchronism and asynchro nous conditions If closing is permitted ex...

Page 316: ...hronism will not be checked A new synchronism check se quence requires a new request The device outputs indications if after a request to check synchronism the conditions for release are not fulfilled i e if the absolute voltage difference Max Volt Diff the absolute frequency difference Max Freq Diff or the absolute phase angle difference Max Angle Diff lie outside the permissible limit values A p...

Page 317: ...ting range fN 3 Hz Does the frequency difference fline fbus lie within the permissible tolerance Max Freq Diff Is the angle difference ϕline ϕbus within the permissible tolerance Max Angle Diff To check whether these conditions are observed for a certain minimum time you can set this minimum time as T SYNC STAB Checking the synchronism conditions can also be confined to a maximum monitoring time T...

Page 318: ...feeder voltage and second ary bus bar voltage under nominal voltage conditions 230 Rated Frequency The operating range of the synchronism check refers to the nominal frequency of the power system fN 3 Hz 1103 FullScaleVolt Nominal operational voltage of the primary power system phase phase in kV and if closing at asynchronous system conditions is allowed 239 T CB close The closing time of the circ...

Page 319: ...GSI Depending on the connection of the voltages these are phase to earth voltages or phase to phase voltages The maximum permissible voltage for the operating range of the synchronism check function is set in address 3504 Umax The setting is applied in Volts secondary This value can be entered as a primary value when parameterizing with a PC and DIGSI Depending on the VT connection these are phase...

Page 320: ...ronism Check Conditions before Manual Closing Addresses 3530 to 3539 are relevant to the check conditions before manual closure and closing via control command of the circuit breaker When setting the general pro tection data Power System Data 2 Section 2 1 4 1 it was already decided at address 1151 whether synchronism and voltage check should be carried out before manual closing With the following...

Page 321: ...arameter can only be altered with DIGSI under Additional Settings 3536 MC Usyn Uline The busbar UBus must be live Live Volt Thr address 3503 the feeder ULine must be dead Dead Volt Thr address 3502 3537 MC Usyn Uline The busbar UBus must be dead Dead Volt Thr address 3502 the feeder ULine must be live Live Volt Thr address 3503 3538 MC Usyn Uline The busbar UBus and the feeder ULine must both be d...

Page 322: ...measurement request Sync release No 2951 Release signal to an external automatic reclosure device 2 16 3 Settings Addresses which have an appended A can only be changed with DIGSI under Ad ditional Settings Addr Parameter Setting Options Default Setting Comments 3501 FCT Synchronism ON OFF ON w o CloseCmd ON Synchronism and Voltage Check function 3502 Dead Volt Thr 1 60 V 5 V Voltage threshold dea...

Page 323: ...ve line check before Man Cl 3538 MC Usyn Uline YES NO NO Dead bus dead line check before Man Cl 3539 MC O RIDE YES NO NO Override of any check before Man Cl No Information Type of In formation Comments 2901 Sync on SP Switch on synchro check function 2902 Sync off SP Switch off synchro check function 2903 BLOCK Sync SP BLOCK synchro check function 2905 Sync Start MC SP Start synchro check for Manu...

Page 324: ...f OUT Sync Freq diff greater than limit 2949 Sync ϕ diff OUT Sync Angle diff greater than limit 2951 Sync release OUT Synchronism release to ext AR 2961 Sync CloseCmd OUT Close command from synchro check 2970 Sync f bus OUT Sync Bus frequency fn 3Hz 2971 Sync f bus OUT Sync Bus frequency fn 3Hz 2972 Sync f line OUT Sync Line frequency fn 3Hz 2973 Sync f line OUT Sync Line frequency fn 3Hz 2974 Syn...

Page 325: ...its respective time delay Abnormally high voltages often occur e g in low loaded long distance transmission lines in islanded systems when generator voltage regulation fails or after full load shutdown of a generator from the system Even if compensation reactors are used to avoid line overvoltages by compensation of the line capacitance and thus reduction of the overvoltage the overvoltage will en...

Page 326: ... protection can also be blocked via a binary input Uph ph BLK Overvoltage Posi tive Sequence System U1 The device calculates the positive sequence system according to its defining equation U1 1 3 UL1 a UL2 a2 UL3 where a ej120 The resulting single phase AC voltage is fed to the two threshold stages U1 and U1 see Figure 2 133 Combined with the associated time delays T U1 and T U1 these stages form ...

Page 327: ...ine end but it can only be removed by switch ing off the local line end For calculating the voltage at the opposite line end the device requires the line data inductance per unit length capacitance per unit length line angle line length which were entered in the Power System Data 2 Section 2 1 4 1 during configuration Compounding is only available if address 137 is set to Enabl w comp In this case...

Page 328: ...wo stage overvoltage protection for the negative sequence system is formed Here too the drop out to pickup ratio can be set Figure 2 135 Logic diagram of the overvoltage protection for the negative sequence voltage system U2 The overvoltage protection for the negative sequence system can also be blocked via a binary input U2 BLK The stages of the negative sequence voltage protec tion are automatic...

Page 329: ...re automatically blocked as soon as an asymmetrical voltage failure was detected Fuse Failure Monitor also see Section 2 22 1 margin heading Fuse Failure Monitor Non symmetrical Voltages or when the trip of the mcb for voltage trans formers has been signalled via the binary input FAIL Feeder VT internal indi cation internal blocking The stages of the zero sequence voltage protection are automatica...

Page 330: ... depicts the logic diagram of the phase voltage stages The fundamental frequency is numerically filtered from each of the three measuring voltages so that har monics or transient voltage peaks are largely harmless Two threshold stages Uph e and Uph e are compared with the voltages If phase voltage falls below a threshold it is indicated phase segregated Furthermore a general pickup indication Uph ...

Page 331: ...urrent of the corresponding phase is also exceeded This condition is communicated by the central function control of the device The undervoltage protection phase earth can be blocked via a binary input Uph e BLK The stages of the undervoltage protection are then automatically blocked if a voltage failure is detected Fuse Failure Monitor also see Section 2 22 1 or if the trip of the mcb of the volt...

Page 332: ...t is sufficient for the current criterion that current flow is detected in one of the involved phases The phase phase undervoltage protection can also be blocked via a binary input Uphph BLK There is an automatic blocking if the measuring voltage failure was detected or voltage mcb tripping was indicated internal blocking of the phases affected by the voltage failure During single pole dead time f...

Page 333: ...f the current flow is detected in at least one phase together with the un dervoltage criterion The undervoltage protection for the positive sequence system can be blocked via the binary input U1 BLK The stages of the undervoltage protection are automat ically blocked if voltage failure is detected Fuse Failure Monitor also see Section 2 22 1 or if the trip of the mcb for the voltage transformer is...

Page 334: ...d on long unloaded lines the Uph e stage address 3702 is set to at least 5 above the maximum stationary phase to earth voltage that is to be expected in operation Additionally a high drop off to pick up ratio is required address 3709 Uph e RESET 0 98 preset ting This setting is only possible via DIGSI at Additional Settings The delay time T Uph e address 3703 should be a few seconds so that overvo...

Page 335: ...d ON or OFF separately for each of the U1 stages for the U1 stage at address 3736 U1 Compound and for the U1 stage at address 3737 U1 Compound The dropout to pickup ratio address 3739 U1 RESET is set as high as possible with regard to the detection of even small steady state overvoltages This parameter can only be altered with DIGSI under Additional Settings Overvoltage Nega tive Sequence System U...

Page 336: ...voltage If any other voltage is connected to U4 which is not used for voltage protection and if this was already set in the Power System Data 1 refer also to Section 2 1 2 1 under margin heading Voltage Connection e g U4 transformer Usync transf or U4 transformer Not connected the device calculates the zero sequence voltage from the phase voltages according to its definition 3 U0 UL1 UL2 UL3 When ...

Page 337: ...ding times delay are T Uph ph address 3763 and T Uphph ad dress 3765 The dropout to pickup ratio can be set in address This parameter can only be altered with DIGSI under Additional Settings If the voltage transformers are located on the line side the measuring voltages will be missing when the line is disconnected To avoid that the undervoltage levels in these cases are or remain picked up the cu...

Page 338: ... e Time Delay 3704 Uph e 1 0 170 0 V 100 0 V Uph e Pickup 3705 T Uph e 0 00 100 00 sec 1 00 sec T Uph e Time Delay 3709A Uph e RESET 0 30 0 98 0 98 Uph e Reset ratio 3711 Uph ph OFF Alarm Only ON OFF Operating mode Uph ph overvolt age prot 3712 Uph ph 2 0 220 0 V 150 0 V Uph ph Pickup 3713 T Uph ph 0 00 100 00 sec 2 00 sec T Uph ph Time Delay 3714 Uph ph 2 0 220 0 V 175 0 V Uph ph Pickup 3715 T Up...

Page 339: ...100 00 sec 2 00 sec T Uph e Time Delay 3754 Uph e 1 0 100 0 V 0 10 0 V Uph e Pickup 3755 T Uph e 0 00 100 00 sec 1 00 sec T Uph e Time Delay 3758 CURR SUP Uphe ON OFF ON Current supervision Uph e 3761 Uph ph OFF Alarm Only ON OFF Operating mode Uph ph under voltage prot 3762 Uph ph 1 0 175 0 V 0 50 0 V Uph ph Pickup 3763 T Uph ph 0 00 100 00 sec 2 00 sec T Uph ph Time Delay 3764 Uph ph 1 0 175 0 V...

Page 340: ...K OUT U2 Overvolt is BLOCKED 10225 Uph e OFF OUT Uph e Undervolt is switched OFF 10226 Uph e BLK OUT Uph e Undervolt is BLOCKED 10227 Uph ph OFF OUT Uph ph Undervolt is switched OFF 10228 Uph ph BLK OUT Uphph Undervolt is BLOCKED 10229 U1 OFF OUT U1 Undervolt is switched OFF 10230 U1 BLK OUT U1 Undervolt is BLOCKED 10231 U ACTIVE OUT Over Under Voltage protection is ACTIVE 10240 Uph e Pickup OUT U...

Page 341: ...1 TimeOut OUT U1 TimeOut 10304 U1 TRIP OUT U1 TRIP command 10310 Uph e Pickup OUT Uph e Pickup 10311 Uph e Pickup OUT Uph e Pickup 10312 Uph e PU L1 OUT Uph e Pickup L1 10313 Uph e PU L2 OUT Uph e Pickup L2 10314 Uph e PU L3 OUT Uph e Pickup L3 10315 Uph e TimeOut OUT Uph e TimeOut 10316 Uph e TimeOut OUT Uph e TimeOut 10317 Uph e TRIP OUT Uph e TRIP command 10325 Uph ph Pickup OUT Uph ph Pickup 1...

Page 342: ...lds and time delays This ensures variable matching to the application pur pose If an element is set to a value above the rated frequency it is automatically inter preted to be an overfrequency stage f If an element is set to a value below the rated frequency it is automatically inter preted to be an underfrequency stage f If an element is set exactly to the rated frequency it is inactive Each elem...

Page 343: ...ng location of the device and the setting of the frequency elements power swings may cause the frequency protection to pickup and even to trip In such cases out of step trips can not be pre vented by operating the distance protection with power swing blocking see also Section 2 6 Rather it is reasonable to block the frequency protection once power swings are detected This can be accomplished via b...

Page 344: ...s If the function is not required Disabled is to be set The frequency protection function features 4 frequency stages f1 to f4 each of which can function as overfrequency stage or underfrequency stage Each zone can be set active or inactive This is set in addresses 3601 O U FREQ f1 for frequency stage f1 3611 O U FREQ f2 for frequency stage f2 3621 O U FREQ f3 for frequency stage f3 3631 O U FREQ ...

Page 345: ...pickup value for frequency stage f1 at fN 50 Hz Address 3603 f1 PICKUP pickup value for frequency stage f1 at fN 60 Hz Address 3604 T f1 trip delay for frequency stage f1 Address 3612 f2 PICKUP pickup value for frequency stage f2 at fN 50 Hz Address 3613 f2 PICKUP pickup value for frequency stage f2 at fN 60 Hz Address 3614 T f2 trip delay for frequency element f2 Address 3622 f3 PICKUP pickup val...

Page 346: ...ettings Addr Parameter Setting Options Default Setting Comments 3601 O U FREQ f1 ON Alarm only ON with Trip OFF ON Alarm only Over Under Frequency Protection stage f1 3602 f1 PICKUP 45 50 54 50 Hz 49 50 Hz f1 Pickup 3603 f1 PICKUP 55 50 64 50 Hz 59 50 Hz f1 Pickup 3604 T f1 0 00 600 00 sec 60 00 sec T f1 Time Delay 3611 O U FREQ f2 ON Alarm only ON with Trip OFF ON Alarm only Over Under Frequency ...

Page 347: ... Frequency protection is ACTIVE 5232 f1 picked up OUT Frequency protection f1 picked up 5233 f2 picked up OUT Frequency protection f2 picked up 5234 f3 picked up OUT Frequency protection f3 picked up 5235 f4 picked up OUT Frequency protection f4 picked up 5236 f1 TRIP OUT Frequency protection f1 TRIP 5237 f2 TRIP OUT Frequency protection f2 TRIP 5238 f3 TRIP OUT Frequency protection f3 TRIP 5239 f...

Page 348: ...ible because of heavily distorted measuring signals or faults outside the protected object When double ended fault locating is used the results of single ended fault locating are output in any case in additional indications The protected object can be an inhomogenous line For calculation purposes the line can be divided into different sections such as a short cable followed by an overhead line In ...

Page 349: ...t locator The double ended fault locator method also considers line capacitance and line resis tance It adapts the fault locating for an optimum matching between the voltages cal culated for the fault locating and the values measured at the line ends It is assumed in this context that voltages on a line cannot leap The voltage at the presumed fault location is calculated once with the values measu...

Page 350: ...length The additional indications always show the results of single ended fault locating Where double ended fault locating is configured the results of single ended fault locating are output in any case in additional indications Rpri single No 1135 Xpri single No 1136 Rsec single No 1137 and Xsec single No 1138 If the double ended fault locator fails they are output as main results in the indi cat...

Page 351: ...be taken into account in order to achieve greater accu racy of the double ended fault locator The asymmetry is estimated on the basis of the phase arrangement You must set the central phase If you do not wish an estimation of the asymmetry it can be switched off The system assumes lines having a high degree of symmetry with respect to the central phase in particular a single level ar rangement Fig...

Page 352: ...the distance calculation For single ended fault location calculation a load compensation feature is provided in the 7SD5 which corrects this measurement inaccuracy Correction for the R compo nent of the fault impedance is not possible but the resultant inaccuracy is not critical since only the X component is critical for the distance to fault indication Load compensation is effective for single ph...

Page 353: ... length in µF km or µF mile For correct indication of the fault lo cation in of line length the correct line length has also to be entered For the double ended fault locator this information is mandatory These setting parameters were already applied with the Power System Data 2 Section 2 1 4 1 at General Line Data A prerequisite for the correct indication of the fault location is furthermore that ...

Page 354: ...bove For setting values please refer to Table 2 15 Table 2 15 Additional line section parameters Addr Setting Title C Setting Options Default Settings Description 6001 S1 Line angle 30 89 ohne 0 85 A1 Line impedance angle 6002 S1 x 1 A 0 0010 1 9000 Ω km ohne 0 0 0300 Ω km A1 Line reactance per unit length x in Ω km 5 A 0 0050 9 5000 Ω km without 0 0 1500 Ω km 1 A 0 0010 3 0000 Ω mi ohne 0 0 0484 ...

Page 355: ...lation 6023 S2 c 1 A 0 000 500 000 µF km 0 0 050 µF km A2 Capacitance per unit length C in µF km 5 A 0 000 100 000 µF km 0 0 010 µF km 1 A 0 000 800 000 µF mi 0 0 080 µF mi A2 Capacitance per unit length C in µF mile 5 A 0 000 160 000 µF mile 0 0 016 µF mile 6024 S2 Line length 0 1 1000 0 km ohne 0 100 0 km A2 Line length in kilome ters 0 1 650 0 Miles ohne 0 62 1 Miles A2 Line length in miles 602...

Page 356: ... ended faulr location 3811 Tmax OUTPUT BCD 0 10 180 00 sec 0 30 sec Maximum output time via BCD No Information Type of In formation Comments 1111 FL active OUT Fault locator active 1113 quality VI Quality of the fault location 1114 Rpri VI Flt Locator primary RESISTANCE 1115 Xpri VI Flt Locator primary REACTANCE 1117 Rsec VI Flt Locator secondary RESISTANCE 1118 Xsec VI Flt Locator secondary REACT...

Page 357: ...CD Fault location 2 1145 BCD d 4 OUT BCD Fault location 4 1146 BCD d 8 OUT BCD Fault location 8 1147 BCD d 10 OUT BCD Fault location 10 1148 BCD d 20 OUT BCD Fault location 20 1149 BCD d 40 OUT BCD Fault location 40 1150 BCD d 80 OUT BCD Fault location 80 1151 BCD d 100 OUT BCD Fault location 100 1152 BCD dist VALID OUT BCD Fault location valid No Information Type of In formation Comments w w w E ...

Page 358: ...e current monitoring stage quickly resets typical 10 ms and stops the timer T BF If the trip command is not carried out breaker failure case current continues to flow and the timer runs to its set limit The breaker failure protection then issues a command to trip the back up breakers and interrupt the fault current The reset time of the feeder protection is not relevant because the breaker failure...

Page 359: ...urrent is reliably detected The currents are monitored and compared with the set threshold Besides the three phase currents two further current detectors are provided in order to allow a plausibility check see Figure 2 145 As plausibility current the earth current residual current IE 3 I0 is preferably used If the residual current from the starpoint of the current transformer set is connected to t...

Page 360: ...terion and avoids overfunctioning due to a defect e g in the auxiliary contact mechanism or circuit This interlock feature is provided for each indi vidual phase as well as for three pole trip It is possible to disable the auxiliary contact criterion If you set the parameter switch Chk BRK CONTACT Figure 2 148 top to NO the breaker failure protection can only be started when current flow is detect...

Page 361: ...reaker failure protection in single channel mode should a separate release criterion not be available The binary input BF release No 1432 must then not be assigned to any physical input of the device during configuration Figure 2 148 shows the operating principle When the trip signal appears from any in ternal or external feeder protection and at least one current flow criterion according to Figur...

Page 362: ...tart L2 and BF Start L3 it is recommended to connect also for example the general device pickup to binary input BF release Figure 2 149 shows this connection 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 BF release must then not be assigned to any physical input of the device durin...

