Siemens siprotec 7SA6 Manual Download Page 291

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Functions

6-101

7SA6 Manual
C53000-G1176-C156-2

Figure 6-58

Logic diagram of the directional comparison pick-up scheme (one line end)

Two terminals

Dis Telep. off

>Dis.Telep. Blk

≥

Dis. forward L1

Dis. forward L2

Dis. forward. L3

Dis. forward

2103

Send Prolong

>Dis.T.RecCh1L1

>Dis.T.RecCh1L3

>Dis.T.RecCh1L2

≥

Z4 instantaneous trip L3

>DisTel Rec.Ch1

>DisTel Rec.Ch2

Three terminals

Two terminals

Three terminals

„1“

2102

Line Config.

≥

TRIP Command

≥

Dis.Telep.OFF

Dis.T.SEND L1

Dis.T.SEND L2

Dis.T.SEND L3

Dis.T.SEND

Transient Blocking

(Section 6.6.1.10)

Echo function

Section 6.6.1.11

FNr 4003

FNr 4006

FNr 4010

FNr 4007

FNr 4008

FNr 4009

FNr 4052

FNr 4057

FNr 4058

FNr 4059

FNr 4056

>Dis. RecFail

FNr 4005

Z4 instantaneous trip L2

Z4 instantaneous trip L1

Dis.T.Carr.Fail

FNr 4055

Summary of Contents for siprotec 7SA6

Page 1: ...eface Table of Contents Introduction 1 Hardware and Connections 2 Initial Inspections 3 SIPROTEC 4 Devices 4 Configuration 5 Functions 6 Control During Operation 7 Installation and Commissioning 8 Routine Checks and Maintenance 9 Technical Data 10 Appendix A Appendix B ...

Page 2: ...Siemens Aktiengesellschaft Book No C53000 G1176 C156 2 ...

Page 3: ...ware version 4 2 Additional support Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser s purpose the matter should be referred to the local Siemens representative Courses Individual course offerings may be found in our Training Catalog or questions can be directed to our training center Please contact your Siemens represen...

Page 4: ...equipment in accordance with established safety practices Is trained in the proper care and use of protective equipment in accordance with es tablished safety practices Is trained in rendering first aid Typographic and Symbol Conventions The following text formats are used when literal information from the device or to the device appear in the text flow Parameter names i e designators of configura...

Page 5: ...quotes Deviations may be permitted in drawings when the type of designator can be obviously derived from the illustration The following symbols are used in drawings Furthermore the graphic symbols according IEC 617 12 IEC 617 13 or similar are used in most cases and the possible settings On and Off UL1 L2 Earth fault device internal logical input signal Earth fault device internal logical output s...

Page 6: ... of this document and giving it to others and the use or communication of the contents thereof are forbidden without ex press authority Offenders are liable to the payment of damages All rights are reserved especially in the event or grant of a patent or registration of a utility model or design Registered trademarks SIPROTEC SINAUT SICAM and DIGSI are registered trade marks of SIEMENS AG Other na...

Page 7: ...0 2 1 6 Connections to Analog Outputs 2 21 2 2 Version of 7SA6 for Panel Surface Mounting 2 22 2 2 1 Housing 2 22 2 2 2 Screw Terminal Connections 2 29 2 2 3 Connections to Optical Communication Interfaces 2 30 2 2 4 Connections to Electrical Communication Interfaces 2 34 2 2 5 Connections to Analog Outputs 2 35 2 3 Version of 7SA6 with Detached Operator Panel 2 36 2 3 1 Housing and Detached Opera...

Page 8: ...s 4 4 4 2 Operator Control Facilities 4 5 4 2 1 Operator Control Panel On Device 4 5 4 2 2 DIGSI 4 Tool 4 7 4 3 Information Retrieval 4 8 4 3 1 Annunciations 4 9 4 3 2 Measurements 4 11 4 3 3 Oscillographic Fault Records 4 13 4 4 Control 4 14 4 5 Manual Overwrite Tagging 4 16 4 6 General about the Setting Procedures 4 17 4 7 Configuration of the Scope of Device Functions 4 20 4 8 Configuration of ...

Page 9: ... 2 5 Transferring Metered Values 5 36 5 2 6 Settings for Contact Chatter Blocking 5 37 5 3 Creating User Defined Functions with CFC 5 39 5 4 Establishing a Default Display 5 48 5 5 Draft of a Feeder Control Display 5 52 5 6 Serial Interfaces 5 54 5 7 Date and Time Stamping 5 58 6 Functions 6 1 6 1 General 6 2 6 1 1 Power System Data 1 6 7 6 1 1 1 Settings 6 11 6 1 2 Setting Groups 6 14 6 1 2 1 Set...

Page 10: ... 6 51 6 2 3 4 Information Overview 6 52 6 2 4 Distance Protection with Polygonal Tripping Characteristic optional 6 55 6 2 4 1 Method of Operation 6 55 6 2 4 2 Applying the Function Parameter Settings 6 60 6 2 4 3 Settings 6 64 6 2 5 Tripping Logic of the Distance Protection 6 67 6 2 5 1 Method of Operation 6 67 6 2 5 2 Applying the Function Parameter Settings 6 71 6 3 Measures to Be Taken in Case...

Page 11: ...g the Function Parameter Settings 6 128 6 7 3 Settings 6 135 6 7 4 Information Overview 6 138 6 8 Earth Fault Protection Teleprotection Schemes optional 6 139 6 8 1 Method of Operation 6 140 6 8 1 1 Directional Comparison Scheme 6 140 6 8 1 2 Directional Unblocking Scheme 6 144 6 8 1 3 Directional Blocking Scheme 6 146 6 8 1 4 Transient Blocking 6 148 6 8 1 5 Measures for Weak or Zero Infeed 6 149...

Page 12: ...plying the Function Parameter Settings 6 220 6 15 3 Settings 6 224 6 15 4 Information Overview 6 225 6 16 Voltage Protection optional 6 227 6 16 1 Method of Operation 6 227 6 16 1 1 Overvoltage Protection 6 227 6 16 1 2 Undervoltage Protection 6 231 6 16 2 Applying the Function Parameter Settings 6 234 6 16 3 Settings 6 237 6 16 4 Information Overview 6 238 6 17 Fault Location 6 242 6 17 1 Method ...

Page 13: ...on of Line Energization 6 292 6 22 2 Processing of the Circuit Breaker Position 6 293 6 22 3 Overall Fault Detection Logic of the Device 6 296 6 22 4 Overall Tripping Logic of the Device 6 297 6 22 5 Circuit Breaker Trip Test 6 303 6 22 6 Applying the Function Parameter Settings 6 304 6 22 7 Settings 6 304 6 22 8 Information Overview 6 305 6 23 Supplementary Functions 6 306 6 23 1 Processing of Me...

Page 14: ...gy 7 21 7 1 3 3 Setting Set Points 7 21 7 1 3 4 Resetting of Metered Values and Minimum Maximum Values 7 24 7 1 4 Fault Records 7 26 7 1 4 1 Viewing Fault Records 7 26 7 1 4 2 Saving the Fault Records 7 27 7 2 Control of Device Functions 7 28 7 2 1 Read and Set Date and Time 7 28 7 2 2 Changeover of Setting Groups 7 34 7 2 3 Test Messages to the System SCADA Interface during Test Operation 7 36 7 ...