Page 363: ... processed for each individual breaker pole If however the breaker auxiliary contacts are not available for each individual breaker pole then a single pole trip command is assumed to be executed only once the series connection of the normally open NO auxiliary contacts is interrupted This informa tion is provided to the breaker failure protection by the central function control of the device refer...

Page 364: ... after common phase initiation and phase segregated initiation A third time stage can be used for two stage breaker failure protection With single stage breaker failure protection the trip command is routed to the adjacent circuit breakers should the local feeder breaker fail refer to Figure 2 143 or 2 144 The adjacent circuit breakers are those which must trip in order to interrupt the fault curr...

Page 365: ...pole according to Figure 2 153 Figure 2 152 Single stage breaker failure protection with common phase initiation Figure 2 153 Single stage breaker failure protection with different delay timers With two stage breaker failure protection the trip command of the feeder protection is usually repeated after a first time stage to the feeder circuit breaker often via a second trip coil or set of trip coi...

Page 366: ...r protection a separate timer T3 BkrDefective which is normally set to 0 is started Figure 2 155 Thus the adjacent circuit breakers bus bar are tripped imme diately in case the feeder circuit breaker is not operational Figure 2 155 Circuit breaker not operational Transfer Trip to the Remote End Circuit Breaker The device has the facility to provide an additional intertrip signal to the circuit bre...

Page 367: ...t a trip signal to the remote end s of the protected object to clear the fault For this purpose the output command BF EndFlt TRIP No 1495 is available to trigger the inter trip input of the differential protection if applicable together with other commands that need to be transferred This can be achieved by external connection or via CFC The end fault is recognized when the current continues flowi...

Page 368: ...illary functions end fault protection pole dis crepancy supervision can only operate if they were configured as Enabled during configuration of the scope of functions adress 139 BREAKER FAILURE Breaker Failure Protection The breaker failure protection is switched ON or OFF at address 3901 FCT BreakerFail The current threshold I BF address 3902 should be selected such that the protec tion will oper...

Page 369: ...safety margin which allows for any tolerance of the delay timers Figure 2 159 illustrates the timing of a typical breaker failure scenario The dropout time for si nusoidal currents is 15 ms If current transformer saturation is anticipated the time should be set to 25 ms Figure 2 159 Time sequence example for normal clearance of a fault and with circuit breaker failure using two stage breaker failu...

Page 370: ...outed in the event that the breaker is not operational when a feeder protection trip occurs Select that output which is used to trip the adjacent breakers bus bar trip End Fault Protection The end fault protection can be switched separately ON or OFF in address 3921 End Flt stage An end fault is a short circuit between the circuit breaker and the current transformer set of the feeder The end fault...

Page 371: ...y the unsymmetrical position of the circuit breaker poles Conventional values are 2 s to 5 s 2 20 3 Settings The table indicates region specific presettings Column C configuration indicates the corresponding secondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 3901 FCT BreakerFail ON OFF ON Breaker Failure Protection is 3902 I BF 1A 0 05 20...

Page 372: ...2 BkrFail BLOCK OUT Breaker failure is BLOCKED 1453 BkrFail ACTIVE OUT Breaker failure is ACTIVE 1461 BF Start OUT Breaker failure protection started 1472 BF T1 TRIP 1pL1 OUT BF Trip T1 local trip only phase L1 1473 BF T1 TRIP 1pL2 OUT BF Trip T1 local trip only phase L2 1474 BF T1 TRIP 1pL3 OUT BF Trip T1 local trip only phase L3 1476 BF T1 TRIP L123 OUT BF Trip T1 local trip 3pole 1493 BF TRIP C...

Page 373: ...to Alarm Only If this option is set the device only outputs an alarm even if the end temperature is reached The temperature rises are calculated separately for each phase in a thermal replica from the square of the associated phase current This guarantees a true RMS value measurement and also considers the effect of harmonic content A choice can be made whether the maximum calculated overtemperatu...

Page 374: ...n the tripping temperature is reached i e the output function Th O L TRIP is not active K Factor The nominal device current is taken as a basis for overload detection The setting factor k is set under address 4202 K FACTOR It is determined by the relation between the permissible thermal continuous current and this nominal current The permissible continuous current is at the same time the current a...

Page 375: ...etting value K FACTOR 0 80 Time Constant τ The thermal time constant τth is set at address 4203 TIME CONSTANT This is also provided by the manufacturer Please note that the time constant is set in minutes Quite often other values for determining the time constant are stated which can be converted into the time constant as follows 1 s current Permissible current for application time other than 1 s ...

Page 376: ...of minor impor tance If unbalanced overloads are to be expected however these options lead to dif ferent results Averaging should only be used if a rapid thermal equilibrium is possible in the protect ed object e g with belted cables If the three phases are however more or less ther mally isolated e g single conductor cables or overhead lines one of the maximum settings should be chosen at any rat...

Page 377: ...CTIVE 1515 Th O L I Alarm OUT Th Overload Current Alarm I alarm 1516 Th O L Θ Alarm OUT Th Overload Alarm Near Thermal Trip 1517 Th O L Pickup OUT Th Overload Pickup before trip 1521 Th O L TRIP OUT Th Overload TRIP command No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 378: ...ss of the device see for the Technical Data The processor monitors the offset and reference voltage of the ADC analog digital converter The protection is suspended if the voltages deviate outside an allowable range and lengthy deviations are reported Buffer Battery The buffer battery which ensures operation of the internal clock and storage of counters and messages if the auxiliary voltage fails i...

Page 379: ...ance current transformer ΣI THRESHOLD and ΣI FACTOR are setting parameters The component ΣI FACTOR Σ I takes into account the allowable current proportional ratio errors of the input transducers which are particularly prevalent during large fault currents Figure 2 162 Σ I is the sum of all currents Σ I IL1 IL2 IL3 kI IE As soon as a summation current fault is detected after or before a system dist...

Page 380: ...tage input of the relay Voltage sum monitoring can operate properly only if the adaptation factor Uph Udelta at address 211 has been correctly configured see Section 2 1 2 1 Figure 2 163 Voltage sum monitoring 2 22 1 2 Software Monitoring Watchdog For continuous monitoring of the program sequences a time monitor is provided in the hardware watchdog for hardware that expires upon failure of the pro...

Page 381: ...hile the limit value BALANCE I LIMIT is the lower limit of the operating range of this monitoring see Figure 2 164 Both parameters can be set The dropout ratio is about 97 After a settable time 5 100 s this malfunction is signalled as Fail I balance No 163 Figure 2 164 Current symmetry monitoring VoltageSymmetry During normal system operation i e the absence of a short circuit fault symmetry among...

Page 382: ...o the affected phase The blocking is cancelled as soon as the device is again supplied with current in the relevant phase It is also suppressed as long as a high fault current is registered by any device of the differential protection system Note that electronic test devices do not simulate the correct behaviour of broken wire so that pickup may occur Note Broken wire monitoring can operate proper...

Page 383: ...re no reliable criterion since a considerable zero sequence voltage occurs also in case of a simple earth fault where a significant zero sequence current does not necessarily flow Therefore the zero sequence voltage is not evaluated in such networks but only the negative se quence voltage parameter SystemStarpoint As soon as this state is recognized the distance protection and all other functions ...

Page 384: ...riterion A three pole voltage failure is detected if All three phase to earth voltages are smaller than the threshold FFM U max 3ph The current differential in all three phases is smaller than the threshold FFM Idelta 3p All three phase current amplitudes are greater than the minimum current Iph for impedance measurement by the distance protection If no stored current values are present yet the cu...

Page 385: ...dditional monitoring function Where circuit breaker auxiliary con tacts are used they should be used for monitoring as well Figure 2 167 shows the logic diagram of the measured voltage failure monitoring A failure of the measured voltage is detected if the following conditions are met at the same time All three phase to earth voltages are smaller than FFM U max 3ph At least one phase current is la...

Page 386: ...vice is also taken out of service The operational readiness NC contact life contact operates to indicate the device is malfunctioning 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 fails then all LEDs are dark Table 2 16 shows a summary of the monitoring functions and the malfunct...

Page 387: ...out of opera tion Error1A 5Awrong 192 Error A D conv 181 LED ERROR DOK2 drops out Calibration data Internal EEPROM or RAM Indication Using default values Alarm adjustm 193 As allocated Earth current transform er sensitive insensitivity I O BG does not comply with the order number MLFB of the device Indications Protection out of opera tion Error neutralCT 194 Error A D conv 181 LED ERROR DOK2 drops...

Page 388: ... infeed tripping is blocked Frequency protection is blocked and Direction determination of the earth fault protec tion is blocked VT FuseFail 10s 169 VT FuseFail 170 As allocated Voltage failure single and two phase Fuse Failure Monitor External voltage transform ers Indication Distance protection is blocked Undervoltageprotection is blocked Weak infeed tripping is blocked Frequency protection is ...

Page 389: ...toring is not activated Asymmetrical Mea suring Voltage Failure Fuse FailureMonitor The settings of the fuse failure monitor for asymmetrical measured voltage failure must be selected such that on the other hand reliable pickup of the monitoring is ensured in the case of loss of a single phase voltage address 2911 FFM U min while on the other hand a pickup due to earth faults in an earthed system ...

Page 390: ... Column C configuration indicates the corresponding secondary nominal current of the current transformer Addr Parameter C Setting Options Default Setting Comments 2901 MEASURE SUPERV ON OFF ON Measurement Supervision 2902A BALANCE U LIMIT 10 100 V 50 V Voltage Threshold for Balance Monitoring 2903A BAL FACTOR U 0 58 0 95 0 75 Balance Factor for Voltage Monitor 2904A BALANCE I LIMIT 1A 0 10 1 00 A ...

Page 391: ...on 2921 T mcb 0 30 ms 0 ms VT mcb operating time 2931 BROKEN WIRE ON OFF OFF Fast broken current wire supervision 2933 FAST Σ i SUPERV ON OFF ON State of fast current sum mation supervis No Information Type of In formation Comments 161 Fail I Superv OUT Failure General Current Supervision 163 Fail I balance OUT Failure Current Balance 164 Fail U Superv OUT Failure General Voltage Supervision 165 F...

Page 392: ...s Supervision with binary inputs not only detects interruptions in the trip circuit and loss of control voltage it also supervises the response of the circuit breaker using the po sition of the circuit breaker auxiliary contacts Depending on the conditions of the trip contact and the circuit breaker the binary inputs are activated logical condition H in the following table or short circuited log i...

Page 393: ...on with One Binary Input The binary input is connected in parallel to the respective command relay contact of the protection device according to Figure 2 170 The circuit breaker auxiliary contact is bridged with a high ohm equivalent resistor R The control voltage for the circuit breaker should be at least twice as high as the minimum voltage drop at the binary input UCtrl 2 UBImin Since at least ...

Page 394: ...ical condition L If the binary input is permanently deactivated during operation an interruption in the trip circuit or a failure of the trip control voltage can be assumed The trip circuit supervision does not operate during system faults A momentary closed tripping contact does not lead to a failure indication If however other trip relay con tacts from different devices are connected in parallel...

Page 395: ...upervision does not operate during a system fault If however trip contacts from other devices are connected in parallel in the trip circuit the alarm must be delayed such that the longest trip command duration can be reliably bridged 2 22 2 3 Settings 2 22 2 4 Information List Addr Parameter Setting Options Default Setting Comments 4001 FCT TripSuperv ON OFF OFF TRIP Circuit Supervision is 4002 No...

Page 396: ...g a manual closure onto a short circuit immediate trip of the circuit breaker is usually required This is done e g in the overcurrent protection by bypass ing the delay time of specific stages For every short circuit protection function which can be delayed at least one stage can be selected that will operate instantaneously in the event of a manual closing as mentioned in the relevant sections Al...

Page 397: ... logic of the 7SD5 automatically distinguishes between an external control command via the binary input and an automatic reclosure by the internal automatic reclosure so that the binary input Manual Close can be connected directly to the control circuit of the close coil of the circuit breaker Figure 2 173 Each reclosure that is not initiated by the internal automatic reclosure function is interpr...

Page 398: ...re available as measuring quantities A flowing current excludes that the circuit breaker is open exception a fault between current transformer and circuit breaker If the circuit breaker is closed it may however still occur that no current is flowing The voltages can only be used as a criterion for the de energized line if the voltage transformers are installed on the feeder side Therefore the devi...

Page 399: ... trip command after an energization the fast switch on to fault protection is released selectively for each phase already when the line is open In order to avoid that an energization is detected mistakenly the state line open which precedes any energization must apply for at least 250 ms 2 23 1 2 Detection of the Circuit Breaker Position For Protection Purposes Information regarding the circuit br...

Page 400: ...s case If the circuit breaker can be switched individually two binary inputs are sufficient if both the parallel as well as series connection of the auxiliary contacts of the three poles are available In this case the parallel connection of the auxiliary contacts is routed to the input function CB 3p Closed No 379 and the series connection is routed to the input function CB 3p Open No 380 Please n...

Page 401: ...circuit check with the help of the TRIP CLOSE test cycle refer to Section 2 23 2 When using 11 2 or 2 circuit breakers in each feeder the automatic reclosure function and the circuit breaker test are referred to one circuit breaker The feedback informa tion of this circuit breaker can be connected separately to the device For this separate binary inputs are available which should be treated the sa...

Page 402: ...ole L1 CB1 Pole L2 No 367 for the auxiliary contact of pole L2 CB1 Pole L3 No 368 for the auxiliary contact of pole L3 2 23 1 3 Open Pole Detector Single pole dead times can be detected and reported via the Open Pole Detector The corresponding protection and monitoring functions can respond The following figure shows the logic structure of an Open Pole Detector Figure 2 177 Logic diagram of the Op...

Page 403: ...messages to a personal comput er or a centralized control system several protection functions provide the possibility to display the faulted phase information in a single annunciation e g Diff Flt L12E or Dis Pickup L12E for fault detection in L1 L2 E Only one such annun ciation appears which represents the complete definition of the fault detection General Pickup The pickup signals are combined w...

Page 404: ...aults with or without earth three pole tripping is usually carried out Device prerequisites for phase segregated tripping are Phase segregated tripping is provided by the device according to the ordering code The tripping protection function is suitable for pole segregated tripping for exam ple not for frequency protection overvoltage protection or overload protection The binary input 1p Trip Perm...

Page 405: ...this fault can be cleared by single pole trip and automatic reclosure in one of the faulted phases as the short circuit path is inter rupted in this manner The phase selected for tripping must be the same at both line ends and should be the same for the entire system The setting parameter Trip2phFlt address 1156 allows to select whether this trip ping should be 1pole leading Ø i e single pole trip...

Page 406: ...the trip command is that the circuit breaker has opened in the event of single pole tripping the relevant circuit breaker pole In the function control of the device this is checked by means of the circuit breaker position feedback Section Detection of the Circuit Breaker Position and the flow of current The residual current PoleOpenCurrent that is certainly undershot when the circuit breaker pole ...

Page 407: ...ld activate reclosing lock out Please bear in mind that the message Final Trip No 536 applies only for 500 ms Then combine the output alarm Final Trip No 536 with the interlocking input Lockout SET so that the interlocking function is not established when an automatic reclosure is still expected to come In the most simple case the output alarm LOCKOUT No 530 can be allocated to the output which tr...

Page 408: ...n the ready state the contact is opened so that no signal from the circuit breaker is forwarded This is only the case if the device is equipped with internal automatic reclosure and if the latter was taken into consideration when configuring the protection functions address 133 Also when closing the breaker via the binary input Manual Close No 356 or via the integrated automatic reclosure the cont...

Page 409: ... hand allows for single pole tripping The output alarms mentioned must be allocated to the relevant command relays that are used for controlling the circuit breaker coils The test is started using the operator panel on the front of the device or using the PC with DIGSI The procedure is described in detail in the SIPROTEC 4 System De scription Figure 2 182 shows the chronological sequence of one TR...

Page 410: ...IP CLOSE cycle phase L3 CB1 TESTtrip L3 7327 4 3 pole TRIP CLOSE cycle CB1 TESTtrip 123 7328 Associated close command CB1 TEST CLOSE 7329 No Information Type of In formation Comments CB1tst L1 CB1 TEST trip close Only L1 CB1tst L2 CB1 TEST trip close Only L2 CB1tst L3 CB1 TEST trip close Only L3 CB1tst 123 CB1 TEST trip close Phases L123 7325 CB1 TESTtrip L1 OUT CB1 TEST TRIP command Only L1 7326 ...

Page 411: ...D and LCD messages 2 23 3 2 Spontaneous Indications on the Display You can determine whether or not the most important data of a fault event is displayed automatically after the fault has occurred see also Fault indications in Section 2 24 2 Ancillary Functions 2 23 3 3 Switching Statistics The number of trips caused by the device 7SD5 is counted If the device is capable of single pole tripping a ...

Page 412: ...s on the device front to select the different represenations of the measured values for the so called default display The start page of the default display which is displayed by default after startup of the device can be selected via parameter 640 Start image DD The available representation types for the mea sured values are listed in the appendix 2 23 3 5 Settings 2 23 3 6 Information List Addr P...

Page 413: ...t OUT Flag Lost 125 Chatter ON OUT Chatter ON 126 ProtON OFF IntSP Protection ON OFF via system port 128 TelepONoff IntSP Teleprot ON OFF via system port 140 Error Sum Alarm OUT Error with a summary alarm 144 Error 5V OUT Error 5V 160 Alarm Sum Event OUT Alarm Summary Event 177 Fail Battery OUT Failure Battery empty 181 Error A D conv OUT Error A D converter 182 Alarm Clock OUT Alarm Real Time Clo...

Page 414: ...on that can also be deactivat ed by the settings The actual operation of the device can be now simulated with the mouse pointer This possibility can be disabled IBS Tool The IBS Tool is a comprehensive commissioning and visualization tool which enables the user to chart the communication and the most important measurement data of the complete differential protection system on a PC screen by means ...

Page 415: ... differential protection system should be operated with the IBS Tool from the PC When setting YES the devices cannot be operated by the front panel emulation of the PC This is the normal state during operation Once this address is set to NO during commissioning all device parameters can be changed to correct for example false or inconsistent set tings In address 4406 LCP NCP set if your PC interfa...

Page 416: ...figuration procedure The output relays and the LEDs may be operated in a latched or unlatched mode each may be individually set Addr Parameter Setting Options Default Setting Comments 4401 IP A A x x x 0 255 141 IP address xxx xxx xxx Posi tion 1 3 4402 IP B x B x x 0 255 142 IP address xxx xxx xxx Posi tion 4 6 4403 IP C x x C x 0 255 255 IP address xxx xxx xxx Posi tion 7 9 4404 IP D x x x D 0 2...

Page 417: ...sked to it Information via DisplayPanelorPC Events and conditions can be read out on the display on the front panel of the relay Using the front operator interface or the rear service interface for instance a personal computer can be connected to which the information can be sent In the quiescent state i e as long as no system fault is present the LCD can display selectable operational information...

Page 418: ...s with the convenience of visualization on a monitor and a menu guided dialog The data may either be printed or stored for evaluation at a later time and place Information to a ControlCentre If the device has a serial system interface stored information may additionally be transferred via this interface to a centralized control and storage device Several com munication protocols are available for ...

Page 419: ...umber The fault indications contain de tailed information on the behaviour of the power system fault Fault Indications Following a system fault it is possible for example to retrieve important information regarding its progress such as pickup and trip The time the initial occurrence of the short circuit fault occurred is accurately provided via the system clock The progress of the disturbance is o...

Page 420: ...last eight network faults can be retrieved and output In total 600 indications can be recorded Oldest indications are erased for newest fault indications when the buffer is full Spontaneous Indications Spontaneous indications contain information that new indications have arrived Each new incoming indication appears immediately i e the user does not have to wait for an update or initiate one This c...

Page 421: ...older The avail ability of the transmission media is also reported The availability is indicated in min and h This enables an evaluation of the transmission quality If GPS synchronization is configured the transmission times for each direction and each protection data interface are regularly measured and indicated as long as GPS synchronization is intact 2 24 3 2 Information List No Information Ty...

Page 422: ...lity per hour 7875 PI1 TD R MV Prot Interface 1 Transmission delay rec 7876 PI1 TD S MV Prot Interface 1 Transmission delay send 7877 PI2 TD R MV Prot Interface 2 Transmission delay rec 7878 PI2 TD S MV Prot Interface 2 Transmission delay send No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 423: ...erconnected via their protection data interfaces a common frequency value is calculated across the whole constellation constellation frequency This value is displayed as the operational measured value Frequency It allows to display a frequency even in devices in which local frequency measurement is not pos sible The constellation frequency is also used by the differential protection for syn chroni...

Page 424: ... angle of the phase voltages towards the phase currents U1 U2 Positive and negative sequence com ponent of the voltages kV V Nominal operational voltage 3 2 UX UEN Voltage at measuring input U4 V U1compound Positive sequence component of volt ages at the remote end if compound ing is active in voltage protection kV V Operational rated voltage 3 2 RL1 E RL2 E RL3 E RL1 L2 RL1 L2 RL3 L1 Operational ...

Page 425: ...T 634 U1 MV U1 positive sequence 635 U2 MV U2 negative sequence 636 Udiff MV U diff line bus 637 Uline MV U line 638 Ubus MV U bus 641 P MV P active power 642 Q MV Q reactive power 643 PF MV Power Factor 644 Freq MV Frequency 645 S MV S apparent power 646 F bus MV Frequency busbar 647 F diff MV Frequency difference line bus 648 ϕ diff MV Angle difference line bus 649 F line MV Frequency line 679 U...

Page 426: ... 7731 Φ IL1L2 MV PHI IL1L2 local 7732 Φ IL2L3 MV PHI IL2L3 local 7733 Φ IL3L1 MV PHI IL3L1 local 7734 Φ UL1L2 MV PHI UL1L2 local 7735 Φ UL2L3 MV PHI UL2L3 local 7736 Φ UL3L1 MV PHI UL3L1 local 7737 Φ UIL1 MV PHI UIL1 local 7738 Φ UIL2 MV PHI UIL2 local 7739 Φ UIL3 MV PHI UIL3 local No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 427: ... the three phases Nominal operationalcurrent 1 IRestL1 IRestL2 IRestL3 Calculated restraint currents of the three phases Nominal operationalcurrent 1 IDiff 3I0 Calculated differential current of the zero sequence system Nominal operationalcurrent 1 IcL1 IcL2 IcL3 Measured charging currents of the three phases Nominal operational current No Information Type of In formation Comments 7742 IDiffL1 MV ...

Page 428: ...2 Operational measured values transmitted from the other ends and compared with the local values 1 for lines according to address 1104 2 according to address 1103 The information overviews below show you which information is available for each device Data Primary value Device ADR Device address of the remote device absolute IL1 IL2 IL3 remote Phase currents of the remote device Nominal operational...

Page 429: ...d memory is approx 15 s The fault recording buffer is updated when a new fault occurs so that acknowledging is not necessary In addition to storage of the fault recording by the pro tection fault detection this may also be initiated via binary input the integrated keypad and display or via the serial operator or service interface For the differential protection system of a protected object all fau...

Page 430: ...e g fault detection tripping are also represent ed Where transfer to a central device is possible the request for data transfer can be ex ecuted automatically It can be selected to take place after each fault detection by the protection or only after a trip 2 24 8 2 Settings Addresses which have an appended A can only be changed with DIGSI under Ad ditional Settings 2 24 8 3 Information List Addr ...

Page 431: ...inputs or by using the inte grated control panel in the DIGSI operating program 2 24 9 2 Settings 2 24 9 3 Information List Addr Parameter 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 ...

Page 432: ... formation Comments ResMinMax IntSP_Ev Reset Minimum and Maximum counter 395 I MinMax Reset SP I MIN MAX Buffer Reset 396 I1 MiMaReset SP I1 MIN MAX Buffer Reset 397 U MiMaReset SP U MIN MAX Buffer Reset 398 UphphMiMaRes SP Uphph MIN MAX Buffer Reset 399 U1 MiMa Reset SP U1 MIN MAX Buffer Reset 400 P MiMa Reset SP P MIN MAX Buffer Reset 401 S MiMa Reset SP S MIN MAX Buffer Reset 402 Q MiMa Reset S...

Page 433: ... U L12 Maximum 868 UL23Min MVT U L23 Minimum 869 UL23Max MVT U L23 Maximum 870 UL31Min MVT U L31 Minimum 871 UL31Min MVT U L31 Maximum 874 U1 Min MVT U1 positive sequence Voltage Minimum 875 U1 Max MVT U1 positive sequence Voltage Maximum 880 SMin MVT Apparent Power Minimum 881 SMax MVT Apparent Power Maximum 882 fMin MVT Frequency Minimum 883 fMax MVT Frequency Maximum 1040 Pmin Forw MVT Active P...

Page 434: ...alue Monitoring Set points can be set for the following measured and metered values IL1dmd Exceeding a preset maximum average value in Phase L1 IL2dmd Exceeding a preset maximum average value in Phase L2 IL3dmd Exceeding a preset maximum average value in Phase L3 I1dmd Exceeding a preset maximum average value of the positive sequence system currents Pdmd Exceeding a preset maximum average active p...

Page 435: ...T Set Point Sdmd 285 cosϕ alarm OUT Power factor alarm No Information Type of In formation Comments Meter res IntSP_Ev Reset meter 888 Wp puls PMV Pulsed Energy Wp active 889 Wq puls PMV Pulsed Energy Wq reactive 916 Wp Increment of active energy 917 Wq Increment of reactive energy 924 Wp MVMV Wp Forward 925 Wq MVMV Wq Forward 928 Wp MVMV Wp Reverse 929 Wq MVMV Wq Reverse No Information Type of In...

Page 436: ... described in the SIPROTEC 4 System De scription under Control of Switchgear 2 25 1 Control Authorization 2 25 1 1 Command Types Commands to the System This type of commands are directly output to the switchgear to change their process state Commands for the operation of circuit breakers asynchronous or synchronized through integration of the synchronism check and closing control function as well ...

Page 437: ...ng mode interlocking activated deactivated selection of deac tivated interlocking status User configurable interlocking checks Switching authority Device position check set vs actual comparison Zone controlled bay interlocking logic using CFC System interlocking centrally via SICAM Double operation interlocking against parallel switching operation Protection blocking blocking of switching operatio...

Page 438: ...control system are as signed to a specific parameter inside the bay unit via configuration matrix For all commands operation with interlocking normal mode or without interlocking test mode can be selected For local commands by reprogramming the settings with password check For automatic commands via command processing by CFC and Deactivated Inter locking Recognition For local remote commands using...

Page 439: ... internal commands such as over riding or abort are not tested i e are executed independently of the interlockings Figure 2 188 Example of an operational indication for switching circuit breaker 52 Standard Interlock ing The standard interlocking includes the checks for each switchgear which were set during the configuration of inputs and outputs see SIPROTEC 4 System Description An overview for p...

Page 440: ...The are marked by letters ex plained in Table 2 25 Table 2 25 Interlocking Commands Figure 2 190 shows all interlocking conditions which usually appear in the display of the device for three switchgear items with the relevant abbreviations explained in Table 2 25 All parametrized interlocking conditions are shown Interlocking Commands Command Display Switching Authority L L System Interlocking S S...

Page 441: ...trol Authority ModeLOCAL IntSP Controlmode LOCAL No Information Type of In formation Comments Breaker CF_D12 Breaker Breaker DP Breaker Disc Swit CF_D2 Disconnect Switch Disc Swit DP Disconnect Switch EarthSwit CF_D2 Earth Switch EarthSwit DP Earth Switch 52 Open IntSP Interlocking 52 Open 52 Close IntSP Interlocking 52 Close Disc Open IntSP Interlocking Disconnect switch Open Disc Close IntSP Int...

Page 442: ... with the local command but by ordinary command and feedback in formation recording Feedback Monitor ing Command processing time monitors all commands with feedback Parallel to the com mand a monitoring time period command runtime monitoring is started which checks whether the switchgear has achieved the desired final state within this period The monitoring time is stopped as soon as the feedback ...

Page 443: ...age ErrCntrlU SP Error Control Voltage SF6 Loss SP SF6 Loss Err Meter SP Error Meter Tx Temp SP Transformer Temperature Tx Danger SP Transformer Danger No Information Type of In formation Comments SysIntErr IntSP Error Systeminterface No Information Type of In formation Comments w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 444: ...2 Functions 444 7SD5 Manual C53000 G1176 C169 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 445: ...gement of power systems and with the relevant safety rules and guidelines Under certain cir cumstances particular power system adaptations of the hardware are necessary Some of the primary tests require the protected line or equipment to carry load 3 1 Mounting and Connections 446 3 2 Checking Connections 471 3 3 Commissioning 477 3 4 Final Preparation of the Device 516 w w w E l e c t r i c a l P...

Page 446: ... provided in Appendix A 3 It must be checked that the setting of the P System Data 1 Section 2 1 2 1 was made in ac cordance to the device connections Currents In Appendix A 3 examples for the possibilities of the current transformer connections in dependence on network conditions are displayed For normal connection address 220 I4 transformer In prot line must be set and furthermore address 221 I4...

Page 447: ...ding values If there is a power transformer between the set of busbar and the feeder VT s the phase displacement of the voltages caused by the transformer must be considered for the synchronism check if used In this case also check the addresses 212 Usync connect 214 ϕ Usync Uline and 215 U line Usync You will find detailed hints and an example in Section 2 1 2 1 under Voltage Transformer Connecti...

Page 448: ...on these binary inputs must be isolated i o w not be communed with each other or with another binary input If one binary input is used a bypass resistor R must be used refer to Figure 3 2 This resistor R is connected in series with the second circuit breaker auxiliary contact Aux2 to also allow the detection of a trip circuit failure when the circuit breaker aux iliary contact 1 Aux1 is open and t...

Page 449: ...at Rmax Rmin then the calculation must be repeated with the next lowest switching threshold UBI min and this threshold must be implemented in the relay using plug in jumpers see Section Hardware Modifications IBI HIGH Constant current with activated BI 1 8 mA UBI min Minimum control voltage for BI 19 V for delivery setting for nominal voltages of 24 48 60 250 V 88 V for delivery setting for nomina...

Page 450: ... the binary inputs it may be necessary to addi tionally burden the pilot wire loop with an external shunt connected resistor so that the binary inputs are not blocked by the charge of the pilot wire after an interruption of the loop As an alternative auxiliary relay combinations e g 7PA5210 2A can be intro duced Pilot wires used as cable connections between stations must always be checked on their...

Page 451: ...re carried out AuxiliaryVoltage There are different power supply voltage ranges for the auxiliary voltage refer to the Ordering Information in Appendix A 1 The power supplies of the variants for 60 110 125 VDC and 110 125 220 VDC 115 VAC are largely interchangeable by mod ifying the position of the jumpers The assignment of these jumpers to the nominal voltage ranges and the spatial layout on the ...

Page 452: ...on Printed Circuit Boards explain for which relays on which boards this applies Exchanging Interfaces Only serial interfaces of devices for panel flush and cubicle mounting as well as of mounting devices with detached operator panel are replaceable In the following section under margin heading Exchanging Interface Modules it is described which interfaces can be exchanged and how this is done Termi...

Page 453: ...ing switching elements or exchanging modules proceed as follows Prepare your workplace prepare a suitable underlay for electrostatically sensitive devices ESD Also the following tools are required screwdriver with a 5 to 6 mm wide tip a crosstip screwdriver for Pz size 1 a 5 mm socket wrench Unfasten the screw posts of the D subminiature connectors on the back panel at location A This activity doe...

Page 454: ...part the top and bottom latches at the plug connector so that the ribbon cable con nector is pressed out Disconnect the ribbon cables between the processor board C CPU 1 No 1 in Figure 3 3 or 3 4 and the input output board I O according to order variant No 2 to No 3 in Figure 3 3 or 3 4 Remove the boards and place them on a surface suitable for electrostatically sen sitive devices ESD In the case ...

Page 455: ...nput output board C I O 1 No 2 in Figure 3 3 slot 19 for housing size 1 2 On the input output board C I O 1 No 2 in Figure 3 4 slot 33 left for housing size 1 1 The preset nominal voltage of the integrated power supply is checked according to Table 3 2 the quiescent state of the life contact is checked according to Table 3 3 Table 3 2 Jumper setting for the nominal voltage of the integrated Power ...

Page 456: ... and command acceleration this is valid for the binary output BO24 Figure 3 4 slot 19 left Table 3 4 shows the jumper settings for the contact mode Table 3 4 Jumper settings for contact mode of the binary outputs BO16 and BO24 on the input output board C I O 1 Interchangeable Cannot be changed Fuse T2H250V T4H250V Jumper Open in Quiescent State NO Closed in Quiescent State NC Factory Setting X40 1...

Page 457: ...Connections 457 7SD5 Manual C53000 G1176 C169 1 Figure 3 5 Input output board C I O 1 with representation of the jumper settings required for the board configuration w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 458: ...O 10 with representation of the jumper settings required for the board configuration Checking the control voltages of the binary inputs BI1 to BI8 with housing size 1 2 according to Table3 5 BI1 to BI24 with housing size 1 1 according to Table3 6 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 459: ...110 VDC to 250 VDC and 115 VAC 3 Factory settings for devices with power supply voltages of 220 VDC to 250 VDC and 115 VAC Table 3 7 Jumper settings of the Board Address of the input output board C I O 1 or C I O 10 with housing size 1 1 binary inputs slot 19 Jumper 19 V Threshold 1 88 V Threshold 2 176 V Threshold 3 BI1 X21 X22 L M H BI2 X23 X24 L M H BI3 X25 X26 L M H BI4 X27 X28 L M H BI5 X29 X...

Page 460: ...tings The contact of the relay for the binary output BO13 can be configured as NO or NC contact see also General Diagrams in Appendix A Section A 2 with housing size 1 2 No 3 in Figure 3 3 slot 33 with housing size 1 1 No 3 in Figure 3 4 slot 33 right Table 3 8 Jumper setting for contact type of binary output BO13 Jumper Open in Quiescent State NO Closed in Quiescent State NC Factory Setting X41 1...

Page 461: ...ive earth fault current input input transformer T8 there is no jumper X64 Jumpers X71 X72 and X73 on the input output board C I O 2 are used to set the bus address and must not be changed The following table lists the jumper presettings Mounting location with housing size 1 2 No 3 in Figure 3 3 slot 33 with housing size 1 1 No 3 in Figure 3 4 slot 33 right Table 3 9 Jumper settings of Board Addres...

Page 462: ...3 4 Figure 3 8 Processor board C CPU 1 with interface modules maximum configuration Note Surface mounted devices with fibre optics connection have their fibre optics module fitted in the inclined housing on the case bottom The CPU module has there instead an RS232 interface module which communicates electrically with the FO module in the inclined housing w w w E l e c t r i c a l P a r t M a n u a...

Page 463: ... the C CPU 1 with the layout of the boards The following figure shows the location of the jumpers of interface RS232 on the inter face module Devices in surface mounting housing with fibre optics connection have their fibre optics module housed in the console housing The fibre optics module is controlled via an RS232 interface module at the associated CPU interface slot For this application type t...

Page 464: ... 7XV5100 4 Jumper Setting 1 2 This setting makes the modem signals available i e for a direct RS232 connection between the SIPROTEC 4 device and the modem this setting can be selected optionally We recommend to use a standard RS232 modem connection cable converter 9 pin to 25 pin Note For a direct connection to DIGSI with Interface RS232 jumper X11 must be plugged in position 2 3 RS485 Interface T...

Page 465: ... No 1 in Figure 3 3 and 3 4 Figure 3 8 shows the PCB of the C CPU 1 with the layout of the modules The board with configuration as RS485 interface is shown in Figure 3 10 the module for the PROFIBUS interface in Figure 3 11 For the configuration of the terminating resistors both jumpers have to be plugged in the same way On delivery the jumpers are set so that the terminating resistors are disconn...

Page 466: ... housing size 1 1 as indicated in Figure 3 14 Remove the 4 covers at the corners of the front cover for housing size 1 1 the two covers located centrally at the top and bottom also have to be removed The 4 or 6 elongated holes in the mounting bracket are revealed and can be accessed Insert the device into the panel cut out and fasten it with four or six screws For di mensions refer to Section 4 25...

Page 467: ...7 7SD5 Manual C53000 G1176 C169 1 Figure 3 13 Example of panel flush mounting of a device housing size 1 2 Figure 3 14 Example of panel flush mounting of a device housing size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 468: ...en fast the eight screws of the angle brackets in the rack or cabinet Screw down a robust low ohmic protective earth or station earth to the rear of the device using at least an M4 screw The cross sectional area of the earth wire must be equal to the cross sectional area of any other conductor connected to the device The cross section of the earth wire must be at least 2 5 mm2 Connections use the ...

Page 469: ...D5 Manual C53000 G1176 C169 1 Figure 3 15 Example of rack or cubicle mounting of a device housing size 1 2 Figure 3 16 Example of rack or cubicle mounting of a device housing size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 470: ...ce The cross section of the earth wire must be at least 2 5 mm2 Connect solid low impedance operational earthing cross sectional area 2 5 mm2 to the earthing surface on the side Use at least one M4 screw for the device earth Make the connections according to the circuit diagram via the screwed type termi nals Fibre optic cables and electrical communication modules are connected at the inclined hou...