Page 15: ...lure Protection 8 56 8 3 7 Current Voltage and Phase Rotation Checks 8 59 8 3 8 Directional Checks with Load Current 8 60 8 3 9 Polarity check for the voltage input U4 8 61 8 3 10 Earth Fault Check in a Non earthed System 8 63 8 3 11 Polarity Check for the Current Measuring Input I4 8 64 8 3 12 Measuring the operating time of the circuit breaker 8 68 8 3 13 Testing of the Teleprotection System 8 6...

Page 16: ... 1 6 Mechanical Stress Tests 10 11 10 1 7 Climatic Stress Tests 10 12 10 1 8 Service Conditions 10 12 10 1 9 Certifications 10 13 10 1 10 Construction 10 13 10 2 Distance Protection 10 15 10 3 Power Swing Supplement optional 10 18 10 4 Distance Protection Teleprotection Schemes 10 18 10 5 Earth Fault Protection in Earthed Systems optional 10 19 10 6 Earth Fault Protection Teleprotection Schemes op...

Page 17: ...10 44 10 22 Dimensions 10 47 A Appendix A 1 A 1 Ordering Information and Accessories A 2 A 1 1 Accessories A 10 A 2 General Diagrams A 13 A 2 1 Panel Flush Mounting or Cubicle Mounting A 13 A 2 2 Panel Surface Mounting A 27 A 2 3 Housing for Mounting with Detached Operator Panel A 41 A 3 Connection Examples A 51 A 4 Preset Configurations A 66 A 5 Protocol Dependent Functions A 75 B Appendix B 1 B ...

Page 18: ...xviii 7SA6 Manual C53000 G1176 C156 2 ...

Page 19: ...on 1 The SIPROTEC 4 devices 7SA6 are introduced in this chapter An overview of the devices is presented in their application features and scope of functions 1 1 Overall Operation 1 2 1 2 Applications 1 5 1 3 Features 1 8 1 4 Scope of Functions 1 9 ...

Page 20: ...t 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 transformer star point the earth current of a parallel line for parallel line compensation or the star point current of a power transformer for earth fault direction determination µC Error Run Output Relays allocatable LEDs on the...

Page 21: ...btains external information through binary inputs such as remote resetting or blocking commands for protective elements The µC issues information to external equipment via the output contacts These outputs include in particular trip commands to circuit breakers and signals for remote annunciation of important events and conditions Front Elements Light emitting diodes LEDs and a display screen LCD ...

Page 22: ...version there are one or two protection data interfaces Via these interfaces the data for the teleprotection scheme and further information such as closing the local circuit breaker other external trip commands coupled via binary inputs and binary information can be transmitted to other ends Power Supply The 7SA6 can be supplied with any of the common power supply voltages Transient dips of the su...

Page 23: ...us 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 lines with weak or no infeed at one line end it is possible to achieve fast tripping at both line ends by means of the signal tra...

Page 24: ... measured variables also binary commands or other information ordered variant can be transmitted The devices will automatically find the remaining healthy communication lines But even with two ends communication lines can be doubled to create redundancies Messages and Measured Values Storage of Data for Fault Recordings A series of operating messages provides information about conditions in the po...

Page 25: ...tion between the device and the control centre It can also be operated via data and fibre optic cables Standardized protocols for data transfer in accordance with IEC 60870 5 103 are available This profile also enables the integration of devices into the SINAUT LSA and SICAM automation systems As an alternative SIPROTEC 4 also provides a field bus interface with PROFIBUS FMS The PROFIBUS FMS accor...

Page 26: ...along the X axis reach and R axis arc resistance reserve and separate R setting for earth faults Direction determination is done with unfaulted loop quadrature voltages and voltage memory thereby achieving unlimited directional sensitivity Compensation of the influence of a parallel line during earth faults is possible Abundance of additional protective and control functions available some as opti...

Page 27: ...ble as forward reverse or non directional reaching one may be graded as an overreaching zone Nine time stages for the distance zones Direction determination is done with unfaulted loop quadrature voltages and voltage memory thereby achieving unlimited directional sensitivity and not affected by capacitive voltage transformer transients Current transformer saturation detection and compensation Comp...

Page 28: ...lization with second harmonic Earth fault protection with a tripping time dependent on zero sequence voltage Each stage can be set to be non directional or directional in the forward or reverse direction Direction determination with zero sequence system quantities I0 U0 with zero sequence current and transformer star point current I0 IY or with negative sequence system quantities I2 U2 One or more...

Page 29: ...n of displacement voltage Determination of earth faulted phases Sensitive determination of the earth fault direction Phase displacement correction for current transformers Automatic Reclosure optional For reclosure after single pole three pole or single and three pole tripping Single or multiple reclosure up to 8 reclosure attempts With separate action times for every reclosure attempt optionally ...

Page 30: ... of the distance to fault with dedicated measured value registers Fault location output in ohm kilometers or miles and of line length Parallel line compensation can be selected Optional function taking into consideration the load current in case of single phase earth faults fed from both sides Fault location output as BCD code or analog value dependent on the order variant Circuit Breaker Failure ...

Page 31: ... of the current and voltage transformer secondary circuits by means of summation and symmetry checks Trip circuit supervision is possible Checking for the load impedance the measured direction and the phase sequence Monitoring the signal transmission of the digital communication way optional Further Functions Battery buffered real time clock which may be sychronized via a synchronization signal DC...

Page 32: ...Introduction 1 14 7SA6 Manual C53000 G1176 C156 2 ...

Page 33: ... housing versions and available termination techniques are described The recommended and permitted data for the wiring is stated and suitable accessories and tools are given 2 1 Version of 7SA6 for Panel Flush Mounting Cubicle Mounting 2 2 2 2 Version of 7SA6 for Panel Surface Mounting 2 22 2 3 Version of 7SA6 with Detached Operator Panel 2 36 ...

Page 34: ...ted by means of flat ribbon cables and the corresponding plug connectors The rear plate screwed to the tube contains the required connectors for the external con nections to the device The front cover can be taken off after removal of the covers located at the 4 corners of the front cover and the 4 screws that are then revealed Housing size 1 1 has 2 ad ditional screw covers located at the centre ...

Page 35: ...s or execute changes such as setting changes 5 Numerical keys These keys serve for entry of numerical values such as limit value settings 6 Function keys Four function keys F1 to F4 allow the quick and simple execution of frequently used actions Typical applications include for example jumping to a particular po sition in the menu tree such as the fault data in the Trip Log or the measured val ues...

Page 36: ...ht emitting diodes LEDs The function of the 7 LEDs can be programmed There is a vast selection of sig nals from which to choose Some examples are device status processing or con trol information and binary input or output status Next to the LEDs on the front panel a labeling strip is provided on which the user specified LED functions may be written 10 Operating condition indicators The two LEDs RU...

Page 37: ...nd display elements is the same as explained after Figure 2 1 However 14 LEDs are freely configurable Figure 2 2 Front view of a 7SA61 housing size 1 2 for panel flush mounting or cubicle mounting SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA611 RUN ERROR MENU ESC LED ENTER F4 F1 F2 F3 Meas Val MAIN MENU 01 04 Annunciation Measurement Annunciation Trip log 1 2 ...

Page 38: ...ousing size 1 1 for panel flush mounting or cubicle mounting SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA6 RUN ERROR MENU ESC LED ENTER F4 F1 F2 F3 MAIN MENU 01 04 Annunciation 1 Measurement 2 Annunciation Meas Val Trip log The significance of the operating and display elements is the same as explained after Figure 2 1 However 14 LEDs are freely configurable ...