Page 471: ...the PC or Laptop is automatically ensured Service Interface Check the data connection if the service interface Interface C for communicating with the device is via fix wiring or a modem SystemInterface For versions equipped with a serial interface to a control center the user must check the data connection The visual check of the assignment of the transmission and re ception channels is of particu...

Page 472: ...tors can also be imple mented outside the device e g in the plug connectors as shown in Figure 3 12 In this case the terminating resistors located on the module must be disabled If the bus is extended make sure again that only terminating resistors at the last device to the bus are switched in Time Synchroniza tionInterface It is optionally possible to process 5V 12V or 24V time synchronization si...

Page 473: ... from device to device via optical fibres or via communication converters and a communication network or a dedicated transmission medium Optical Fibres Directly WARNING Warning of laser rays Non observance of the following measure can result in death personal injury or sub stantial property damage Do not look directly into the fibre optic elements not even with optical devices Laser Class 3A accor...

Page 474: ...attery charger without a battery Non observance of the following measure can lead to unusually high voltages and consequently the destruction of the device Do not operate the device on a battery charger without a connected battery For limit values see also Technical Data Section 4 1 Before the device is energized for the first time it should be in the final operating en vironment for at least 2 ho...

Page 475: ...sert the I O module Carefully connect the ribbon cable Be careful not to bend connecting pins Do not apply force At the terminals of the device again check continuity for each pair of terminals that receives current from the CTs Attach the front panel and tighten the screws Connect an ammeter in the supply circuit of the power supply A range of about 2 5 A to 5 A for the meter is appropriate Switc...

Page 476: ...vice ready relay DOK Device Ok picks up This also signalizes that the clock pulse of the communication network is recognized Further checks are performed according to Section Checking the Protection Data Topology Please also observe carefully the documentation on the communication converters w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 477: ...moving voltage from the power supply wait a minimum of 10 seconds before re energizing the power supply This wait allows the initial conditions to be firmly es tablished before the device is re energized The limit values given in Technical Data must not be exceeded neither during testing nor during commissioning For tests with a secondary test equipment ensure that no other measurement voltages ar...

Page 478: ...ge to be recognized as resulting from testing and not an actual fault or power system event Furthermore it can be determined by activating the Transmission block that no annunciations at all are transmitted via the system interface during a test mode The SIPROTEC 4 System Description describes how to activate and deactivate test mode and blocked data transmission Note that when DIGSI is being used...

Page 479: ... or disconnectors is to be checked only during commissioning Do not under any circumstances check them by means of the testing mode during real operation performing transmission and recep tion of messages via the system interface Note After termination of this test the device will reboot Thereby all indication buffers are erased If required these buffers should be extracted with DIGSI prior to the...

Page 480: ...h appears Make sure that each checking process is carried out carefully without causing any danger see above and refer to DANGER Click Send in the function to be tested and check whether the corresponding infor mation reaches the control center and possibly shows the expected effect Data which are normally linked via binary inputs first character are likewise indicated to the control center with t...

Page 481: ...ice will reboot Thereby all annunciation buffers are erased If required these buffers should be extracted with DIGSI prior to the test The hardware test can be carried out using DIGSI in the Online operating mode Open the Online directory by double clicking the operating functions for the device appear Click on Test the function selection appears in the right half of the window Double click in the...

Page 482: ...s are separated from the internal device func tions and can only be operated by the hardware test function This means for exam ple a TRIP command coming from a protection function or a control command from the operator panel to an output relay cannot be executed Proceed as follows in order to check the output relay Make sure that the switching operations caused by the output relays can be execut e...

Page 483: ...er to the other input output components As soon as the first state change of any LED has been triggered all LEDs are separated from the internal device functionality and can only be controlled via the hardware test function This means e g that no LED is illuminated anymore by a protection function or by pressing the LED reset button Updating the Display When the dialog box Hardware Test is opened ...

Page 484: ...xample in Figure 3 22 If you use the WEB Monitor Make sure that the 12 digit IP address valid for the browser is set correctly in the format A three digit block of the IP address is inserted into each address from 4401 to 4404 or 4411 to 4414 Set the address 4405 or 4415 NUM LOCK toNO if you are directly interfaced to the device You will then have the option to operate the device with the WEB Moni...

Page 485: ...e of an incorrect communication link the message PI1 Data fault No 3229 or PI2 Data fault No 3231 will appear In this case recheck the fibre optical cable link Have the devices been linked correctly and no cables been mixed up Are the cables free from mechanical damage intact and the connectors locked Otherwise repeat check Continue with the margin heading Consistency of Topology and Parameterizat...

Page 486: ...t transmitter clock to the communication converter Change the interface parameters at the 7SD5 at the device front or via DIGSI Address 4502 CONNEC 1 OVER F optic direct when you are testing pro tection data interface 1 Address 4602 CONNEC 2 OVER F optic direct when you are testing pro tection data interface 2 Check the Event Log or spontaneous annunciations Message 3217 PI1 Data reflec Protection...

Page 487: ...device index of the other device if interface 1 is applying Message No 3244 PI2 with protection data interface 2 linked with fol lowed by the device index of the other device if interface 2 is applying If the devices are at least connected once the message No 3458 Chaintopology will appear If no other devices are involved in the topology as an entity the message No 3464 Topol complete will then be...

Page 488: ...all other cases the mean value for both directions will be indicated No 7751 PI1 TD indicates the transmission time via protection data interface 1 No 7752 PI2 TD indicates the transmission time via protection data interface 2 Checking Further Links If more than two devices have been linked that is if the object to be protected has more than two ends or if two devices have been linked via both pro...

Page 489: ...ology The devices have been properly linked green shaded squares and work as differential protection status Differential Mode The PC has been interfaced to the device with index 2 PC connected relay Figure 3 25 illustrates the interface data of a 7SD5 with GPS synchronization as an example The PC has been interfaced to the device with index 3 PC connected relay The transmission between device 2 an...

Page 490: ...s the feeder which is to be tested i e line disconnectors and busbar disconnectors should be open so that the breaker can be operated without risk Caution Also for tests on the local circuit breaker of the feeder a trip command to the surround ing circuit breakers can be issued for the busbar Non observance of the following measure can result in minor personal injury or prop erty damage Therefore ...

Page 491: ...fault indications Trip command dependent on settings Start by single pole trip command of the external protection L3 Binary input functions BF Start L3 and if necessary BF release in spontaneous or fault indications Trip command dependent on settings Starting by trip command of the external protection via all three binary inputs L1 L2 and L3 Binary input functions BF Start L1 BF Start L2 and BF St...

Page 492: ...ividually switched off protection functions 3 3 7 Checking the Instrument Transformer Connections of One Line End Should secondary test equipment be connected to the device it is to be removed or if applying test switches should be in normal operation position Note It must be taken into consideration that tripping can occur even at the opposite ends of the protected object if connections were made...

Page 493: ... instead of 120 one voltage must be polarity reversed The same applies if there are phase to phase voltages which almost equal the phase to earth voltages instead of having a value that is 3 greater The measurements are to be repeated after setting the connections right In general the phase rotation is a clockwise phase rotation If the system has a counter clockwise phase rotation this must go for...

Page 494: ...y or secondary measured values in the front display panel or via the operator or service interface with a personal computer and compared with the actually measured values The absolute values as well as the phase differences of the currents are indicated so that the correct phase sequence and polarity of individual transformers can also be seen The WEB Monitor provides comfortable read out possibil...

Page 495: ...3 3 Commissioning 495 7SD5 Manual C53000 G1176 C169 1 Figure 3 26 Local measured values in the WEB Monitor examples for plausible measured values w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 496: ...Polarity Check If the device is connected with voltage transformers the local measured values already provide a polarity test For more than two ends one current path is continued to be tested first A load current of at least 5 of the rated operational current is required Any direction is possible but must be known w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 497: ...ive if active power flows towards the busbar Q positive if inductive reactive power flows into the protected object Q negative if inductive reactive power flows toward the busbar Therefore the power results and their components must have opposite signs at both ends It must be taken into consideration that high charging currents which might occur with long overhead lines or with cables are capaciti...

Page 498: ...e signs at both ends i e turned by 180 In the WEB Monitor the local and remote measured values can be shown graphically One example is illustrated in Figure 3 27 The protected object is now switched off i e the circuit breakers are opened Polarity Check for the Voltage Input U4 Depending on the application of the voltage measuring input U4 a polarity check may be necessary If no measuring voltage ...

Page 499: ...eck the program OVERRIDE YES address 3519 is set the other programs addresses 3515 to 3518 are set to NO Via binary input No 2906 Sync Start AR initiate the measuring request The synchronism check must release closing message Sync release FNo 2951 If not check all relevant parameters again synchrocheck configured and enabled correctly see Sections 2 1 1 3 2 1 2 1 and 2 16 2 Set address 3519 OVERRI...

Page 500: ...lease closing message Sync release No 2951 If not check all voltage connections and the corresponding parameters again carefully as described in Section 2 1 2 1 Open the VT mcb of the feeder voltage Via binary input No 2906 Sync Start AR initiate the measuring request No close release is given Open the VT mcb of the feeder voltage again Addresses 3515 to 3519 must be restored as they were changed ...

Page 501: ... to the same conditions that exist during an earth fault in the direction of the line At least one stage of the earth fault protection must be set to be directional address 31x 0 of the earth fault protection The pickup threshold of this stage must be below the load current flowing on the line if necessary the pickup threshold must be reduced The parameters that are changed must be noted After swi...

Page 502: ...line should carry load The line remains switched on for the duration of the measurement If the polarity of the parallel line earth current measurement is correct the impedance measured in the tested loop in the example of Figure 3 31 this is L1 E should be reduced by the influence of the parallel line The impedances can be read out as primary or secondary quantities in the list of operational meas...

Page 503: ...orks then the polarity check can only be carried out with a zero sequence current flowing through the transformer A test voltage source is required for this purpose single phase low voltage source Caution Feeding of zero sequence currents via a transformer without broken delta winding Inadmissible heating of the transformer is possible Zero sequence current should only be routed via a transformer ...

Page 504: ...sary the pickup threshold must be reduced The parameters that have been changed must be noted Figure 3 32 Polarity check of I4 example with earth current from a power transformer star point After switching the test source on and off again the direction indication must be checked in the fault log the messages EF Pickup and EF forward must at least be present If the directional pickup alarm is missi...

Page 505: ...nsformer error according to address 253 E ALF ALF_N see Section 2 1 2 the permissible current transformer errors at the other ends according to that setting there as well as the internal estimation of the system errors frequency synchronization and delay time difference errors With the default values for I DIFF 0 3IN and E ALF ALF_N 5 0 0 05 there is with I the actual current flowing INB the nomin...

Page 506: ... paths in such a way that all ends of the object to be protected have been included in the current flow test at least once It is not necessary to test every possible current path At the ends not involved in a test the circuit breakers are to remain open Also pay at tention to all safety notes especially the DANGER warning in the above Section Checking the Instrument Transformer Connections for Mor...

Page 507: ...ULine appears and the timer is stopped The time displayed by the timer is the real circuit breaker closing time If the timer is not stopped due to an unfavourable closing moment the attempt will be repeated It is particularly favourable to calculate the mean value from several 3 to 5 successful switching attempts Set the calculated time under address 239 as T CB close under P System Data 1 Select ...

Page 508: ...utside of zone Z1 but within zone Z1B Since stage Z1B is blocked the distance protection is only tripped in a higher leveled zone usually with T2 This check must be carried out at both line ends The direct voltage for the quiescent current loop of the pilot wire comparison is switched to the line The loop is then fed with quiescent current At one line end a fault is simulated outside of the first ...

Page 509: ...ia the echo circuit if these release techniques are used The echo function must be activated at both line ends i e address 2501 FCT Weak Infeed ECHO only with the setting ECHO and TRIP at the remote end of the check a tripping command may result A short circuit is simulated outside Z1 with POTT or UNBLOCKING inside Z1B with Dir Comp Pickup somewhere in forward direction This may be done with secon...

Page 510: ...mains blocked for the duration of the transmit prolongation time of the transmitting line end Send Prolong address 2103 If applicable the transient blocking time of the receiving line end TrBlk BlockTime address 2110 appears additionally if a finite delay time TrBlk Wait Time address 2109 has been set and exceeded In case of a phase segregated transmission the above mentioned checks are carried ou...

Page 511: ... by signals from the dis tance protection address 1501 FCT Distance OFF Checking with Per missiveSchemes Requirements Teleprot E F is configured in address 132 to one of the compari son schemes using permissive signal i e Dir Comp Pickup or UNBLOCKING Fur thermore FCT Telep E F is switched ON at address 3201 Naturally the corre sponding send and receive signals must also be assigned to the corresp...

Page 512: ... receive signals must also be assigned to the corresponding binary output and input For more details about the function of the blocking scheme refer to Section 2 9 In the case of the blocking scheme communication between the line ends is necessary An earth fault in the reverse direction is simulated at the transmitting line end Subse quently a fault at the receiving end in the direction of the lin...

Page 513: ...sponse of the circuit breaker at the opposite line end is verified In the case of the distance protection the permissive underreach scheme may be used to trip the remote line end The procedure is then the same as was the case for permissive underreach under Checking with Permissive Underreach Transfer Trip however the received signal causes a direct trip For the remote transmission the external co...

Page 514: ...it breaker for the CB test must be indicated to the binary input with No 371 3 3 17 Trip Close Tests for the Configured Operating Devices Switching by Local Command If the configured operating devices were not switched sufficiently in the hardware test already described all configured switching devices must be switched on and off from the device via the integrated control element The feedback info...

Page 515: ...oscillographic recording that is externally triggered that is without a protective element pickup or device trip is processed by the device as a normal oscillographic recording and has a number for establishing a sequence However these recordings are not displayed in the fault indication buffer as they are not fault events Start Triggering Os cillographic Re cording In order to start a test measur...

Page 516: ...nciation Set Re set so that in the future they only contain information on actual events and states The numbers in the switching statistics should be reset to the values that were existing prior to the testing The counters of the operational measured values e g operation counter if available are reset under Main Menu Measurement Reset Press the ESC key several times if necessary to return to the d...

Page 517: ...rotection for Distance Protection optional 540 4 8 Earth Fault Protection in Earthed Systems optional 541 4 9 Teleprotection for Earth Fault Protection optional 550 4 10 Weak infeed Tripping classic optional 551 4 11 Weak infeed Tripping French specif optional 552 4 12 Direct Remote Trip and Transmission of Binary Information 553 4 13 Instantaneous High Current Switch onto Fault Protection SOTF 55...

Page 518: ...4 Technical Data 518 7SD5 Manual C53000 G1176 C169 1 4 24 Additional Functions 574 4 25 Dimensions 577 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 519: ...Current Input thermal rms 300 A for 1 s 100 A for 10 s 15 A continuous dynamic pulse current 750 A half cycle 1st Condition For a maximum fault current the current transformers must not be saturated under steady stateconditions 2nd Condition The operational accuracy limit factor n must be at least 30 or a non saturated period of t AL of at least 1 4 AC cycle after fault inception must be ensured n...

Page 520: ...failure short circuit of the power supply IEC 60255 11 50 ms at UAux 48 V and UAux 110 V 20 ms at UAux 24 V and UAux 60 V Voltage supply via integrated converter Nominal auxiliary voltage AC UAUX 115 VAC Admissible voltage ranges 92 to 132 VAC Power input Quiescent Approx 7 VA Energized 7SD5 A E J Approx 17 VA 7SD5 C G L N Q S Approx 20 VA 7SD5 D H M P R T Approx 23 VA plus approx 1 5 VA per inter...

Page 521: ... high speed 1 7SD5 A E J X 7 7 1 7SD5 C G L X 14 7 2 7SD5 N Q S X 7 10 1 5 7SD5 D H M X 21 7 3 7SD5 P R T X 14 10 2 5 Switching capability MAKE 1000 W VA 1000 W VA OPEN 30 VA 40 W resistive 25 W VA at L R 50 ms 1000 W VA Switching voltage DC 250 V AC 250 V 200 V max Permissible current per contact continuous 5 A Admissible current per contact close and hold pulse current 30 A for 0 5 s NO contact ...

Page 522: ...232 9 pin D subminiature female connector for connection of a PC Operation With DIGSI Transmission speed Min 4 800 Baud max 115 200 Baud Factory Setting 38400 Baud Parity 8E1 Transmission distance 15 m 50 feet RS232 RS485 FO Acc to ordered variant Isolated interface for data transfer Operation With DIGSI RS232 RS485 RS232 RS485 according to the ordering variant Connection for panel flush mounting ...

Page 523: ...el surface mounting housing In console housing at device bottom Optical wavelength λ 820 nm Laser class 1 according to EN 60825 1 2 Using glass fibre 50 125 µm or Using glass fibre 62 5 125 µm Permissible optical signal attenuation Max 8 dB with glass fibre 62 5 125 µm Transmission distance Max 1 5 km 0 93 miles Character idle state Selectable factory setting Light off w w w E l e c t r i c a l P ...

Page 524: ... D subminiature female connector Test voltage 500 V 50 Hz Transmission speed Min 4800 Bd max 38400 Bd Factory setting 19200 Bd Transmission distance Max 1 km 0 93 miles Fibre optic cable FO FO connector type ST connector Connection for panel flush mounting housing Rear panel mounting location B Connection for panel surface mounting housing In console housing at device bottom Optical wavelength λ 8...

Page 525: ...us for No charac ter Light OFF Max number of modules in optical rings with 500 kB s or 1500 kB s 41 DNP 3 0 RS 485 Connection for panel flush mounting housing Rear panel slot B 9 pole D subminiature female connector Connection for panel surface mounting housing In console housing on bottom 9 pole D subminiature female connector Test voltage 500 V 50 Hz Transmission speed Up to 19200 Baud Transmiss...

Page 526: ... 8 V 3560 Ω at UI 31 V PPS Signal for GPS ON OFF pulse duty factor 1 999 to 1 1 max rise fall time deviation of all receivers 3 µs For GPS receiver antenna and power supply unit please refer to Appendix A1 2 Accessories Standards IEC 60255 product standards IEEE Std C37 90 0 1 2 UL 508 VDE 0435 For more standards see also individual functions Standards IEC 60255 5 and IEC 60870 2 1 High voltage te...

Page 527: ...alog measuring inputs binary inputs relay outputs Impulse 1 2 50 µs Common mode 2 kV 12 Ω 9 µF Diff mode 1 kV 2 Ω 18 µF Common mode 2 kV 42Ω 0 5 µF diff mode 1 kV 42Ω 0 5 µF Line conducted HF amplitude modulated IEC 61000 4 6 Class III 10 V 150 kHz to 80 MHz 80 AM 1 kHz Power system frequency magnetic field IEC 60255 6 IEC 61000 4 8 Class IV 0 5 mT 50 Hz 30 A m continuous 300 A m for 3 s 50 Hz Osc...