Page 39: ...e for controlling the process They are located below the LCD 5 Numerical keys These keys serve for entry of numerical values such as limit value settings 6 Function keys Four function keys F1 to F4 allow the quick and simple execution of frequently used actions Typical applications include for example jumping to a particular po sition in the menu tree such as the fault data in the Trip Log or the ...

Page 40: ...lection of sig nals from which to choose Some examples are device status processing or con trol information and binary input or output status Next to the LEDs on the front panel a labeling strip is provided on which the user specified LED functions may be written 12 Operating condition indicators The two LEDs RUN green and ERROR red indicate the operating condition of the device 13 Coverings for t...

Page 41: ...ure 2 6 shows a simplified view of the rear panel of a device with screw type termi nals Figure 2 6 Rear view of a 7SA6 housing size 1 3 terminal arrangement example only 1 2 3 4 5 6 7 8 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Ch1 Ch2 A B D F R Q UH UH C 1 2 3 4 5 6 7 8 9 10 11 12 AN20 20 mA 332R ...

Page 42: ...ype terminals Figure 2 8 Rear view of a 7SA6 housing size 1 1 terminal arrangement example only 1 2 3 4 5 6 7 8 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 A B D K J 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 R Q 1 2 3 4 5 6 7 8 9 10 11 12 Ch1 Ch2 F 1 2 3 4 5 6 7 8 9 10 11 12 C UH UH AN20 20 mA 332R 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Ch1 Ch...

Page 43: ...2 9 Connection plug module with screw terminals for voltage connections rear view Figure 2 10 shows an example of the allocation of an individual screw terminals to their terminal numbers Figure 2 10 Allocation of screw terminal to terminal number example Terminal Block for Current Connections There is one version of a terminal block for current connections to a 7SA6 The termi nal block is illustr...

Page 44: ...when working on the current transformer secondary circuits The short circuiting contacts of the current terminals are located on the housing side inside the terminal module connector while the operating pins are located on the mod ule side of the plug connector Connections to Voltage Terminals Ring type and fork type lugs may be used To ensure that the insulation paths are maintained insulated lug...

Page 45: ...convenience in making terminal connections The short circuit links can connect two neighbouring terminals located on the same side of the terminal module By connecting further links neighbouring terminals can be included in the short circuit On each terminal it is possible to connect two shot circuiting links or one short circuit link and one lug or one individual conductor The links meet the safe...

Page 46: ...driver 6x1 There are two types of covering caps as shown in Figure 2 13 Ordering information is provided in Section A 1 in the Appendix Figure 2 13 Covering caps for terminal blocks with screw terminals Covering cap for 18 terminal voltage Covering cap for 12 terminal voltage connection terminal block or 8 Terminal Current connection terminal block SIEMENS C73334 A1 C31 1 PCGF AMP SIEMENS C73334 A...

Page 47: ...and connection numbers letters Each plug in terminal forms a complete set of connections that consists of three pins arranged as follows Pin a Signal connection Pin b Common connection Pin c Shielding connection The signal pins are the only terminal pins that are directly connected to the internal printed circuit boards of the 7SA6 Depending on the version of the terminal block 18 or 12 signal con...

Page 48: ...ns are also connected to the housing Depending on the version of the terminal block 18 or 12 shielding connections are provided Figure 2 16 Schematic diagram of the plug in terminal blocks Connections to Plug In Terminals Connections to plug in terminals are made with pin connectors There are two versions of pin connectors Version 1 2 pin connector Version 2 3 pin connector Signal connection Commo...

Page 49: ...o 2 5 mm2 e g Bandware 4000 pieces type 0 827040 1 from Messrs Tyco Electronics AMP Individual piece type 0 827397 1 from Messrs Tyco Electronics AMP Connection of a conductor to a contact is performed using the following tools e g Hand crimping tool type 0 734372 1 from Messrs Tyco Electronics AMP Stencil type 1 734387 1 from Messrs Tyco Electronics AMP The use of individual pieces is recommended...

Page 50: ...The caps can be removed by turning them 90 to the left Figure 2 18 Optical communication interfaces with protective caps Connections to Optical Communication Interfaces with ST Connectors Optical connector type ST connector Fibre type Multimode graded index G optical fibre G50 125 µm G62 5 125 µm G100 140 µm Wavelength λ 820 nm approximately Allowable bending radius For indoor cable rmin 5 cm 2 in...

Page 51: ...unication interfaces with caps Connections to Optical Communication Interfaces with FC Connectors Optical connector type FC connector Fibre type Monomode 9 125 µm Wavelength λ 1300 nm approximately Allowable bending radius For indoor cable rmin 5 cm 2 in For outdoor cable rmin 20 cm 8 in ...

Page 52: ...endent on the type of interface RS232 EIA232 Five wire twisted and shielded e g interface cable 7XV5100 4 RS485 EIA485 Three wire twisted and shielded Profibus Two wire or four wire twisted and shielded Wire type A DIN 19245 part 2 and EN 50170 vol 2 twisted and shielded Wire Resistance 135 Ω to 165 Ω f 100 kHz Capacitance 30 nF km 48 nF mile Circuit resistance 110 Ω km 177 Ω mile Conductor diamet...

Page 53: ...uts of the 7SA6 The connector is illustrated in Figure 2 21 The pin assignments are de scribed in Subsection 8 2 1 Figure 2 21 9 pin D subminiature connectors Connections to Serial Communication Interfaces Standard 9 pin D subminiature plug connectors per MIL C 24308 and DIN 41652 can be used Communication cable Two wire four wire shielded Max load impedance 350 Ω 1 6 5 9 AN20 20 mA 332R ...

Page 54: ...covering caps and associated securing screws are located at the cen tre top and bottom of the front cover frame with the housing size 1 1 The surface mounting housing contains the wiring from the back plate to the screw terminal The front cover can be taken off after removal of the covers located on the 4 corners of the front cover and the 4 screws that are then revealed Housing size 1 1 has 2 ad ...

Page 55: ...enus 3 MENU key This key activates the main menu 4 ESC and ENTER keys These keys serve to escape from specific menues or execute changes such as setting changes 5 Numerical keys These keys serve for entry of numerical values such as limit value settings 6 Function keys Four function keys allow the quick and simple execution of frequently used ac tions Typical applications include for example jumpi...

Page 56: ...ose of resetting latched LEDs and the latched contacts of output relays as well as testing all of the LEDs 9 Light emitting diodes LEDs The function of these indicators can be programmed There is a vast selection of signals from which to choose Some examples are device status processing or control information and binary input or output status Next to the LEDs on the front panel a labeling strip is...

Page 57: ...for panel flush mounting without optical communication interfaces 74 73 72 11 70 69 68 67 66 75 90 89 88 87 86 85 79 84 83 82 81 80 78 77 76 64 63 62 61 60 54 59 58 57 56 55 53 52 51 65 100 99 98 97 96 95 94 93 92 91 27 28 29 30 31 32 33 34 35 11 12 13 14 L L 22 17 18 19 20 21 23 24 25 37 38 39 40 41 47 42 43 44 45 46 48 49 50 36 1 2 3 4 5 6 7 8 9 10 SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA611 RUN...