Page 528: ...l 1 Hz to 8 Hz 3 5 mm amplitude horizontal axis 1 Hz to 8 Hz 1 5 mm amplitude vertical axis 8 Hz to 35 Hz 1 g acceleration horizontal axis 8 Hz to 35 Hz 0 5 g acceleration vertical axis Frequency sweep 1 octave min 1 cycle in 3 orthogonal axes Standards IEC 60255 21 and IEC 60068 Oscillation IEC 60255 21 1 Class 2 IEC 60068 2 6 Sinusoidal 5 Hz to 8 Hz 7 5 mm Amplitude 8 Hz to 150 Hz 2 g accelerati...

Page 529: ...dity on 56 days of the year up to 93 relative humidity Conden sation is to be avoided during operation It is recommended that all devices be installed so that they are not exposed to direct sunlight nor subject to large fluc tuations in temperature that may cause condensation to occur The protection device is designed for installation in normal relay rooms and plants so that electromagnetic immuni...

Page 530: ...or maximum number of components Size Weight In flush mounting housing 1 2 6 kg 13 23 lb 1 1 10 kg 22 04 lb In panel surface mounting housing 1 2 11 kg 24 24 lb 1 1 19 kg 41 88 lb Degree of protection according to IEC 60529 For equipment in surface mounting housing IP 51 For equipment in flush mounting housing Front IP 51 Back IP 50 For human safety IP 2x with cover cap UL certification conditions ...

Page 531: ...el surface mounting housing In console housing at device bottom Connection modules for protection data interface depending on the ordering version Module in the Device Connector Type Fibre Type Optical wavelength Perm path attenuation Distance maximum FO5 1 ST Multimode 62 5 125µm 820 nm 8 dB 1 5 km 0 93 miles FO6 2 ST Multimode 62 5 125µm 820 nm 16 dB 3 5 km 2 2 miles FO7 1 ST Monomode 9 125 µm 1...

Page 532: ...onverter See table above under module FO 5 Transmission rate 64 kbit s with G703 1 512 kbit s or 128 kBit s or 64 kbit s with X 21 64 Kbits s or 128 Kbits s with S0 ISDN 64 Kbits s or 128 kBit s with pilot wires Max runtime time 0 1 ms to 30 ms Increments 0 1 ms Max runtime difference 0 000 ms to 3 000 ms Increments 0 001 ms Transmission accuracy CRC 32 according to CCITT or ITU w w w E l e c t r ...

Page 533: ...ng times depend on the number of ends and the communication speed The following data presuppose a transmission speed of 512 kBit s and the output of commands via high speed output relays 7SD5 N P Q R S T Pickup trip times of the I DIFF stages at 50 or 60 Hz approx For 2 ends minimum 9 ms typical 12 ms For 3 ends minimum 9 ms typical 12 ms For 6 ends minimum 14 ms typical 20 ms Dropout time of the ...

Page 534: ...ror at n n 0 5 to 50 0 Increments 0 1 Transformer error at n x IN class 0 5 to 50 0 Increments 0 1 Further restraint quantities adaptive self restraint Frequency deviations delay time differ ences harmonics synchronous quality jitter Restraint ratio 2 Harmonic I2fN IfN 0 to 45 Increments 1 Max current for restraint IN 1 A 1 1 A to 25 0 A Increments 0 1 A IN 5 A 5 5 A to 125 0 A Crossblock Function...

Page 535: ...P Q R S T Tripping of remote ends by a command that is coupled into a binary input The operating times depend on the number of ends and the communication speed The following data presuppose a transmission speed of 512 kBit s and the output of commands via high speed output relays 7SD5 N P Q R S T Operating times total approx For 2 ends minimum 7 ms typical 12 ms For 3 ends minimum 9 ms typical 13 ...

Page 536: ...phase earth Block lagging phase earth Release all associated loops Release only phase to earth loops Release of phase to phase loops For double earth fault in isolated or resonant earthed systems L3 L1 acyclic L1 L3 acyclic L2 L1 acyclic L1 L2 acyclic L3 L2 acyclic L2 L3 acyclic L3 L1 acyclic L1 L3 acyclic All associated loops Earth current 3I0 for IN 1 A 0 05 A to 4 00 A Increments 0 01 A for IN ...

Page 537: ...aracteristic depending on ordered vari ant 5 independent zones and 1 controlled zone Setting ranges of polygon IPh min current phases for IN 1 A 0 05 A to 4 00 A Increments 0 01 A for IN 5 A 0 25 A to 20 00 A X reactance reach for IN 1 A 0 050 Ω to 600 000 Ω Increments 0 001 Ω for IN 5 A 0 010 Ω to 120 000 Ω R resistance tolerance phase phase for IN 1 A 0 050 Ω to 600 000 Ω Increments 0 001 Ω for ...

Page 538: ...der option Measuring tolerances for sinusoidal measured values Shortest trip time approx 17 ms 50 Hz 15 ms 60 Hz with fast relay and approx 12 ms 50 Hz 10 ms 60 Hz with high speed relay Dropout time Approx 30 ms Stage timers 0 00 s to 30 00 s for all zones separate time setting possibilities for single phase and multi phase faults for the zones Z1 Z2 and Z1B Increments 0 01 s Time expiry tolerance...

Page 539: ...or and observation of the path curve Maximum power swing frequency Approx 7 Hz Power swing blocking programs Block 1st zone only Block higher zones Block 1st and 2nd zone Block all zones Power swing trip Trip following instable power swings out of step Trip time delay after power swing block 0 08 to 5 00 s Increments 0 01 s w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 540: ...ments 0 01 s Method Permissive Overreach Transfer Trip POTT with overreach ing zone Z1B Dir Comp Pickup Unblocking with overreaching zone Z1B Blocking with overreaching zone Z1B Pilot wire comp Rev Interlock Send signal prolongation 0 00 s to 30 00 s Increments 0 01 s Enable delay 0 s to 30 000 s Increments 0 001 s Transient blocking time 0 00 s to 30 00 s Increments 0 01 s Wait time for transient...

Page 541: ...ays high speed relays approx 30 25 ms Dropout time Approx 30 ms Tolerances Current 3 of setting value or 1 nominal current Time 1 of setting value or 10 ms The set times are pure delay times Pickup value 3I0 for IN 1 A 0 05 A to 25 00 A Increments 0 01 A for IN 5 A 0 25 A to 125 00 A Delay T3I0 0 00 s to 30 00 s or ineffective Increments 0 01 s Dropout Ratio Approx 0 95 for I IN 0 5 Pickup time fa...

Page 542: ...s Current Pickup at 1 05 I 3I0P 1 15 Time 5 15 ms for 2 I 3I0P 20 and T3I0P s 1 Pickup value 3I0P for IN 1 A 0 05 A to 25 00 A or 0 003 A to 25 000 A Increments 0 01 A Increments 0 001 A for IN 5 A 0 25 A to 125 00 A or 0 015 A to 125 000 A Increments 0 01 A Increments 0 001 A Time Factor D3I0P 0 50 s to 15 00 s or ineffective Increments 0 01 s Additional time delay T3I0P add 0 00 s to 30 00 s or ...

Page 543: ...lue or 10 ms Dropout Ratio Current Approx 0 95 for I IN 0 5 Voltage Approx 0 95 for 3U0 1 V The set times are pure delay times Pickup value 3I0P for IN 1 A 0 05 A to 25 00 A 0 003 A to 25 000 A Increments 0 01 A Increments 0 001 A for IN 5 A 0 25 A to 125 00 A 0 015 A to 125 000 A Increments 0 01 A Increments 0 001 A Pickup value S FORWARD for IN 1 A for IN 5 A 0 1 VA to 10 0 VA Increments 0 1 VA ...

Page 544: ...ltage 3U0 0 5 V to 10 0 V Increments 0 1 V Starpoint current of a power transformer IY for IN 1 A 0 05 A to 1 00 A Increments 0 01 A for IN 5 A 0 25 A to 5 00 A Negative sequence current 3I2 for IN 1 A 0 05 A to 1 00 A Increments 0 01 A for IN 5 A 0 25 A to 5 00 A Negative sequence voltage 3U2 0 5 V to 10 0 V Increments 0 1 V Forward angle Capacitive alpha 0 to 360 Increments 1 Inductive beta 0 to...

Page 545: ...tection in Earthed Systems optional 545 7SD5 Manual C53000 G1176 C169 1 Figure 4 1 Trip time characteristics of inverse time overcurrent stage acc IEC phases and earth w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 546: ...echnical Data 546 7SD5 Manual C53000 G1176 C169 1 Figure 4 2 Trip time characteristics of inverse time overcurrent stage acc ANSI IEEE phases and earth w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 547: ...tion in Earthed Systems optional 547 7SD5 Manual C53000 G1176 C169 1 Figure 4 3 Trip time characteristics of inverse time overcurrent stage acc ANSI IEEE phases and earth w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 548: ...e time overcurrent stage with logarithmic inverse characteristic Logarithmic inverse t T3I0Pmax T3I0P ln I 3I0P Note For I 3I0P 35 the time for I 3I0P 35 applies Figure 4 5 Trip time characteristics of the zero sequence voltage protection U0 inverse w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 549: ...ems optional 549 7SD5 Manual C53000 G1176 C169 1 Figure 4 6 Tripping characteristics of the zero sequence power protection This characteristic applies for Sref 10 VA and T3IOPAdd T_DELAY 0 s w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 550: ...ectional unblocking scheme Directional blocking scheme Send signal prolongation 0 00 s to 30 00 s Increments 0 01 s Enable delay 0 000 s to 30 000 s Increments 0 001 s Transient blocking time 0 00 s to 30 00 s Increments 0 01 s Wait time for transient blocking 0 00 s to 30 00 s Increments 0 01 s Echo delay time 0 00 s to 30 00 s Increments 0 01 s Echo impulse duration 0 00 s to 30 00 s Increments ...

Page 551: ...ier signal from the remote end Setting value UPhE 2 V to 70 V Increments 1 V Dropout to pickup ratio Approx 1 1 Pickup tolerance 5 of setting value or 0 5 V Enable delay 0 00 s to 30 00 s Increments 0 01 s Enable delay 0 00 s to 30 00 s Increments 0 01 s Echo blocking duration after echo 0 00 s to 30 00 s Increments 0 01 s Pickup tolerance 1 of setting value or 10 ms w w w E l e c t r i c a l P a ...

Page 552: ...ments 0 01 Dropout pickup ratio Approx 1 1 Pickup tolerance 5 Receive prolongation 0 00 s to 30 00 s Increments 0 01 s Extension time 3I0 0 00 s to 30 00 s Increments 0 01 s Alarm time 3I0 0 00 s to 30 00 s Increments 0 01 s Delay single pole 0 00 s to 30 00 s Increments 0 01 s Delay multi pole 0 00 s to 30 00 s Increments 0 01 s Time constant τ 1 to 60 s Increments 1 s Pickup tolerance 1 of setti...

Page 553: ...ds minimum 10 ms typical 14 ms For 6 ends minimum 15 ms typical 18 ms Dropout times total approx For 2 ends typical 19 ms For 3 ends typical 20 ms For 6 ends typical 26 ms Number of possible remote commands 24 The operating times depend on the number of ends and the communication speed The following data presuppose a transmission speed of 512 kBit s and the output of commands via high speed output...

Page 554: ...nwirk sam Increments 0 01 A for IN 5 A 0 50 A bis 75 00 A oder unwirk sam High current pickup I for IN 1 A 1 00 A to 25 00 A or disabled Increments 0 01 A for IN 5 A 5 00 A to 125 00 A or disabled Dropout to pickup ratio Approx 90 Pickup tolerance 3 of setting value or 1 of IN Shortest trip time fast relays high speed relays ca 10 5 ms w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 555: ... is blocked e g because of a trip of the voltage transformer mcb via binary input a measuring voltage failure or a pickup of the fuse failure monitor Back up overcurrent protection operates independent of any events Definite dime stages definite IPh 3I0 IPh 3I0 Inverse time stages IDMT IP 3I0P one of the characteristics according to Figure 4 1 to 4 3 can be selected Pickup value IPh phases for IN ...

Page 556: ...00 A or ineffective Pickup value 3I0P earth for IN 1 A 0 05 A to 4 00 A or ineffective Increments 0 01 A for IN 5 A 0 25 A to 20 00 A or ineffective Time factors TIP phas es 0 05 s to 3 00 s or ineffective Increments 0 01 s T3I0P earth 0 05 s to 3 00 s or ineffective Increments 0 01 s Additional time delays TIP delayed phases 0 00 s to 30 00 s Increments 0 01 s T3I0P delayed earth 0 00 s to 30 00 ...

Page 557: ... s 1 Defined times 1 of setting value or 10 ms Pickup value IPh phases for IN 1 A 0 10 A to 25 00 A or ineffective Increments 0 01 A for IN 5 A 0 50 A to 125 00 A or ineffective Pickup value 3I0 earth for IN 1 A 0 05 A to 25 00 A or ineffective Increments 0 01 A for IN 5 A 0 25 A to 125 00 A or ineffective Delays TIPh 0 00 s to 30 00 s or ineffective Increments 0 01 s T3I0 0 00 s to 30 00 s or ine...

Page 558: ...50 s to 300 00 s Increments 0 01 s Blocking time after dynamic blocking 0 5 sec Blocking time after manual closing 0 50 s to 300 00 s 0 Increments 0 01 s Start signal monitoring time 0 01 s to 300 00 s Increments 0 01 s Circuit breaker monitoring time 0 01 s to 300 00 s Increments 0 01 s Adaptive dead time With voltage measurement or with close command transmission Action times Initiation possible...

Page 559: ...g voltage 20 V to 140 V phase to phase Increments 1 V U for dead status 1 V to 60 V phase to phase Increments 1 V U for live status 20 V to 125 V phase to phase Increments 1 V Tolerances 2 of pickup value or 1 V Dropout to pickup ratio Approx 0 9 U or 1 1 U Voltage difference 1 0 V to 40 0 V phase to phase Increments 0 1V Tolerance 1 V Dropout to pickup ratio Approx 1 05 ϕ measurement 2 to 80 Incr...

Page 560: ...Manual C53000 G1176 C169 1 Minimum measuring time Approx 80 ms Maximum measuring time 0 01 s to 600 00 s Increments 0 01 s Tolerance of all timers 1 of setting value or 10 ms w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 561: ...0 s to 100 00 s Increments 0 01 s Dropout ratio 0 30 to 0 98 Increments 0 01 Pickup times fast relays high speed relays approx 35 30 ms Dropout time approx 30 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of setting value or 10 ms Overvoltage U1 2 0 V to 220 0 V Increments 0 1 V Delay TU1 0 00 s to 100 00 s Increments 0 01 s Overvoltage U1 2 0 V to 220 0 V Increments 0 1 V Delay TU1 0 0...

Page 562: ...1 V Times 1 of setting value or 10 ms Undervoltage UPh 1 0 V to 100 0 V Increments 0 1 V Delay TUPh 0 00 s to 100 00 s Increments 0 01 s Undervoltage UPh 1 0 V to 100 0 V Increments 0 1 V Delay TUPh 0 00 s to 100 00 s Increments 0 01 s Dropout ratio approx 1 05 Current criterion Can be switched on off Pickup times fast relays high speed relays approx 35 30 ms Dropout time approx 30 ms Tolerances V...

Page 563: ... 00 s Increments 0 01 s Undervoltage U1 1 0 V to 100 0 V Increments 0 1 V Delay TU1 0 00 s to 100 00 s Increments 0 01 s Dropout ratio approx 1 05 Current criterion Can be switched on off Pickup times fast relays high speed relays approx 35 30 ms Dropout time approx 30 ms Tolerances Voltages 3 of setting value or 1 V Times 1 of setting value or 10 ms w w w E l e c t r i c a l P a r t M a n u a l s...

Page 564: ... Dropout times f f approx 30 ms Delay times T 0 00 s to 600 00 s Increments 0 01 s The set times are pure delay times Note on dropout times Dropout was enforced by current 0 A and voltage 0 V Enforcing the dropout by means of a frequency change below the dropout threshold extends the dropout times f pickup value dropout value Approx 20 mHz In voltage range Approx 6 V to 230 V phase earth In freque...

Page 565: ...n A1 to A3 Parallel line compensation optional Can be switched on off The setting values are the same as for distance protection see Section 4 5 Taking into consideration the load current in case of single phase earth faults Correction of the X value can be enabled and disabled Output of the fault distance In Ω primary and Ω secondary in km or miles line length 1 in of the line length 1 Double end...

Page 566: ...educed Auxiliary contacts are necessary for the circuit breaker failure protection for tripping without or with a very low current flow e g Buchholz protection stub fault protection circuit breaker pole discrepancy monitoring For circuit breaker failure protection Internal or external single pole trip 1 Internal or external three pole trip 1 Internal or external three pole trip without current 1 P...

Page 567: ...ip overtem perature Increments 1 Current Overload IAlarm for IN 1 A 0 10 A to 4 00 A Increments 0 01 A for IN 5 A 0 50 A to 20 00 A Calculation method temperature rise Maximum temperature rise of 3 phases Average of temperature rise of 3 phases Temperature rise from maximum current Θ ΘTrip Θ ΘAlarm I IAlarm Drops out with ΘAlarm Approx 0 99 Approx 0 97 Referring to k IN 2 or 1 of nominal current C...

Page 568: ...4 Technical Data 568 7SD5 Manual C53000 G1176 C169 1 Figure 4 7 Trip time characteristics of the overload protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 569: ... Umax BAL ULIMIT BAL FACTOR U 0 58 to 0 95 Increments 0 01 BAL ULIMIT 10 V to 100 V Increments 1 V T BAL ULIMIT 5 s to 100 s Increments 1 s Voltage phase sequence UL1 before UL2 before UL3 as long as UL1 UL2 UL3 40 V 3 Non symmetrical voltages Fuse failure monitoring 3 U0 FFM U OR 3 U2 FFM U AND at the same time 3 I0 FFM I AND 3 I2 FFM I FFM U 10 V to 100 V Increments 1 V FFM I for IN 1 A 0 10 A t...

Page 570: ... Number of monitored circuits 1 to 3 Operation per circuit With 1 binary input or with 2 binary inputs Pickup and Dropout Time Approx 1 to 2 s Settable delay time for operation with 1 binary input 1 s to 30 s Increments 1 s w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 571: ...e X X CMD_INF Command information X CONNECT Connection X X X D_FF D Flipflop X X X D_FF_MEMO status memory for restart X X X X DI_TO_BOOL Double Point to Boolean conversion X X X DIV division X X X X DM_DECODE Decode double point X X X X DYN_OR dynamic or X X X X LIVE_ZERO X LONG_TIMER Timer max 1193h X X X X LOOP Feedback loop X X X X LOWER_SETPOINT Lower limit X MUL multiplication X X X X NAND N...