Page 58: ...90 91 97 92 93 94 95 96 98 99 100 85 26 27 28 29 30 31 32 33 34 35 11 12 13 14 15 16 22 17 18 19 20 21 23 24 25 1 2 3 4 5 6 7 8 9 10 124 123 122 121 120 119 118 117 116 125 149 148 147 146 145 144 143 142 141 150 139 138 137 136 135 129 134 133 132 131 130 128 127 126 140 165 164 163 162 161 160 154 159 158 157 156 155 153 152 151 114 113 112 111 110 104 109 108 107 106 105 103 102 101 115 175 174...

Page 59: ...s serve for controlling the process They are located below the LCD 5 Numerical keys These keys serve for entry of numerical values such as limit value settings 6 Function keys Four function keys F1 to F4 allow the quick and simple execution of frequently used actions Typical applications include for example jumping to a particular po sition in the menu tree such as the fault data in the Trip Log o...

Page 60: ...terlocked operation 9 9 pin female D subminiature connector This serial interface is for the connection of a local PC running DIGSI 4 10 LED key This key has the dual purpose of resetting latched LEDs and the latched contacts of output relays as well as testing all of the LEDs 11 Light emitting diodes LEDs The function of the 14 LEDs are freely configurable There is a vast selection of signals fro...

Page 61: ...es are withdrawn This does not reduce necessary care that must be taken when working on the current transform er secondary circuits 77 78 79 80 81 82 83 84 85 76 52 53 54 55 56 57 58 59 60 62 63 64 65 66 72 67 68 69 70 71 73 74 75 61 36 L L 39 40 41 47 42 43 44 45 46 48 49 50 87 88 89 90 91 97 92 93 94 95 96 98 99 100 85 26 27 28 29 30 31 32 33 34 35 11 12 13 14 15 16 22 17 18 19 20 21 23 24 25 1 ...

Page 62: ...cal communication interfaces may be 1 to 4 channel The ports are supplied with caps to protect the optical components against dust or other contaminants The caps can be removed by turning them 90 to the left A maximum of two fibre optic channels are located in each inclined housing In the case of device versions with 1 and 2 channels the inclined housing is located at the bottom side of the device...

Page 63: ...2 28 the channels B and C are fitted Figure 2 28 Inclined housing with optical communication interfaces example channel B and C fitted For the device variant with the electrical Profibus interface RS485 and DNP3 0 a direct fibre communication connection in the surface mounting housing is not possible For Housing for optical communication interfaces channel D and E Housing for optical communication...

Page 64: ...G100 140 µm Wavelength λ 820 nm approximately Allowable bending radius For indoor cable rmin 5 cm 2 in For outdoor cable rmin 20 cm 8 in Laser class 1 acc EN 60825 1 is achieved with fibre type G50 125 µm and G62 5 125 µm Optical Interfaces FC Connector Optical communication interfaces with FC connectors are provided with 1 channel or 1 to 2 channels The ports are supplied with caps to protect the...

Page 65: ...ions channel D and E fitted Connections to Optical Communication Interfaces with FC Connectors Optical connector type FC connector Fibre type Monomode 9 125 µm Wavelength λ 1300 nm approximately Allowable bending radius For indoor cable rmin 5 cm 2 in For outdoor cable rmin 20 cm 8 in Kanal B Kanal D Kanal C Kanal E ...

Page 66: ...nd DIN 41652 can be used The necessary communication cables are dependent on the type of interface RS232 EIA232 Five wire twisted and shielded e g interface cable 7XV5100 4 RS485 EIA485 Three wire twisted and shielded Profibus Two wire or four wire twisted and shielded Wire type A DIN 19245 part 2 and EN 50170 vol 2 twisted and shielded Wire Resistance 135 Ω to 165 Ω f 100 kHz Capacitance 30 nF km...

Page 67: ...tor is illustrated in Figure 2 32 The pin assignments are de scribed in Subsection 8 2 1 Figure 2 32 Inclined housing with 9 pin D subminiature connectors Connections to Serial Communication Interfaces Standard 9 pin D subminiature plug connectors per MIL C 24308 and DIN 41652 can be used Communication cable Two wire four wire shielded Max load impedance 350 Ω Channel B Channel D Channel C Channel...

Page 68: ... from 1 to 42 designating the mounting positions of the modules The connection between the modules and to the front cover is by means of flat ribbon cables and the corresponding plug connectors The rear plate screwed to the tube contains the required connectors for the external connec tions to the device The name plate containing the principal data of the device such as auxiliary supply voltage th...

Page 69: ...d operator panel housing size 1 2 1 2 3 4 5 6 7 8 D UH 9 c 7 c 5 c 3 1 a b c 2 4 6 8 10 12 14 16 18 a b c 13 c 11 c 15 c 17 c 9 7 5 3 1 a b c 2 4 6 8 10 12 a b c 11 9 7 5 3 1 a b c 2 4 6 8 10 12a b c 14 16 18 a b c 13 11 15 17 SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA641 RUN ERROR MENU ESC LED CTRL ENTER F4 F1 F2 F3 Remote Normal Local Test Schlossplatz Abzweig erden mit F4 21 kV 1000 A F K J UH A ...

Page 70: ...s The terminal screws have a slot head for tightening or loosening with a flat screw driv er sized 6 1 mm Terminal Blocks for Voltage Connections The voltage connection terminal modules are available in 2 variants Figure 2 9 B UH F K J UH 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18...

Page 71: ...l Block for Current Connections There is one version of a terminal block for current connections to a 7SA6 The termi nal block is illustrated in Figure 2 11 The correlation between the terminals and their terminal numbers is the same for the current terminals as shown in Figure 2 10 Figure 2 37 Terminal block of screw terminals for current connections rear view 18 terminal 12 terminal 1 2 3 4 5 6 ...

Page 72: ... used To ensure that the insulation paths are maintained insulated lugs must be used Alternatively the crimping area must be in sulated with other methods e g by covering with a shrink sleeve The following must be observed Connections with cable lugs inner diameter of lugs 4 mm maximum outer diameter of lugs 10 mm conductor with cross section of 1 mm2 to 2 6 mm2 AWG 16 to 14 Use copper wires only ...

Page 73: ...shock There are two types of links one for voltage connections and one for current connec tions The links are illustrated in Figure 2 12 Ordering information for the links is pro vided in Section A 1 in the Appendix Figure 2 38 Short circuit links for voltage connections and current connections Covering Caps Terminal covering caps are available for the screw terminal modules to increase the protec...

Page 74: ...ltage Connections There are two versions of plug in terminal blocks They are shown in Figure 2 14 Figure 2 40 Terminal blocks of plug in terminals for voltage connections rear view Covering cap for 18 terminal voltage Covering cap for 12 terminal voltage connection terminal block or 8 Terminal Current connection terminal block SIEMENS C73334 A1 C31 1 PCGF AMP SIEMENS C73334 A1 C32 1 PCGF AMP 18 te...

Page 75: ...s of common pins Within a group the pins are inter con nected as shown in Figure 2 16 The common pins b are not connected to the boards inside the 7SA6 Each common group can for example be used for signal multiplica tion or as a common point for a signal independent of the signals on the pin a termi nals Depending on the version of the terminal block 18 or 12 common connections are available Group...

Page 76: ...s connection only to pins a and b An erroneous connection to pins b and c is excluded The pin connectors snap in to the plug in terminals The connectors can be removed without tools Control wires are connected to contacts of the pin connectors Wires with 0 5 mm2 to 2 5 mm2 diameter AWG 20 to 14 can be accommodated Signal connection Common connection Shielding connection Common connections group 1 ...

Page 77: ... AMP Connection of a conductor to a contact is performed using the following tools e g Hand crimping tool type 0 539635 1 from Messrs Tyco Electronics AMP Stencil type 1 539668 2 from Messrs Tyco Electronics AMP The use of individual pieces is recommended After the wires are crimped the contacts are pressed into the terminals of the connec tor until they snap into place Stress relief for individua...

Page 78: ...e G50 125 µm and G62 5 125 µm Optical Interfaces FC Connector Optical communication interfaces with FC connectors are provided with 1 channel or 1 to 2 channels The ports are supplied with caps to protect the optical components against dust or other contaminants They can be removed from the interfaces The fibre optic channels are located in an inclined housing The inclined housing is at the top si...

Page 79: ... 2 Connections to Optical Communication Interfaces with FC Connectors Optical connector type FC connector Fibre type Monomode 9 125 µm Wavelength λ 1300 nm approximately Allowable bending radius For indoor cable rmin 5 cm 2 in For outdoor cable rmin 20 cm 8 in ...

Page 80: ...dent on the type of interface RS232 EIA232 Five wire twisted and shielded e g interface cable 7XV5100 4 RS485 EIA485 Three wire twisted and shielded Profibus Two wire or four wire twisted and shielded Wire type A DIN 19245 part 2 and EN 50170 vol 2 twisted and shielded Wire Resistance 135 Ω to 165 Ω f 100 kHz Capacitance 30 nF km 48 nF mile Circuit resistance 110 Ω km 177 Ω mile Conductor diameter...

Page 81: ...ts of the 7SA6 The connector is illustrated in Figure 2 47 The pin assignments are de scribed in Subsection 8 2 1 Figure 2 47 9 pin D subminiature connectors Connections to Serial Communication Interfaces Standard 9 pin D subminiature plug connectors per MIL C 24308 and DIN 41652 can be used Communication cable Two wire four wire shielded Max load impedance 350 Ω n 1 6 5 9 AN20 20 mA 332R ...

Page 82: ...Hardware and Connections 2 50 7SA6 Manual C53000 G1176 C156 2 ...

Page 83: ...the operating menus of the device us ing the operator control panel on the front of the device and the operator control win dows in DIGSI 4 For personnel inexperienced with the 7SA6 these checks also pro vide a quick and simple method for understanding the operation of the control panel and DIGSI 4 The electrical tests can be done without measuring quantities being ap plied Observations relevant t...

Page 84: ...ce booklet and all notes and hints that are en closed in the packaging The transport packaging can be reused in the same manner for further transport Stor age packaging alone for the individual devices is not sufficient for transport If alter native packaging is used shock requirements according to IEC 60255 21 1 Class 2 and IEC 60255 21 2 Class 1 must be met The device should be in the final oper...

Page 85: ...rature equilibrium and prevents dampness and con densation from occurring Power Up For a first electrical inspection of the device it is sufficient to ensure safe grounding of the housing and to apply the power supply voltage o Connect the ground of the device solidly to the ground of the location The ground of a 7SA6 designed for flush mounting is on the rear panel the ground of a device de signe...

Page 86: ...on of firmware imple mented and the serial number G When the device is ready for operation first press the key The MAIN MENU ap pears G Using the key select the menu item Settings and move to the device settings using the key The SETTINGS menu appears as shown in Figure 3 1 G Using the key select the menu item Setup Extras and switch to the selection SETUP EXTRAS using the key See Figure 3 2 Figur...

Page 87: ...ress the key The MAIN MENU appears G Using the key select the menu item Annunciation and switch to the annun ciations using the key The ANNUNCIATION sub menu appears G Using the key select the menu item Event Log and move to the EVENT LOG sub menu using the key The last number in the upper right corner of the display indicates the number of oper ational messages stored in memory The number before ...

Page 88: ...erwrite the present setting with the desired setting using the numerical keys The setting range is 11 to 22 G Confirm the change with the key or cancel the change with the key Exit the sub menu using the key or return to the main menu using the key Figure 3 3 Operating sub menu for adjusting the display contrast 3 3 2 Operation Using DIGSI 4 DIGSI 4 User Interface DIGSI 4 has the typical PC applic...

Page 89: ...e newly opened window Then click in the menu bar the item Device and select the option DIGSI Device Plug Play as shown in Figure 3 5 The Plug Play dialogue box opens as shown in Figure 3 6 Figure 3 5 Window with selection of Plug and Play G Enter the designation of the PC serial interface COM 1 2 3 or 4 and select in the dialogue box under Frame the transfer format to be used in making the connect...

Page 90: ...ctory tree G By clicking on one of the menu items offered there the associated contents become visible in the right window Figure 3 7 DIGSI 4 online initial screen example Viewing Measured Values As an example the procedure for viewing the measured values is described G Double click on Measurement in the navigation window left G Double click on the subdirectory Secondary Values in the navigation w...

Page 91: ...eration al Messages The read out of operating messages is described to serve as an additional example G Double click on Annunciation in the navigation window G Click on Event Log in the function selection The present date and time are shown in the data window G Double click on this entry in the data window A table of the accumulated event messages is displayed See Figure 3 10as an ex ample The num...

Page 92: ...y is pressed G The message Reset LED appears as the newest message as soon as the window is updated The window can be updated by clicking on View in the menu bar and then on Refresh Pressing the F5 function key on the keyboard also updates the window The operating messages can be saved in DIGSI 4 and also deleted from the de vice s memory as described in Sub section 7 1 1 LED ...

Page 93: ...d shows the present date and the approximate present time according to the device The day of the week is automatically derived from the date and cannot be edited Edit the input fields Date and Time The format depends on your regional settings of the PC See Figure 3 12 Date mm dd yyyy or dd mm yyyyy Time hh mm ss Click OK to download the entered values to the device The former values are changed an...

Page 94: ...y of the device should be energized approx imately every two years for one or two days to regenerate the electrolytic capacitors in the power supply This procedure should also be done prior to the device being put in service Under extreme climatic conditions tropics pre warming is achieved at the same time and condensation is prevented After long storage power should not be applied until the devic...

Page 95: ...specific device some of the functions discussed may not be available Details about the extent of the functions of the devices the individual settings and the representation structure of the system data are found in the following chapters and the DIGSI 4 instruction book 4 1 General 4 2 4 2 Operator Control Facilities 4 5 4 3 Information Retrieval 4 8 4 4 Control 4 14 4 5 Manual Overwrite Tagging 4...

Page 96: ...with separate protective and process control functions or select a solution that implements both requirements The following solutions are available G Protection and control in separate devices G Protective devices that provide the capability to control the circuit breaker or primary switching device through a communication interface G Devices with combined features that in addition to protective f...

Page 97: ...tres SCADA In the case when commands are sent to the devices equally flexible processing is possible that is substation switching operations can be initiated from the network control centres as well as from the operation and observation unit of the substation control system Operation and Observation SICAM WinCC DIGSI 4 SICAM SC To Network Control Centers IEC 60870 5 101 IEC 60870 5 103 Profibus FM...

Page 98: ...on a normal personal computer For local use the PC is connect ed to the operating serial interface on the front panel of the device 4 1 4 Operations All on site operations of a SIPROTEC 4 device can be done with DIGSI 4 Exam ples of operations are switching retrieval of information or changing of setting groups These operations can also be performed using the operator control panel on the front of...