Page 572: ...or each task level number of unequal information items of the left border per task level 400 Only error message here the number of elements of the left border per task level is counted Since the same information is indicated at the border several times only unequal information is to be count ed Maximum number of reset resistant flipflops D_FF_MEMO 50 When the limit is exceeded an error message is ...

Page 573: ... Processing 1 900 PLC_BEARB Fast PLC Processing 200 SFS_BEARB switchgear interlocking 10 000 Individual Element Number of TICKS Block basic requirement 5 Each input more than 3 inputs for generic modules 1 Connection to an input signal 6 Connection to an output signal 7 Additional for each chart 1 Operating sequence module CMD_CHAIN 34 Flipflop D_FF_MEMO 6 Loop module LOOP 8 Decoder DM_DECODE 8 Dy...

Page 574: ...L3 E XL1 L2 XL2 L3 XL3 L1 XL1 E XL2 E XL3 E in Ω primary and secondary Operational measured values for power S P Q apparent active and reactive power in MVA MW Mvar primary and SN operational nominal power 3 UN IN Tolerance for S Tolerance for P Tolerance for Q 1 of SN at I IN and U UN in range 50 to 120 1 of SN at I IN and U UN in the range from 50 to 120 and ABS cos ϕ in the range 0 7 1 of SNat ...

Page 575: ...mote end in UNOperation 3 ϕ UL1 ϕ UL2 ϕ UL3 remote versus local in Capacity 200 records Capacity 8 faults with a total of max 600 messages Number of stored fault records Max 8 Storage time Max 5s for each fault approx 15 s in total Sampling rate at fN 50 Hz 1 ms Sampling rate at fN 60 Hz 0 83 ms Availability of transmission for applications with pro tection data interface Availability in min and h...

Page 576: ...management No Operating mode Explanations 1 Internal Internal synchronization via RTC default 2 IEC 60870 5 103 External via system interface IEC 60870 5 103 3 GPS synchronization External synchronization using GPS interface 4 Time signal IRIG B External synchronization via IRIG B telegram format IRIG B000 5 Time signal DCF 77 External synchronization via DCF 77 6 Time signal synchro box External ...

Page 577: ...Manual C53000 G1176 C169 1 4 25 Dimensions 4 25 1 PanelFlushandCubicleMounting HousingSize1 2 Figure 4 8 Dimensions of a device for panel flush or cubicle mounting size 1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 578: ...578 7SD5 Manual C53000 G1176 C169 1 4 25 2 PanelFlushandCubicleMounting HousingSize1 1 Figure 4 9 Dimensions of a device for panel flush or cubicle mounting size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 579: ...ce Mounting Housing Size 1 2 Figure 4 10 Dimensions of a device for panel surface mounting size 1 2 4 25 4 Panel Surface Mounting Housing Size 1 1 Figure 4 11 Dimensions of a device for panel surface mounting size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 580: ...4 Technical Data 580 7SD5 Manual C53000 G1176 C169 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 581: ...tions of the devices to primary equipment in many typical power system configurations Tables with all set tings and all information available in this device equipped with all options are provided Default settings are also given A 1 Ordering Information and Accessories 582 A 2 Terminal Assignments 590 A 3 Connection Examples 602 A 4 Default Settings 609 A 5 Protocol dependent Functions 616 A 6 Func...

Page 582: ...16 With Distance Pro tection 7 S D 5 L M N Function Package Version Pos 5 Line differential protection with 4 line display 2 Line differential protection with graphical display 3 Device Type Pos 6 Line differential protection for two end operation1 2 Line differential protection for multi end operation2 3 Measured Current Input Pos 7 IPh 1 A IE 1 A 1 IPh 1 A IE sensitive min 0 005 A 2 IPh 5 A IE 5...

Page 583: ... mounting housing with two tier terminals 1 1 x 19 16 BI 23 BO 5 high speed relays 1 life contact Q Surface mounting housing with two tier terminals 1 1 x 19 24 BI 31 BO 5 high speed relays 1 life contact R Flush mounting housing with plug in terminals 1 1 x 19 16 BI 23 BO 5 high speed relays 1 life contact S Flush mounting housing with plug in terminals 1 1 x 19 24 BI 31 BO 5 high speed relays 1 ...

Page 584: ... direct connection or communication networks using multimode fibre A Port D optical 820 nm 2 ST connectors length of optical fibre up to 3 5 km for direct connection using multimode fibre B Port D optical 1300 nm 2 ST connectors length of optical fibre up to 10 km for direct connection using monomode fibre C Port D optical 1300 nm 2 FC connectors length of optical fibre up to 35 km for direct conn...

Page 585: ...heck 7 Port E optical 820 nm 2 ST connectors length of optical fibre up to 1 5 km for direct connection or communication networks using multimode fibre A Port E optical 820 nm 2 ST connectors length of optical fibre up to 3 5 km for direct connection using multimode fibre B Port E optical 1300 nm 2 ST connectors length of optical fibre up to 10 km for direct connection using monomode fibre C Port ...

Page 586: ... in more than 60 of the test voltage at the communication converter i e 3 kV for CC CC They are connected between the communication con verter and the communication line Name Order No Isolation transformer test voltage 20 kV 7XR6516 GPS Name Order No GPS receiver with antenna and cable 7XV5664 0AA0 Power supply 7XV5810 0BA00 with without without with K with without with without L with without with...

Page 587: ... 1 FO 820 nm C53207 A351 D643 1 Profibus DP RS485 C53207 A351 D611 1 Profibus DP double ring C53207 A351 D613 1 Profibus FMS RS485 C53207 A351 D603 1 Profibus FMS double ring C53207 A351 D606 1 DNP 3 0 RS 485 C53207 A351 D631 3 DNP 3 0 820 nm C53207 A351 D633 3 FO5 with ST connector 820 nm multimode optical fibre maximum length 1 5 km1 C53207 A351 D651 1 FO6 with ST connector 820 nm multimode opti...

Page 588: ...Interface cable between PC and SIPROTEC 4 device Order No Cable with 9 pole male female connector 7XV5100 4 DIGSI operating software DIGSI protection operation and configuration software Order No DIGSI basic version with licenses for 10 computers 7XS5400 0AA00 DIGSI complete version with all option packages 7XS5402 0AA00 Graphical Analysis Program SIGRA Software for graphical visualization analysi...

Page 589: ...0 G1176 C169 1 SIMATIC CFC 4 Name Order No Graphical software for setting interlocking latching control conditions and creating additional functions option package of the complete version of DIGSI 7XS5450 0AA0 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 590: ...0 G1176 C169 1 A 2 Terminal Assignments A 2 1 Panel Flush Mounting or Cubicle Mounting 7SD5 A J Figure A 1 General diagram 7SD5 A J panel flush mounting or cubicle mounting size1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 591: ... Terminal Assignments 591 7SD5 Manual C53000 G1176 C169 1 7SD5 C L Figure A 2 General diagram 7SD5 C L panel flush mounting or cubicle mounting size1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 592: ...A Appendix 592 7SD5 Manual C53000 G1176 C169 1 7SD5 N S Figure A 3 General diagram 7SD5 N S panel flush mounting or cubicle mounting size1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 593: ... Terminal Assignments 593 7SD5 Manual C53000 G1176 C169 1 7SD5 D M Figure A 4 General diagram 7SD5 D M panel flush mounting or cubicle mounting size1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 594: ...A Appendix 594 7SD5 Manual C53000 G1176 C169 1 7SD5 P T Figure A 5 General diagram 7SD5 P T panel flush mounting or cubicle mounting size1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 595: ...minal Assignments 595 7SD5 Manual C53000 G1176 C169 1 A 2 2 Panel Surface Mounting 7SD5 E Figure A 6 General diagram 7SD5 E panel surface mounting size1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 596: ...dix 596 7SD5 Manual C53000 G1176 C169 1 7SD5 E release CC and higher Figure A 7 General diagram 7SD5 E release CC and higher panel surface mounting size1 2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 597: ...A 2 Terminal Assignments 597 7SD5 Manual C53000 G1176 C169 1 7SD5 G Figure A 8 General diagram 7SD5 G panel surface mounting size1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 598: ...A Appendix 598 7SD5 Manual C53000 G1176 C169 1 7SD5 Q Figure A 9 General diagram 7SD5 Q panel surface mounting size1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 599: ...A 2 Terminal Assignments 599 7SD5 Manual C53000 G1176 C169 1 7SD5 H Figure A 10 General diagram 7SD5 H panel surface mounting size1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 600: ...A Appendix 600 7SD5 Manual C53000 G1176 C169 1 7SD5 R Figure A 11 General diagram 7SD5 R panel surface mounting size1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 601: ...nts 601 7SD5 Manual C53000 G1176 C169 1 7SD5 G H Q R release CC and higher Figure A 12 General diagram 7SD5 G H Q R release CC and higher panel surface mounting size 1 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 602: ...76 C169 1 A 3 Connection Examples A 3 1 Current Transformer Connection Examples Figure A 13 Current connections to three current transformers and starpoint current normal circuit layout w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 603: ...G1176 C169 1 Figure A 14 Current connections to 3 current transformers with separate earth current trans former summation current transformer prefered for solidly or low resistive earthed systems w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 604: ...000 G1176 C169 1 Figure A 15 Current connections to three current transformers and earth current from the star point connection of a par allel line for parallel line compensation w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 605: ...0 G1176 C169 1 Figure A 16 Current connections to three current transformers and earth current from the star point current of an earthed power transformer for directional earth fault protection w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 606: ...anual C53000 G1176 C169 1 A 3 2 Voltage Transformer Connection Examples Figure A 17 Voltage connections to three wye connected voltage transformers normal circuit layout w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 607: ...mples 607 7SD5 Manual C53000 G1176 C169 1 Figure A 18 Voltage connections to three wye connected voltage transformers with addition al open delta windings e n winding w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 608: ...000 G1176 C169 1 Figure A 19 Voltage connections to three wye connected voltage transformers and addition ally to a busbar voltage for overvoltage protection or synchronism check w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 609: ...r different 3235 Differences between common pa rameters Equal IDs 3487 Equal IDs in constellation LED6 Relay TRIP 511 Relay GENERAL TRIP command1 Relay TRIP 3ph 515 Relay TRIP command Phases L1232 LED7 no presetting 1 Relay TRIP 1pL1 512 Relay TRIP command Only Phase L12 Relay TRIP 1pL2 513 Relay TRIP command Only Phase L22 Relay TRIP 1pL3 514 Relay TRIP command Only Phase L32 LED8 Test Diff 3190 ...

Page 610: ... 7105 BLOCK Backup OverCurrent I BLOCK O C Ip 7106 BLOCK Backup OverCurrent Ip BLOCK O C Ie 7107 BLOCK Backup OverCurrent Ie BLOCK O C Ie 7108 BLOCK Backup OverCurrent Ie BLOCK O C Iep 7109 BLOCK Backup OverCurrent Iep BLOCK I STUB 7130 BLOCK I STUB BLOCK O CIe 7132 BLOCK Backup OverCurrent Ie BI5 CB 3p Open 380 CB aux contact 3pole Open CB1 3p Open 411 CB1 aux 3p Open for AR CB Test BI6 CB1 Ready...

Page 611: ... L23 Relay TRIP 3ph 515 Relay TRIP command Phases L1233 BO6 no presetting 2 Relay TRIP 1pL3 514 Relay TRIP command Only Phase L33 Relay TRIP 3ph 515 Relay TRIP command Phases L1233 BO7 AR CLOSE Cmd 2851 AR Close command4 BO8 Diff block 3148 Diff Differential protection is blocked BO9 AR not ready 2784 AR Auto reclose is not ready4 BO10 Test Diff 3190 Diff Set Teststate of Diff protection TestDiff ...

Page 612: ...Table A 5 This selection is available as start page which may be configured Function Keys Vorrangierte Funktion Function No Description F1 Display of Opera tional Annuncia tions F2 Display of opera tional values F3 An overview of the last 8 network faults F4 none Page 1 Page 2 Page 3 Page 4 Page 5 Page 6 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 613: ...of the device in the sequence shown in the following Figure Figure A 20 Spontaneous fault indication display Spontaneous Fault Annunciations of the Graphic Display All devices featuring a graphic display allow you to select whether or not to view auto matically the most important fault data on the display after a general interrogation The information is shown in the display in the following order ...

Page 614: ...ix 614 7SD5 Manual C53000 G1176 C169 1 Default Display in the Graphic Editor Figure A 21 Standard default display after starting the Display Editor example w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 615: ...evice Depending on the variant the following charts may be implemented Device and System Logic The NEGATOR block assigns the input signal DataStop directly to an output This is not directly possible without the interconnection of this block Figure A 22 Logical Link between Input and Output w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 616: ...col DCF77 IRIG B GPS Interface Binary Input Via DCF77 IRIG B GPS Interface Binary Input Via protocol DCF77 IRIG B GPS Interface Binary Input Messages with Time Stamp Yes Yes No Yes Commissioning Tools Alarm and Mea sured Value Trans mission Blocking Yes Yes No No Generate Test Alarms Yes Yes No No Physical Mode Asynchronous Asynchronous Asynchronous Asynchronous Transmission Mode Cyclic Event Cycl...

Page 617: ...abled Enabled Disabled Power Swing detection 121 Teleprot Dist PUTT Z1B PUTT Pickup POTT Dir Comp Pickup UNBLOCKING BLOCKING Rev Interlock Pilot wire comp Disabled Disabled Teleprotection for Distance prot 122 DTT Direct Trip Disabled Enabled Disabled DTT Direct Transfer Trip 124 HS SOTF O C Disabled Enabled Disabled Instantaneous HighSpeed SOTF Overcurrent 125 Weak Infeed Disabled Enabled Logic n...

Page 618: ...tection 140 Trip Cir Sup Disabled 1 trip circuit 2 trip circuits 3 trip circuits Disabled Trip Circuit Supervision 142 Therm Overload Disabled Enabled Disabled Thermal Overload Protection 143 TRANSFORMER NO YES NO Transformer inside protection zone 144 V TRANSFORMER Not connected connected connected Voltage transformers 145 P INTERFACE 1 Enabled Disabled Enabled Protection Interface 1 Port D 146 P...

Page 619: ... Data 1 0 360 0 Angle adjustment Usync Uline 215 U line Usync P System Data 1 0 50 2 00 1 00 Matching ratio U line Usync 220 I4 transformer P System Data 1 Not connected In prot line In paral line IY starpoint In prot line I4 current transformer is 221 I4 Iph CT P System Data 1 0 010 5 000 1 000 Matching ratio I4 Iph for CT s 230 Rated Frequency P System Data 1 50 Hz 60 Hz 50 Hz Rated Frequency 23...

Page 620: ...x P System Data 2 1A 0 0050 15 0000 Ω mi 0 2420 Ω mi x Line Reactance per length unit 5A 0 0010 3 0000 Ω mi 0 0484 Ω mi 1112 c P System Data 2 1A 0 000 100 000 µF km 0 010 µF km c capacit per unit line len µF km 5A 0 000 500 000 µF km 0 050 µF km 1112 c P System Data 2 1A 0 000 160 000 µF mi 0 016 µF mi c capacit per unit line len µF mile 5A 0 000 800 000 µF mi 0 080 µF mi 1113 Line Length P Syste...

Page 621: ...GROUP U P System Data 2 0 11 0 Vector group numeral for voltage 1162 VECTOR GROUP I P System Data 2 0 11 0 Vector group numeral for current 1163 TRANS STP IS P System Data 2 Solid Earthed Not Earthed Solid Earthed Transformer starpoint is 1201 STATE OF DIFF Diff Prot OFF ON ON State of differential protection 1210 I DIFF Diff Prot 1A 0 10 20 00 A 0 30 A I DIFF Pickup value 5A 0 50 100 00 A 1 50 A ...

Page 622: ...ve 1540 Distance Angle P System Data 2 Dis General 30 90 85 Angle of inclination distance charact 1541 R load Ø E Dis General 1A 0 100 600 000 Ω Ω R load minimum Load Imped ance ph e 5A 0 020 120 000 Ω Ω 1542 ϕ load Ø E Dis General 20 60 45 PHI load maximum Load Angle ph e 1543 R load Ø Ø Dis General 1A 0 100 600 000 Ω Ω R load minimum Load Imped ance ph ph 5A 0 020 120 000 Ω Ω 1544 ϕ load Ø Ø Dis...

Page 623: ...Directional Inactive Non Directional Operating mode Z4 1632 R Z4 Ø Ø Dis Quadril 1A 0 050 600 000 Ω 12 000 Ω R Z4 Resistance for ph ph faults 5A 0 010 120 000 Ω 2 400 Ω 1633 X Z4 Dis Quadril 1A 0 050 600 000 Ω 12 000 Ω X Z4 Reactance 5A 0 010 120 000 Ω 2 400 Ω 1634 RE Z4 Ø E Dis Quadril 1A 0 050 250 000 Ω 12 000 Ω RE Z4 Resistance for ph e faults 5A 0 010 50 000 Ω 2 400 Ω 1635 T4 DELAY Dis General...

Page 624: ... ZR Z4 Impedance Reach 5A 0 010 40 000 Ω 2 000 Ω 1741 Op mode Z5 Dis MHO Forward Reverse Inactive Inactive Operating mode Z5 1742 ZR Z5 Dis MHO 1A 0 050 200 000 Ω 10 000 Ω ZR Z5 Impedance Reach 5A 0 010 40 000 Ω 2 000 Ω 1751 Op mode Z1B Dis MHO Forward Reverse Inactive Forward Operating mode Z1B extended zone 1752 ZR Z1B Dis MHO 1A 0 050 200 000 Ω 3 000 Ω ZR Z1B Impedance Reach 5A 0 010 40 000 Ω 0...

Page 625: ... 00 sec 10 00 sec Time Delay for Alarm 2108 Release Delay Teleprot Dist 0 000 30 000 sec 0 000 sec Time Delay for release after pickup 2109A TrBlk Wait Time Teleprot Dist 0 00 30 00 sec 0 04 sec Transient Block Duration exter nal flt 2110A TrBlk BlockTime Teleprot Dist 0 00 30 00 sec 0 05 sec Transient Block Blk T after ext flt 2201 FCT Direct Trip DTT Direct Trip ON OFF OFF Direct Transfer Trip D...