Page 99: ... with Four Line Display Figure 4 2 SIPROTEC 4 Device operator control panel with four line display examples Note Refer to Chapter 2 to determine the type of operating field for your specific SIPROTEC 4 device SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA522 RUN ERROR MENU ESC LED ENTER F4 F1 F2 F3 Event Log Operation MAIN MENU 01 05 Annunciation 1 Measurement 2 SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA5...

Page 100: ...device and movement within the op erator control display are accomplished with the keys G The main menu is opened with the key G Changes are cancelled or confirmed with the and keys respectively G Numerical values are entered with the to keys the key for a decimal point and the key for a negative sign If a value of infinity is desired press the decimal point key twice appears in the display G The ...

Page 101: ...so selected in this matrix The setting options are presented in an easy to read tabular format Parts of the matrix can be minimized or expanded as desired to simplify the displayed sections and therefore the setting process Filter functions can reduce the size of the matrix to display only relevant information Passwords Password entry is required for tasks such as changing settings executing contr...

Page 102: ...station control system then information transfer can take place via a connection to the system interface of the SIPROTEC 4 device to G higher level control systems or G substation control devices e g SICAM SC Local On site the operator control panel of the SIPROTEC 4 device can be used to retrieve information DIGSI 4 Information retrieval is simple and fast when DIGSI 4 is used For local use conne...

Page 103: ...messages about switching operations or monitoring functions G Trip Log Fault messages G General interrogation display of present condition messages G Spontaneous messages continuous display of important messages from the de vice e g after faults switching operations etc Figure 4 3 DIGSI 4 annunciations example Display in DIGSI 4 To view the indications in DIGSI 4 Online Select Annunciation in the ...

Page 104: ...ip Log Figure 4 4 SIPROTEC 4 device display of operating messages in the event log ex ample Figure 4 5 SIPROTEC 4 device display of fault messages example ANNUNCIATION 01 05 Event Log 01 Trip Log 02 MAIN MENU 01 05 Annunciation 1 Measurement 2 EVENT LOG 19 19 06 19 98 11 52 05 461 Reset LED ON TRIP LOG 01 08 Last Fault 1 2nd Last Fault 2 LAST FAULT 01 10 06 22 98 23 49 34 845 Network Fault 6 ON ...

Page 105: ...as ured values G Percentage values relative to nominal ratings G Other values calculated by the device e g thermal values or user defined values G Statistics values Figure 4 6 DIGSI 4 measured value display example Display in DIGSI 4 To display the measured values in the DIGSI 4 Online Select Measurement in the navigation left window The measured value groups appear in the data right window Double...

Page 106: ...01 12 Operation pri 01 Operation sec 02 MAIN MENU 02 05 Annunciation 1 Measurement 2 MEASUREMENT 01 12 Operation pri 01 Operation sec 02 OPERATION PRI 02 24 IL1 1062 8A IL2 1081 5A Note Measured values can also be displayed in the default display and the control display Prior to this the measured values to be indicated have to be configured in the config uration matrix under settings in DIGSI 4 Th...

Page 107: ... 4 program is used to convert the oscillographic data into graphical rep resentations that can be used to analyse the fault or the event captured by the device DIGRA 4 calculates additional values from the waveform data e g impedances and rms values and displays the captured and calculated values in G analogue curves with timebase time signals G phasor diagrams G locus diagrams and G harmonic grap...

Page 108: ...AM SC Local On site the SIPROTEC 4 device offers the possibility to control a circuit breaker or primary switching equipment using the operator control panel For devices with a four line display switching operations are controlled using Main menu Control Breaker Switch Control Equipment and in tended direction ON or OFF Figure 4 9 or The Function Keys F1 to F4 The functionality of these keys is pr...

Page 109: ...ed design tool CFC for logic functions in DIGSI 4 infor mation can be logically combined Command outputs can be derived from the output of logic functions The link of the output of the CFC functions to the respective device outputs is determined in the configuration matrix Passwords Only authorized personnel can perform switching operations Switching operations are protected by passwords Interlock...

Page 110: ...ecting the wires This function is activated using the op erator control panel Main Menu Control Breaker Switch Set Status Tagging To identify unusual operating conditions in the power system tagging can be done The tagging can for example be entered as additional operating conditions in inter locking checks which are set up with CFC Tagging is configured in the same way as for operating devices Th...

Page 111: ...s buffers system port etc I O configu ration G defining user definable logic functions CFC q Specific Settings G settings for all elements to be used G settings of the protective functions G settings of the process control functions Settings are first done Off line The settings are then loaded into the SIPROTEC 4 device on site using the operating serial interface or remotely by modem and the serv...

Page 112: ...t the passwords Setting steps partially build on the decisions from the previous steps By following the sequence listed unnecessary changes and rework are avoided The sequence en sures that information required for an individual step will be available To design the control display for example the physical connections between the de vice and the primary equipment must be known These connections are...

Page 113: ...he LCD using Main Menu Settings e g Masking I O Change settings such as date and time using Main Menu Settings Setup Extras Figure 4 14 Changing settings using the operator control panel example MAIN MENU 04 05 Annunciation 1 Measurement 2 Control 3 Settings 4 Test Diagnose 5 SETTINGS 10 11 Device Config 01 Masking I O 02 P System Data1 03 Group A 04 Group B 05 Group C 06 Group D 07 Change Group 0...

Page 114: ...ling in the Device Configuration area of the settings To specify the active functions using DIGSI 4 Double click on Device Configuration in the data window Click on the individual fields and select the functions to be enabled Figure 4 15 DIGSI 4 setting the device configuration example The device configuration can be viewed from the operator control panel on the SIPROTEC 4 device In the main menu ...

Page 115: ... keys on the operating field e g assigned switching operations etc as the origin of the information G CFC programmable logic user specific logic outputs as the origin of the informa tion q Destination of the information with G binary outputs for the output of signals G LED display of information on the device front e g messages G system interface transmission of information e g to a substation con...

Page 116: ... view so that you can view only the sections of the total matrix that are relevant New Information A further function of the configuration matrix is the capability to define new information This is accomplished by inserting a new line defining the appropriate information type and assigning it to a source and a destination The new information can also be dis played in the LCD of the SIPROTEC 4 devi...

Page 117: ...individual messages that are to be combined to form a grouped message must be marked in the Destination C column The logic s output the grouped message in this example is derived from the Source C column Viewing the Config uration on the Operating Panel The configuration can be seen on the operating panel of the SIPROTEC 4 device In the main menu select Settings Masking I O In the next menu select...

Page 118: ...modules that are specially created for the requirements of process control engineering e g MAX MIN etc are available The CFC modules are combined to form complete CFC logic functions in order to G perform system specific checks e g interlocking G generate messages if measured values approach a critical value or G build group messages for transfer to a substation control systems Figure 4 19 DIGSI 4...

Page 119: ...SIPROTEC 4 Devices 4 25 7SA6 Manual C53000 G1176 C156 2 Figure 4 20 CFC Logic example ...

Page 120: ... data such as frequency voltage etc G data for the main current transformers and voltage transformers G circuit breaker or primary switch gear information Figure 4 21 DIGSI 4 setting the power system data example Power System Data 2 Power System Data 2 are part of the setting groups which can be switched over dur ing operation see chapter 4 11 These include for example G Primary Operating Voltage ...

Page 121: ...the ca pability of optimizing the protection and control for the existing configuration of the net work being protected In other words the protection and control can be changed as the network changes The setting groups are saved in the device The setting groups can be changed during operation using DIGSI 4 from the operator control panel on the device by triggering binary inputs or via the system ...

Page 122: ...r a protective function example Changing Setting Groups The setting groups can be changed during operation using DIGSI 4 from the opera tor control panel on the device by triggering binary inputs or via the system interface The active setting group is indicated Figure 4 24 SIPROTEC 4 device changing setting groups on the operator control panel CHANGE GROUP 02 02 0301 ACTIVE GROUP Group A 0302 CHAN...

Page 123: ...ation of network faults on the LEDs and the LCD on the front of the SIPROTEC 4 device are defined in the DIGSI 4 window shown in Figure 4 25 Figure 4 25 DIGSI 4 general device settings targets example The setting can also be changed at any time using the operator control panel on the SIPROTEC 4 device Main Menu Settings Device ...

Page 124: ... pin D subminiature port on the back panel of the device Setting of the time synchronization is done exclusively with DIGSI 4 Double click on Time Synchronization in the data window and enter the set tings Figure 4 26 DIGSI 4 setting of the time synchronization example Read out on the Operator Control Panel Using the SIPROTEC 4 device operator control panel the time synchronization set tings can b...

Page 125: ...4 is installed Via this interface the settings can be loaded and all DIGSI 4 operations can be applied e g read out of oscillographic fault records or event logs G The service interface on the back panel is for connection to a PC of remote diag nostic facilities e g DIGSI 4 via modem and or a star connection All DIGSI 4 op erations are possible via this interface In the DIGSI 4 interface settings ...

Page 126: ...hecked using the SIPROTEC 4 device operator con trol panel In the main menu select Settings Setup Extras Serial Ports follow ing menus Figure 4 29 Read out of serial interface settings from the operator control panel example SERIAL PORTS 01 03 Front Port 1 System Port 2 Service Port 3 SETUP EXTRAS 03 06 Date Time 1 Clock Setup 2 Serial Ports 3 Device ID 4 MLFB Version 5 5 Contrast 6 Note The seria...

Page 127: ... G Hardware test menus G Individual settings G Setting Groups Figure 4 30 DIGSI 4 window indicating the active passwords example When using DIGSI 4 or the operator control panel on the SIPROTEC 4 device a password is requested for the specific functions Note Password protection against unauthorized access is only in place during on line op eration The passwords for setting changes are first activa...

Page 128: ...ew password and confirm with the new password again and OK Figure 4 31 DIGSI 4 changing passwords Passwords are numbers up to 8 digits At delivery all passwords are set to 000000 n Note If the password for setting group switching has been forgotten a temporary password can be received from Siemens The temporary password can be used to define a new password for this function The registration number...

Page 129: ...d via which outputs Which user definable functions need to be performed in CFC Continuous Function Chart Which information should be displayed on the front panel of the device Which interfaces are to be used Which time source is to be used to synchronize the internal clock This chapter describes in details how to configure the 7SA6 5 1 Configuration of Functions 5 2 5 2 Configuration of the Binary...

Page 130: ...e 7SA6 There are no messages and corresponding settings functions limit values are not displayed dur ing detailed settings Determination of Functional Scope Configuration settings may be entered using a PC and the software program DIGSI 4 and transferred via the operating interface on the device front or via the serial service interface Operation via DIGSI 4 is described in Chapter 4 as well as in...

Page 131: ...es at least one protection data interface For more ends it must be guaranteed that all associated devices are connected with each other either directly or via other devices For more detail on this topic read Section 6 4 Communication Topology If the setting group change over function is used the setting in address 103 Grp Chge OPTION must be set to Enabled In this case it is possible to apply up t...

Page 132: ...tection Interface These schemes are described in detail in Subsection 6 6 1 If the teleprotection supplement is not re quired for the distance protection the setting must be Disabled The tripping characteristic group of the time delayed overcurrent protection can be set in address 126 Backup overcurrent Back Up O C In addition to the definite time overcurrent protection DT an inverse time overcurr...

Page 133: ...hen single pole or single three pole automatic reclosure cycles are planned and are possible In this case different dead times for every interrupt cycle are pos sible after single pole tripping and after three pole tripping The tripping protection function determines the type of tripping single pole or three pole The dead time is controlled dependent on this Using the Pickup with T action or Picku...

Page 134: ...current U I phi voltage angle con trolled o c Disabled Z quadrilateral Distance protection pickup pro gram 120 Power Swing Disabled Enabled Disabled Power Swing detection 121 Teleprot Dist PUTT Z1B acceleration PUTT acceleration with Pik kup POTT Directional Comparison Pik kup Unblocking Blocking Reverse Interlocking Pilot wire comparison POTT over Protection Inter face Disabled Disabled Teleprote...

Page 135: ...th Pickup but without Action time with Trip and Action time with Trip but without Action time with Trip and Action time Auto Reclose control mode 135 Synchro Check Disabled Enabled Disabled Synchronism and Voltage Check 137 U O VOLTAGE Disabled Enabled Disabled Under Overvoltage Protection 138 Fault Locator Enabled Disabled with BCD output Enabled Fault Locator 139 BREAKER FAILURE Disabled Enabled...

Page 136: ...location d km Fault location d miles Trip current Imax primary Disabled Analog Output B2 Port B 152 AnalogOutput D1 Disabled IL2 UL23 P Q Fault location d Fault location d km Fault location d miles Trip current Imax primary Disabled Analog Output D1 Port D 153 AnalogOutput D2 Disabled IL2 UL23 P Q Fault location d Fault location d km Fault location d miles Trip current Imax primary Disabled Analog...

Page 137: ...rior to changing the configuration 5 2 1 Preparation Before configuration is started the overall interfacing requirements must be assessed The required inputs and outputs must be coordinated with the number of physical in puts and outputs present on the relay The types of indications and commands and their requirements must be taken into account Indications Indications may be device information re...

Page 138: ...puts of a SIPROTEC device As soon as the type of command is defined DIGSI 4 allocates the necessary number of binary outputs of a device The corresponding outputs relays are numbered consec utively This has to be observed for the assignment of the output relay to the control functions Table 5 1 lists the most important command types as they are offered in the configu ration matrix also refer to th...

Page 139: ... common to a bus L L Control voltage Figure 5 4 Single command with single contact Double Command with Single Output common to a bus With at least 3 relays without feedback with feedback C_D2 CF_D2 Double Command with Double Output With 4 relays without feedback with feedback C_D4 CF_D4 Double Command with Double Close and Single Trip Output With 3 relays without feedback with feedback C_D12 CF_D1...

Page 140: ...e relay common to a bus automatically adopts the properties of the controlling relay i e it is not configured individually The output is single pole Figure 5 7 Double command with single output common to a bus CLOSE Command C C TRIP Command t CLOSE TRIP Switching Device C C L L Matrix Configuration C X 1 C X 2 CLOSE Command C C TRIP Command CC t CLOSE TRIP Switching Device C C L L CC Matrix Config...

Page 141: ...can be connected When using the power relay for a motor controlled three position disconnector please observe the following For the disconnector and earth switch function the same output relays are controlled by two different commands Since both end positions are achieved by different rotation of the motor one of the two commands must be negated Therefore the command types e g CF_D2 and CF_D2N are...