Page 626: ...5 125 00 A 2 50 A 2613 T 3I0 Back Up O C 0 00 30 00 sec 2 00 sec T 3I0 Time delay 2614 I Telep BI Back Up O C NO YES YES Instantaneous trip via Tele prot BI 2615 I SOTF Back Up O C NO YES NO Instantaneous trip after Switch OnToFault 2620 Iph Back Up O C 1A 0 10 25 00 A 1 50 A Iph Pickup 5A 0 50 125 00 A 7 50 A 2621 T Iph Back Up O C 0 00 30 00 sec 0 50 sec T Iph Time delay 2622 3I0 Back Up O C 1A ...

Page 627: ...MinMaxRES START Min Max meter 1 365 Days 1 Days MinMax Start Reset Cycle in 2901 MEASURE SUPERV Measurem Superv ON OFF ON Measurement Supervision 2902A BALANCE U LIMIT Measurem Superv 10 100 V 50 V Voltage Threshold for Balance Monitoring 2903A BAL FACTOR U Measurem Superv 0 58 0 95 0 75 Balance Factor for Voltage Monitor 2904A BALANCE I LIMIT Measurem Superv 1A 0 10 1 00 A 0 50 A Current Balance ...

Page 628: ...12 T 3I0 Earth Fault O C 0 00 30 00 sec 0 30 sec T 3I0 Time delay 3113 3I0 Telep BI Earth Fault O C NO YES NO Instantaneous trip via Tele prot BI 3114 3I0 SOTF Trip Earth Fault O C NO YES NO Instantaneous trip after Switch OnToFault 3115 3I0 InrushBlk Earth Fault O C NO YES NO Inrush Blocking 3120 Op mode 3I0 Earth Fault O C Forward Reverse Non Directional Inactive Inactive Operating mode 3121 3I0...

Page 629: ...50 3I0p InrushBlk Earth Fault O C Earth Fault O C Earth Fault O C Earth Fault O C NO YES NO Inrush Blocking 3151 IEC Curve Earth Fault O C Normal Inverse Very Inverse Extremely Inv LongTimeInverse Normal Inverse IEC Curve 3152 ANSI Curve Earth Fault O C Inverse Short Inverse Long Inverse Moderately Inv Very Inverse Extremely Inv Definite Inv Inverse ANSI Curve 3153 LOG Curve Earth Fault O C Log in...

Page 630: ...000 30 000 sec 0 000 sec Time Delay for release after pickup 3209A TrBlk Wait Time Teleprot E F 0 00 30 00 sec 0 04 sec Transient Block Duration exter nal flt 3210A TrBlk BlockTime Teleprot E F 0 00 30 00 sec 0 05 sec Transient Block Blk T after ext flt 3401 AUTO RECLOSE Auto Reclose OFF ON ON Auto Reclose Function 3402 CB 1 TRIP Auto Reclose YES NO NO CB ready interrogation at 1st trip 3403 T REC...

Page 631: ...fore re closing 3460 1 AR SynRequest Auto Reclose YES NO NO Request for synchro check after 3pole AR 3461 2 AR START Auto Reclose YES NO NO AR start allowed in this cycle 3462 2 AR T ACTION Auto Reclose 0 01 300 00 sec 0 20 sec Action time 3464 2 AR Tdead 1Flt Auto Reclose 0 01 1800 00 sec 1 20 sec Dead time after 1phase faults 3465 2 AR Tdead 2Flt Auto Reclose 0 01 1800 00 sec 1 20 sec Dead time ...

Page 632: ... Operating mode with AR 3511 Max Volt Diff Sync Check 1 0 40 0 V 2 0 V Maximum voltage difference 3512 Max Freq Diff Sync Check 0 03 2 00 Hz 0 10 Hz Maximum frequency difference 3513 Max Angle Diff Sync Check 2 80 10 Maximum angle difference 3515A SYNC CHECK Sync Check YES NO YES Live bus live line and Sync before AR 3516 Usync U line Sync Check YES NO NO Live bus dead line check before AR 3517 Us...

Page 633: ...mode Uph ph over voltage prot 3712 Uph ph Voltage Prot 2 0 220 0 V 150 0 V Uph ph Pickup 3713 T Uph ph Voltage Prot 0 00 100 00 sec 2 00 sec T Uph ph Time Delay 3714 Uph ph Voltage Prot 2 0 220 0 V 175 0 V Uph ph Pickup 3715 T Uph ph Voltage Prot 0 00 100 00 sec 1 00 sec T Uph ph Time Delay 3719A Uphph RESET Voltage Prot 0 30 0 98 0 98 Uph ph Reset ratio 3721 3U0 or Ux Voltage Prot OFF Alarm Only ...

Page 634: ...00 sec T U1 Time Delay 3778 CURR SUP U1 Voltage Prot ON OFF ON Current supervision U1 3802 START Fault Locator Pickup TRIP Pickup Start fault locator with 3805 Paral Line Comp Fault Locator NO YES YES Mutual coupling parall line com pensation 3806 Load Compensat Fault Locator NO YES NO Load Compensation 3807 two ended Fault Locator ON OFF ON two ended faulr location 3811 Tmax OUTPUT BCD Fault Loca...

Page 635: ...s Tool NO YES YES Front interface supports LCP NCP mode 4411 IP A A x x x Commiss Tool 0 255 141 IP address xxx xxx xxx Posi tion 1 3 4412 IP B x B x x Commiss Tool 0 255 142 IP address xxx xxx xxx Posi tion 4 6 4413 IP C x x C x Commiss Tool 0 255 255 IP address xxx xxx xxx Posi tion 7 9 4414 IP D x x x D Commiss Tool 0 255 160 IP address xxx xxx xxx Pos 10 12 4415 NUM LOCK Commiss Tool YES NO YE...

Page 636: ... sec Delay time for local GPS pulse loss 6001 S1 Line angle P System Data 2 30 89 85 S1 Line angle 6002 S1 x P System Data 2 1A 0 0050 9 5000 Ω km 0 1500 Ω km S1 feeder reactance per km x 5A 0 0010 1 9000 Ω km 0 0300 Ω km 6002 S1 x P System Data 2 1A 0 0050 15 0000 Ω mi 0 2420 Ω mi S1 feeder reactance per mile x 5A 0 0010 3 0000 Ω mi 0 0484 Ω mi 6003 S1 c P System Data 2 1A 0 000 100 000 µF km 0 0...

Page 637: ... 0050 9 5000 Ω km 0 1500 Ω km S3 feeder reactance per km x 5A 0 0010 1 9000 Ω km 0 0300 Ω km 6042 S3 x P System Data 2 1A 0 0050 15 0000 Ω mi 0 2420 Ω mi S3 feeder reactance per mile x 5A 0 0010 3 0000 Ω mi 0 0484 Ω mi 6043 S3 c P System Data 2 1A 0 000 100 000 µF km 0 010 µF km S3 feeder capacitance c in µF km 5A 0 000 500 000 µF km 0 050 µF km 6043 S3 c P System Data 2 1A 0 000 160 000 µF mi 0 0...

Page 638: ...ENED Device IntSP LED BO Feeder EARTHED FdrEARTHED Device IntSP LED BO Group A Group A Change Group IntSP ON OFF LED BO 192 23 1 Yes Group B Group B Change Group IntSP ON OFF LED BO 192 24 1 Yes Group C Group C Change Group IntSP ON OFF LED BO 192 25 1 Yes Group D Group D Change Group IntSP ON OFF LED BO 192 26 1 Yes Fault Recording Start FltRecSta Osc Fault Rec IntSP ON OFF m LED BO Reset Minimum...

Page 639: ...Cabinet door open Door open Process Data SP on off LED BI BO CB 101 1 1 Yes CB waiting for Spring charged CB wait Process Data SP on off LED BI BO CB 101 2 1 Yes Error Motor Voltage Err Mot U Process Data SP on off LED BI BO CB 240 181 1 Yes Error Control Voltage ErrCntr lU Process Data SP on off LED BI BO CB 240 182 1 Yes SF6 Loss SF6 Loss Process Data SP on off LED BI BO CB 240 183 1 Yes Error M...

Page 640: ...evice OUT ON OFF LED BO 69 Daylight Saving Time DayLight SavTime Device OUT ON OFF LED BO 70 Setting calculation is running Settings Calc Device OUT ON OFF LED BO 192 22 1 Yes 71 Settings Check Settings Check Device OUT LED BO 72 Level 2 change Level 2 change Device OUT ON OFF LED BO 73 Local setting change Local change Device OUT 110 Event lost Event Lost Device OUT_ Ev ON LED BO 135 130 1 No 113...

Page 641: ...Error Board 3 Device OUT ON OFF LED BO 135 173 1 Yes 186 Error Board 4 Error Board 4 Device OUT ON OFF LED BO 135 174 1 Yes 187 Error Board 5 Error Board 5 Device OUT ON OFF LED BO 135 175 1 Yes 188 Error Board 6 Error Board 6 Device OUT ON OFF LED BO 135 176 1 Yes 189 Error Board 7 Error Board 7 Device OUT ON OFF LED BO 135 177 1 Yes 190 Error Board 0 Error Board 0 Device OUT ON OFF LED BO 135 21...

Page 642: ... Data 2 VI ON OFF ON 351 Circuit breaker aux contact Pole L1 CB Aux L1 P System Data 2 SP LED BI BO 150 1 1 Yes 352 Circuit breaker aux contact Pole L2 CB Aux L2 P System Data 2 SP LED BI BO 150 2 1 Yes 353 Circuit breaker aux contact Pole L3 CB Aux L3 P System Data 2 SP LED BI BO 150 3 1 Yes 356 Manual close signal Manual Close P System Data 2 SP LED BI BO 150 6 1 Yes 357 Block all close commands...

Page 643: ...er Reset Pdmd MiMaReset Min Max meter SP ON LED BI BO 405 Qdmd MIN MAX Buffer Reset Qdmd MiMaReset Min Max meter SP ON LED BI BO 406 Sdmd MIN MAX Buffer Reset Sdmd MiMaReset Min Max meter SP ON LED BI BO 407 Frq MIN MAX Buffer Reset Frq MiMa Reset Min Max meter SP ON LED BI BO 408 Power Factor MIN MAX Buffer Reset PF MiMaReset Min Max meter SP ON LED BI BO 410 CB1 aux 3p Closed for AR CB Test CB1 ...

Page 644: ...e P System Data 2 VI 560 Single phase trip was coupled 3phase Trip Coupled 3p P System Data 2 OUT ON LED BO 150 210 2 No 561 Manual close signal detected Man Clos Detect P System Data 2 OUT ON LED BO 150 211 1 No 562 CB CLOSE command for manual closing Man Close Cmd P System Data 2 OUT LED BO 150 212 1 No 563 CB alarm suppressed CB Alarm Supp P System Data 2 OUT LED BO 590 Line closure detected Li...

Page 645: ...4 No 1122 Flt Locator Distance to fault dist Fault Locator VI ON OFF 151 22 4 No 1123 Fault Locator Loop L1E FL Loop L1E Fault Locator OUT_ Ev ON 1124 Fault Locator Loop L2E FL Loop L2E Fault Locator OUT_ Ev ON 1125 Fault Locator Loop L3E FL Loop L3E Fault Locator OUT_ Ev ON 1126 Fault Locator Loop L1L2 FL Loop L1L2 Fault Locator OUT_ Ev ON 1127 Fault Locator Loop L2L3 FL Loop L2L3 Fault Locator O...

Page 646: ...es 1310 Earth Fault O C Instantaneous trip EF InstTRIP Earth Fault O C SP ON OFF ON OFF LED BI BO 166 10 1 Yes 1311 E F Teleprotection ON EF Teleprot ON Teleprot E F SP LED BI BO 1312 E F Teleprotection OFF EF TeleprotOFF Teleprot E F SP LED BI BO 1313 E F Teleprotection BLOCK EF TeleprotBLK Teleprot E F SP ON OFF LED BI BO 166 13 1 Yes 1318 E F Carrier RECEPTION Channel 1 EF Rec Ch1 Teleprot E F ...

Page 647: ...ault O C OUT ON OFF LED BO 1345 Earth fault protection PICKED UP EF Pickup Earth Fault O C OUT off LED BO 166 45 2 Yes 1354 E F 3I0 PICKED UP EF 3I0 Pickup Earth Fault O C OUT ON LED BO 1355 E F 3I0 PICKED UP EF 3I0 Pickup Earth Fault O C OUT ON LED BO 1356 E F 3I0 PICKED UP EF 3I0 Pickup Earth Fault O C OUT ON LED BO 1357 E F 3I0p PICKED UP EF 3I0p Pickup Earth Fault O C OUT ON LED BO 1358 E F pi...

Page 648: ...il2 Teleprot E F OUT ON OFF LED BO 166 88 1 Yes 1389 E F Telep Blocking carrier STOP signal EF Tele BL STOP Teleprot E F OUT on LED BO 166 89 2 No 1390 E F Tele Blocking Send signal with jump EF Tele BL Jump Teleprot E F OUT LED BO 166 90 2 No 1401 BF Switch on breaker fail pro tection BF on Breaker Failure SP LED BI BO 1402 BF Switch off breaker fail pro tection BF off Breaker Failure SP LED BI B...

Page 649: ...erload Protection OFF Th Overload OFF Therm Overload OUT ON OFF LED BO 167 11 1 Yes 1512 Thermal Overload Protection BLOCKED Th Overload BLK Therm Overload OUT ON OFF ON OFF LED BO 167 12 1 Yes 1513 Thermal Overload Protection ACTIVE Th O L ACTIVE Therm Overload OUT ON OFF LED BO 167 13 1 Yes 1515 Th Overload Current Alarm I alarm Th O L I Alarm Therm Overload OUT ON OFF LED BO 167 15 1 Yes 1516 T...

Page 650: ...ose SP ON OFF LED BI BO 40 40 1 Yes 2746 AR External Trip for AR start Trip for AR Auto Reclose SP ON LED BI BO 40 41 2 Yes 2747 AR External pickup L1 for AR start Pickup L1 AR Auto Reclose SP ON LED BI BO 40 42 2 Yes 2748 AR External pickup L2 for AR start Pickup L2 AR Auto Reclose SP ON LED BI BO 40 43 2 Yes 2749 AR External pickup L3 for AR start Pickup L3 AR Auto Reclose SP ON LED BI BO 40 44 ...

Page 651: ...lose OUT ON LED BO 40 158 2 Yes 2847 AR 4th or higher cycle running AR 4thCyc run Auto Reclose OUT ON LED BO 40 159 2 Yes 2848 AR cycle is running in ADT mode AR ADT run Auto Reclose OUT ON LED BO 40 130 2 Yes 2851 AR Close command AR CLOSE Cmd Auto Reclose OUT ON m LED BO 192 128 2 No 2852 AR Close command after 1pole 1st cycle AR Close1 Cyc1p Auto Reclose OUT LED BO 40 152 1 Yes 2853 AR Close co...

Page 652: ...Prog Live bus dead line Usyn U line Sync Check SP LED BI BO 2910 Sync Prog Dead bus dead line Usyn U line Sync Check SP LED BI BO 2911 Sync Prog Override bypass Sync o ride Sync Check SP LED BI BO 2930 Synchro check ON OFF via BI Sync on off BI Sync Check IntSP ON OFF LED BO 2931 Synchro check is switched OFF Sync OFF Sync Check OUT ON OFF LED BO 41 31 1 Yes 2932 Synchro check is BLOCKED Sync BLOC...

Page 653: ...c U line Sync Check OUT ON OFF ON OFF LED BO 3101 IC compensation active IC comp active Diff Prot OUT on off LED BO 3102 Diff 2nd Harmonic detected in phase L1 2nd Harmonic L1 Diff Prot OUT LED BO 92 89 1 Yes 3103 Diff 2nd Harmonic detected in phase L2 2nd Harmonic L2 Diff Prot OUT LED BO 92 90 1 Yes 3104 Diff 2nd Harmonic detected in phase L3 2nd Harmonic L3 Diff Prot OUT LED BO 92 91 1 Yes 3120 ...

Page 654: ...iff Prot OUT LED BO 3183 Diff Fault detection L3E Diff Flt L3E Diff Prot OUT LED BO 3184 Diff Fault detection L31 Diff Flt L31 Diff Prot OUT LED BO 3185 Diff Fault detection L31E Diff Flt L31E Diff Prot OUT LED BO 3186 Diff Fault detection L23 Diff Flt L23 Diff Prot OUT LED BO 3187 Diff Fault detection L23E Diff Flt L23E Diff Prot OUT LED BO 3188 Diff Fault detection L123 Diff Flt L123 Diff Prot O...

Page 655: ... 93 139 1 Yes 3240 Prot Int 2 Transmission delay too high PI2 TD alarm Prot Interface OUT ON OFF LED BO 93 140 1 Yes 3243 Prot Int 1 Connected with relay ID PI1 with Prot Interface VI ON OFF 3244 Prot Int 2 Connected with relay ID PI2 with Prot Interface VI ON OFF 3245 GPS failure from external GPS failure Prot Interface SP ON OFF LED BI BO 3247 GPS local pulse loss GPS loss Prot Interface OUT ON ...

Page 656: ...7 Equal IDs in constellation Equal IDs Diff Topo OUT ON OFF LED BO 3491 Relay 1 in Login state Rel1 Login Diff Topo OUT ON OFF LED BO 93 191 1 Yes 3492 Relay 2 in Login state Rel2 Login Diff Topo OUT ON OFF LED BO 93 192 1 Yes 3493 Relay 3 in Login state Rel3 Login Diff Topo OUT ON OFF LED BO 93 193 1 Yes 3494 Relay 4 in Login state Rel4 Login Diff Topo OUT ON OFF LED BO 93 194 1 Yes 3495 Relay 5 ...

Page 657: ...1pole Intertrip OUT ON OFF LED BO 3523 I Trip TRIP 3pole Diff TRIP 3pole Intertrip OUT ON OFF LED BO 3525 Differential protection blocking signal Diff block Diff Prot SP ON OFF LED BI BO 3526 Differential blocking received at PI1 Diffblk rec PI1 Diff Prot OUT ON OFF LED BO 3527 Differential blocking received at PI2 Diffblk rec PI2 Diff Prot OUT ON OFF LED BO 3528 Differential blocking sending via ...

Page 658: ... BI BO 3563 Remote Signal 15 input Rem Signal15 Remote Signals SP on off LED BI BO 3564 Remote Signal 16 input Rem Signal16 Remote Signals SP on off LED BI BO 3565 Remote Signal 17 input Rem Signal17 Remote Signals SP on off LED BI BO 3566 Remote Signal 18 input Rem Signal18 Remote Signals SP on off LED BI BO 3567 Remote Signal 19 input Rem Signal19 Remote Signals SP on off LED BI BO 3568 Remote S...

Page 659: ...l 18 received Rem Sig18recv Remote Signals OUT on off LED BO 93 175 1 Yes 3591 Remote signal 19 received Rem Sig19recv Remote Signals OUT on off LED BO 93 176 1 Yes 3592 Remote signal 20 received Rem Sig20recv Remote Signals OUT on off LED BO 93 177 1 Yes 3593 Remote signal 21 received Rem Sig21recv Remote Signals OUT on off LED BO 93 178 1 Yes 3594 Remote signal 22 received Rem Sig22recv Remote S...

Page 660: ...Pickup L2E Dis General OUT ON LED BO 28 84 2 No 3685 Distance Pickup L12 Dis Pickup L12 Dis General OUT ON LED BO 28 85 2 No 3686 Distance Pickup L12E Dis Pick up L12E Dis General OUT ON LED BO 28 86 2 No 3687 Distance Pickup Phase L3 only Dis Pickup 1pL3 Dis General OUT ON LED BO 28 87 2 No 3688 Distance Pickup L3E Dis Pickup L3E Dis General OUT ON LED BO 28 88 2 No 3689 Distance Pickup L31 Dis P...

Page 661: ...oop L2E Dis General OUT ON OFF LED BO 3715 Distance Loop L3E selected non direct Dis Loop L3E Dis General OUT ON OFF LED BO 3716 Distance Loop L12 selected non direct Dis Loop L12 Dis General OUT ON OFF LED BO 3717 Distance Loop L23 selected non direct Dis Loop L23 Dis General OUT ON OFF LED BO 3718 Distance Loop L31 selected non direct Dis Loop L31 Dis General OUT ON OFF LED BO 3719 Distance Pick...

Page 662: ...161 2 No 3801 Distance protection General trip Dis Gen Trip Dis General OUT LED BO 28 201 2 No 3802 Distance TRIP command Only Phase L1 Dis Trip 1pL1 Dis General OUT ON LED BO 28 202 2 No 3803 Distance TRIP command Only Phase L2 Dis Trip 1pL2 Dis General OUT ON LED BO 28 203 2 No 3804 Distance TRIP command Only Phase L3 Dis Trip 1pL3 Dis General OUT ON LED BO 28 204 2 No 3805 Distance TRIP command...

Page 663: ...09 Dis Tele Carrier RECEPTION Channel 1 L3 Dis T RecCh1L3 Teleprot Dist SP on off on LED BI BO 29 9 1 Yes 4010 Dis Tele Carrier RECEPTION Channel 2 Dis T Rec Ch2 Teleprot Dist SP on off on LED BI BO 29 10 1 Yes 4030 Dis Tele Unblocking UNBLOCK Channel 1 Dis T UB ub 1 Teleprot Dist SP on off on LED BI BO 29 30 1 Yes 4031 Dis Tele Unblocking BLOCK Channel 1 Dis T UB bl 1 Teleprot Dist SP on off on L...

Page 664: ...cking carrier STOP signal L3 Dis T BL STOPL3 Teleprot Dist OUT LED BO 4160 BLOCK Power Swing detection Pow Swing BLK Power Swing SP ON OFF ON OFF LED BI BO 4163 Power Swing unstable P Swing unstab Power Swing OUT ON ON LED BO 4164 Power Swing detected Power Swing Power Swing OUT ON OFF ON OFF LED BO 29 164 1 Yes 4166 Power Swing TRIP command Pow Swing TRIP Power Swing OUT ON ON LED BO 29 166 1 No ...

Page 665: ...and L123 Weak TRIP L123 Weak Infeed OUT ON LED BO 25 45 2 No 4246 ECHO Send SIGNAL ECHO SIGNAL Weak Infeed OUT ON ON LED BO 25 46 2 Yes 4253 BLOCK Instantaneous SOTF Overcurrent BLOCK SOTF O C SOTF Overcurr SP LED BI BO 4271 SOTF O C is switched OFF SOTF O C OFF SOTF Overcurr OUT ON OFF LED BO 25 71 1 Yes 4272 SOTF O C is BLOCKED SOTF O C BLOCK SOTF Overcurr OUT ON OFF ON OFF LED BO 25 72 1 Yes 42...

Page 666: ...y L1 DTT TRIP 1p L1 DTT Direct Trip OUT ON LED BO 51 32 2 No 4433 DTT TRIP command Only L2 DTT TRIP 1p L2 DTT Direct Trip OUT ON LED BO 51 33 2 No 4434 DTT TRIP command Only L3 DTT TRIP 1p L3 DTT Direct Trip OUT ON LED BO 51 34 2 No 4435 DTT TRIP command L123 DTT TRIP L123 DTT Direct Trip OUT ON LED BO 51 35 2 No 5203 BLOCK frequency protection BLOCK Freq Frequency Prot SP ON OFF LED BI BO 70 176 ...

Page 667: ...uperv SP ON OFF LED BI BO 6858 Trip circuit superv 3 Trip Relay TripC3 TripRel TripCirc Superv SP ON OFF LED BI BO 6859 Trip circuit superv 3 Breaker Relay TripC3 Bkr Rel TripCirc Superv SP ON OFF LED BI BO 6861 Trip circuit supervision OFF TripC OFF TripCirc Superv OUT ON OFF LED BO 170 53 1 Yes 6865 Failure Trip Circuit FAIL Trip cir TripCirc Superv OUT ON OFF LED BO 192 36 1 Yes 6866 TripC1 blo...

Page 668: ... C Pickup L1E Back Up O C OUT ON LED BO 64 73 2 No 7174 Backup O C Pickup Only L2 O C PU 1p L2 Back Up O C OUT ON LED BO 64 74 2 No 7175 Backup O C Pickup L2E O C Pickup L2E Back Up O C OUT ON LED BO 64 75 2 No 7176 Backup O C Pickup L12 O C Pickup L12 Back Up O C OUT ON LED BO 64 76 2 No 7177 Backup O C Pickup L12E O C Pickup L12E Back Up O C OUT ON LED BO 64 77 2 No 7178 Backup O C Pickup Only L...

Page 669: ... 1 Yes 7327 CB1 TEST TRIP command Only L3 CB1 TESTtrip L3 Testing OUT ON OFF LED BO 153 27 1 Yes 7328 CB1 TEST TRIP command L123 CB1 TESTtrip123 Testing OUT ON OFF LED BO 153 28 1 Yes 7329 CB1 TEST CLOSE command CB1 TEST close Testing OUT ON OFF LED BO 153 29 1 Yes 7345 CB TEST is in progress CB TEST running Testing OUT ON OFF LED BO 153 45 1 Yes 7346 CB TEST canceled due to Power Sys Fault CB TST...

Page 670: ...25 Uph e Undervolt is switched OFF Uph e OFF Voltage Prot OUT ON OFF LED BO 73 25 1 Yes 10226 Uph e Undervolt is BLOCKED Uph e BLK Voltage Prot OUT ON OFF ON OFF LED BO 73 26 1 Yes 10227 Uph ph Undervolt is switched OFF Uph ph OFF Voltage Prot OUT ON OFF LED BO 73 27 1 Yes 10228 Uphph Undervolt is BLOCKED Uph ph BLK Voltage Prot OUT ON OFF ON OFF LED BO 73 28 1 Yes 10229 U1 Undervolt is switched O...

Page 671: ... Voltage Prot OUT ON OFF LED BO 73 80 2 Yes 10281 U1 Pickup U1 Pickup Voltage Prot OUT ON OFF LED BO 73 81 2 Yes 10282 U1 TimeOut U1 TimeOut Voltage Prot OUT LED BO 10283 U1 TimeOut U1 TimeOut Voltage Prot OUT LED BO 10284 U1 TRIP command U1 TRIP Voltage Prot OUT ON LED BO 73 84 2 Yes 10290 U2 Pickup U2 Pickup Voltage Prot OUT ON OFF LED BO 73 90 2 Yes 10291 U2 Pickup U2 Pickup Voltage Prot OUT ON...

Page 672: ...Uph ph Pickup Voltage Prot OUT ON OFF LED BO 73 126 2 Yes 10327 Uphph Pickup L1 L2 Uph ph PU L12 Voltage Prot OUT ON OFF LED BO 73 127 2 Yes 10328 Uphph Pickup L2 L3 Uph ph PU L23 Voltage Prot OUT ON OFF LED BO 73 128 2 Yes 10329 Uphph Pickup L3 L1 Uph ph PU L31 Voltage Prot OUT ON OFF LED BO 73 129 2 Yes 10330 Uphph TimeOut Uphph Time Out Voltage Prot OUT LED BO 10331 Uphph TimeOut Uphph TimeOut ...

Page 673: ...188 189 190 191 193 361 Failure Σi Fail I balance Fail Σ U Ph E Fail U balance Fail U absent VT FuseFail 10s VT FuseFail Fail Ph Seq Fail Battery Error Board 1 Error Board 2 Error Board 3 Error Board 4 Error Board 5 Error Board 6 Error Board 7 Error Board 0 Error Offset Alarm adjustm FAIL Feeder VT 161 Fail I Superv 289 163 Failure Σi Fail I balance 164 Fail U Superv 165 167 168 Fail Σ U Ph E Fail...

Page 674: ... 129 No 9 4 CFC CD DD 622 U L2 E UL2E Measurement 134 129 No 9 5 CFC CD DD 623 U L3 E UL3E Measurement 134 129 No 9 6 CFC CD DD 624 U L12 UL12 Measurement 134 129 No 9 10 CFC CD DD 625 U L23 UL23 Measurement 134 129 No 9 11 CFC CD DD 626 U L31 UL31 Measurement 134 129 No 9 12 CFC CD DD 627 Uen Uen Measurement CFC CD DD 631 3U0 zero sequence 3U0 Measurement CFC CD DD 632 Usync synchronism Usync Mea...

Page 675: ...9 Apparent Power Demand Minimum SdMin Min Max meter CFC CD DD 850 Apparent Power Demand Maximum Sd Max Min Max meter CFC CD DD 851 I L1 Minimum IL1Min Min Max meter CFC CD DD 852 I L1 Maximum IL1Max Min Max meter CFC CD DD 853 I L2 Mimimum IL2Min Min Max meter CFC CD DD 854 I L2 Maximum IL2Max Min Max meter CFC CD DD 855 I L3 Minimum IL3Min Min Max meter CFC CD DD 856 I L3 Maximum IL3Max Min Max m...

Page 676: ...12 Measurement CFC CD DD 978 X L23 X L23 Measurement CFC CD DD 979 X L31 X L31 Measurement CFC CD DD 1040 Active Power Minimum Forward Pmin Forw Min Max meter CFC CD DD 1041 Active Power Maximum Forward Pmax Forw Min Max meter CFC CD DD 1042 Active Power Minimum Reverse Pmin Rev Min Max meter CFC CD DD 1043 Active Power Maximum Reverse Pmax Rev Min Max meter CFC CD DD 1044 Reactive Power Minimum F...

Page 677: ... PI1 TD Statistics 134 122 No 9 7 CFC CD DD 7752 Prot Interface 2 Transmission delay PI2 TD Statistics 134 122 No 9 9 CFC CD DD 7753 Prot Interface 1 Availability per min PI1A m Statistics CFC CD DD 7754 Prot Interface 1 Availability per hour PI1A h Statistics 134 122 No 9 8 CFC CD DD 134 121 No 9 3 7755 Prot Interface 2 Availability per min PI2A m Statistics CFC CD DD 7756 Prot Interface 2 Availa...

Page 678: ...em IL2_loc ΦI L2 Measure relay3 CFC CD DD 7806 IL3 of Operational nominal current IL3_opN Measure relay3 CFC CD DD 7807 Angle IL3_rem IL3_loc ΦI L3 Measure relay3 CFC CD DD 7809 UL1 of Operational nominal voltage UL1_opN Measure relay3 CFC CD DD 7810 Angle UL1_rem UL1_loc ΦU L1 Measure relay3 CFC CD DD 7811 UL2 of Operational nominal voltage UL2_opN Measure relay3 CFC CD DD 7812 Angle UL2_rem UL2_...

Page 679: ... Measure relay6 CFC CD DD 7864 IL2 of Operational nominal current IL2_opN Measure relay6 CFC CD DD 7865 Angle IL2_rem IL2_loc ΦI L2 Measure relay6 CFC CD DD 7866 IL3 of Operational nominal current IL3_opN Measure relay6 CFC CD DD 7867 Angle IL3_rem IL3_loc ΦI L3 Measure relay6 CFC CD DD 7869 UL1 of Operational nominal voltage UL1_opN Measure relay6 CFC CD DD 7870 Angle UL1_rem UL1_loc ΦU L1 Measur...

Page 680: ...Max meter CFC CD DD 10103 Max Zero Sequence Voltage 3U0 3U0max Min Max meter CFC CD DD No Description Function IEC 60870 5 103 Configurable in Matrix Type Information Number Compatibility Data Unit Position CFC Control Display Default Display w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 681: ...ure 1 SIPROTEC 4 System Description E50417 H1176 C151 A2 2 SIPROTEC DIGSI Start Up E50417 G1176 C152 A2 3 DIGSI CFC Manual E50417 H1176 C098 A4 4 SIPROTEC SIGRA 4 Manual E50417 H1176 C070 A2 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 682: ...Literature 682 7SD5 Manual C53000 G1176 C169 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

Page 683: ...locks are parts of the user program delimited by their function their structure or their purpose Chatter blocking A rapidly intermittent input for example due to a relay contact fault is switched off after a configurable monitoring time and can thus not generate any further signal changes The function prevents overloading of the system when a fault arises Combination devices Combination devices ar...

Page 684: ...clock unit of the PTB transmits this time via the long wave time signal transmitter in Mainflingen near Frank furt Main The emitted time signal can be received within a radius of approx 1 500 km from Frankfurt Main Device container In the Component View all SIPROTEC 4 devices are assigned to an object of type Device container This object is a special object of DIGSI Manager However since there is ...

Page 685: ...ouble point indication ExDP_I External double point indication via an ETHERNET connection intermediate position 00 device specific Double point indication ExMV External metered value via an ETHERNET connection device specific ExSI External single point indication via an ETHERNET connection device specific Single point indication ExSI_F External single point indication via an ETHERNET connection de...

Page 686: ... by a reference to the file name HV project descrip tion All the data is exported once the configuration and parameterisation of PCUs and sub modules using ModPara has been completed This data is split up into several files One file contains details about the fundamental project structure This also includes for example information detailing which fields exist in this project This file is called a ...

Page 687: ... dis played in the form of a list this area is called the list view LV Limit value LVU Limit value user defined Master Masters may send data to other users and request data from other users DIGSI op erates as a master Metered value Metered values are a processing function with which the total number of discrete similar events counting pulses is determined for a period usually as an integrated valu...

Page 688: ...de there is a physical link to a SIPROTEC 4 device which can be implemented in various ways This link can be implemented as a direct con nection as a modem connection or as a PROFIBUS FMS connection OUT Output indication Parameter set The parameter set is the set of all parameters that can be set for a SIPROTEC 4 device Phone book User addresses for a modem connection are saved in this object type...

Page 689: ...rm for all adjustments made to the device Parameterization jobs are exe cuted by means of DIGSI or in some cases directly on the device SI Single point indication SI_F Single point indication fleeting Transient information Single point indication SICAM SAS Modularly structured station control system based on the substation controller SICAM SC and the SICAM WinCC operator control and monitoring sys...

Page 690: ...processed further Transient informa tion A transient information is a brief transient single point indication at which only the coming of the process signal is detected and processed immediately Tree view The left pane of the project window displays the names and symbols of all containers of a project in the form of a folder tree This area is called the tree view TxTap Transformer Tap Indication U...

Page 691: ... 491 C Calculation of the Impedances 118 Certifications 530 Chain topology 75 Characteristics Definite time 24 Inverse time 24 Charge comparison stage Pickup value 101 Charging current values 427 Check Blocking scheme 510 Blocking scheme earth fault protection 512 Data connection of serial interfaces 471 Instrument transformer connections for more than two ends 506 Operator interface 471 Permissiv...

Page 692: ...mes Earth fault protection 233 Configuration of auto reclosure 303 Configuration of Function Scope 38 Contact mode for binary outputs 452 Control Logic 441 Control voltage for binary inputs 452 Controlled Zone 160 Controlled zone 147 Cross polarization 153 CT error characteristic 52 Cubicle Mounting 577 578 Cubicle mounting 468 Current Flow Monitoring 359 Current Inputs 519 Current pickup Voltage ...

Page 693: ... 125 Earth Fault Protection Characteristics 541 541 Determination of Direction 544 High Current Stage 541 Zero Sequence Power Protection Stage 543 Zero Sequence Voltage Time Protection Stage U0 inverse 543 Earth fault protection 541 Determination of direction 225 Inrush restraint 543 Inverse time overcurrent stage with logarithmic inverse characteristic 542 Inverse time stage with ANSI characteris...

Page 694: ...n 215 Instantaneous High current Switch onto Fault Protection 265 Instantaneous High set current Switch onto Fault Protection 554 Instantaneous trip I stage 265 I stage 265 Instantaneous tripping Before automatic reclosure 273 Instrument transformer connections Check with more than two ends 506 Differential currents 505 Polarity check 496 Polarity check for the current inputI4 500 Polarity check f...

Page 695: ...U I ϕ pickup 129 U Ipickup 129 Overcurrent Stage IP inverse time 271 Overcurrent stage 3I0 Definite time O C protection 277 3I0P Inverse time O C protection with ANSI characteristics 279 3I0P Inverse time O C protection with IEC characteristics 278 I definite time 271 IP Inverse time O C protection with ANSI characteristics 279 IP Inverse time O C protection with IEC characteristics 278 Iph Defini...

Page 696: ...e tripping 108 Remote CLOSE 295 Requirements for current transformers 519 Reset 432 Resistance Tolerance 144 Restraint current values 427 Retrievable indications 420 Reverse Interlocking 197 Ring topology 76 85 S Series compensated lines 126 Service modem interface 522 Service Conditions 529 Service interface Check 471 Setting group change option 55 Setting groups 55 Single pole Dead Time 403 Sing...

Page 697: ...p dependent messages 411 Tripping characteristic 150 Tripping Logic 167 274 Tripping Logic of the Entire Device 404 Tripping zones 155 Two stage Breaker Failure Protection 368 U Umschaltung von Einstellgruppen 447 Underreach Schemes Distance Protection 540 Undervoltage protection Phase earth 330 336 562 Phase phase 332 337 562 Positive sequence system U1 333 337 563 User Defined Functions 571 V Vi...

Page 698: ...Index 698 7SD5 Manual C53000 G1176 C169 1 w w w E l e c t r i c a l P a r t M a n u a l s c o m ...

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