Page 142: ...e internal grouping see also General Diagrams in Subsection A 2 Appendix A Figures A 4 A 9 A 15 A 19 A 23 and A 27 Figure 5 10 Double command motor control anti clockwise rotation clockwise rotation via two power relays with two contacts each Figure 5 11 Extract of a general diagram of the variants with power relays BO 6 to BO 9 as an example showing the external connections according to Figure 5 ...

Page 143: ...s via 2 power relays with 2 contacts each setting Double Command with Single Output example CLOSE Command C TRIP Command C t C 1 C 1 C 2 C 2 CLOSE TRIP Switching Device The relays characterized with a minus symbol must not be connected in different way Matrix Configuration C 6 C X 7 8 9 X L L ...

Page 144: ...a the operator or service interface The configuration is represented in DIGSI 4 as a matrix Figure 5 13 Each row is assigned to an information of the de vice It is identified by a function number No LCD text display text D an explanation long text L minimized in Figure 5 13 and an information type T The columns give the interfaces which should be the sources and or destinations of the information ...

Page 145: ... rows is reduced allowing the user to focus on the information groups of interest A second double click restores all rows in the information group To limit the width of the matrix two possibilities exist The tool bar allows to switch be tween standard view and short view or individual columns can be hidden In the latter case you double click on the field with the column heading thus hiding the con...

Page 146: ...nnunciations SP Single Point Indication binary input e g LED reset refer also to subsection 5 2 1 DP Double Point Indication binary input refer also to subsection 5 2 1 OUT Output Indication protection output signals e g pickup trip IntSP Internal Single Point Indication IntDP Internal Double Point Indication TxTap Transformer Tap Indication Control Commands for switching devices refer to subsecti...

Page 147: ... CFC Program of the User definable Logic CM Control of switchgears if a switch plant is indicated in the Control Menu of the device 5 2 3 Establishing Information Properties General Different types of information contain different types of properties To view the proper ties associated with a specific information unit indication command etc position the mouse on the specific row under Information a...

Page 148: ...tput Indication OUT Figure 5 14 Information properties example for the information type Output Indication OUT Internal Single Point Indication IntSP Figure 5 15 Information properties example for the information type Internal Single Point Indication IntSP ...

Page 149: ...ay be checked to suppress the interme diate indication during operations If this field is marked then the filter time which can also be set see margin heading Filtering Contact Chatter Suppression below is only effective for the intermediate undefined position indication Hence briefly un defined conditions or contact chattering will not lead to an alarm however defined changes in the condition fin...

Page 150: ...emselves are set the same for all input indications see Sub section 5 2 6 Transformer Tap Changer TxTap The transformer tap changer position is communicated via binary inputs in a speci fied encoding format maximum of 62 positions Only binary inputs that are in direct order with regard to numbering can be used For the encoding formats available binary code BCD code 1 of n code four set tings numbe...

Page 151: ... Using three binary inputs 3 bits a maximum of 23 8 position settings may be rep resented in binary code In order to begin the representation of transformer tap chang er positions with the value 3 the display offset is chosen accordingly The following must be set on the information property window Encoding Binary Number of taps 4 Number of bits 3 Display offset 2 Tap interval 1 The three binary in...

Page 152: ...pon start up is set for 120 A Metered Values For metered values the polarity is an indicator for the direction of the power flow Figure 5 20 and 5 21 For the metered values of measured values MVMV the user may also define the units for pulsed measured values PMV Figure 5 20 the conver sion factor and the number of decimal places Figure 5 21 If wiping pulse S0 is selected each individual impulse in...

Page 153: ...Configuration 5 25 7SA6 Manual C53000 G1176 C156 2 Figure 5 20 Information Properties Example for Information Type Pulse Metered Value PMV ...

Page 154: ...lf Such user defined groups and information may be deleted at any time in contrast to predefined groups and information In order to insert a new information group click on a cell within a group that is next to the location where the new group should be located After pressing the right mouse button a context menu appears Figure 5 22 Figure 5 22 Dialogue box to insert a new information group example...

Page 155: ...f the catalog correspond to the information groups Annunciations Com mands Measured Values and Counter Values To insert a specific information unit into an information group first select it in the cat alog and using the left mouse button it should then be dragged from the information catalog window to a group area on the left of the matrix After the mouse button is re leased the new information un...

Page 156: ...fer X allocated or _ not allocated as the configuration choices In other cases three options will be offered e g L latched U unlatched and _ not allocated Entries resulting in an implausible configuration are blocked and inaccessible to the user Configuring Binary Inputs as Sources Single point indications double point indications transformer tap indications and pulse metered values can all be con...

Page 157: ... Function Key as a Source The four function keys on the front of the relay may also be configured as sources in order to establish a link using CFC In this situation each function key may be linked with one single internal indication A function key may be occupied because it has al ready been set as an operating function for the relay As delivered from the factory the device s function keys F1 F2 ...

Page 158: ...f the device or via a binary input with the indication function LED Reset or via the serial system interface If unlatched is selected the output relay disengages as soon as the indication disappears Fast Binary Outputs Some binary outputs of device 7SA6 depending on the order variant refer to Gen eral Diagrams in Section A 2 of Appendix A have a response time which is approx 3 ms shorter Therefore...

Page 159: ...atter means independent of the switching direction an indication is issued during each operation of the switching device For double commands with a common output a fourth alternative C Common contact appears Using this the binary output may be defined as the common output common contact When this is the case several double commands with common contacts may be assigned to the same common output com...

Page 160: ...ns in the device created with CFC are processed for interlocked switching Switching direction check scheduled actual The switching command is negated and a corresponding indication is issued if the circuit breaker is already in the scheduled position As soon as this check is activated the switching direction check will not only be enabled for interlocked but also for non interlocked switching Bloc...

Page 161: ...s cf also margin header Configuring Binary Outputs as a Destination on page 5 30 When doing this you may select whether the indications are to be latched L or un latched U If you select latched the assigned LED remains energized even after the indication is no longer present It must be manually reset by pressing the LED Reset button on the front panel of the device or via a binary input with the i...

Page 162: ...he information can be used in the default and control display Configuring the Control as a Destination Single point and double point indications as well as all types of commands can be al located to the control as a destination Thus they are available for the operational con trol in the display of the device and the DIGSI 4 Menu Control Configuring the Measured Value Window as a Destination In add...

Page 163: ...ed Selection of binary inputs is illustrated in Figure 5 30 Figure 5 30 Reading the configuration in the front display of the device example Information regarding a binary input may be displayed by using the navigation keys to select the binary input See Figure 5 31 Figure 5 31 Selection of binary input 2 example In the example of Figure 5 31 information is displayed regarding binary input 2 The d...

Page 164: ...og box which contains a register for editing the individual values for cyclical transferring will open Cyclical Restoration Here the user may specify the source of the cyclical trigger for the transfer Also the user may set the time interval and determine whether the metered value buffer should be deleted after transfer to the SIPROTEC device has taken place Figure 5 32 Dialog Box to Restore Meter...

Page 165: ... binary input is checked The time interval begins with the first activation of a signal to the binary input Number of chatter tests This number represents how many check cycles should be conducted before the binary input is finally blocked Please consider that even a high set value can be reached over the normal life span of the device and could lead to blocking of the binary input Therefore this ...

Page 166: ...open CCF ON Al so the indication Contact chatter filter reports this condition Both mes sages are shown in the operating buffer event log Chattering of a single point indication is set as ON coming if the binary input is ac tivated by energization configured High active Chattering of a single point indication is set as OFF going if the binary input is de activated by energization configured Low ac...

Page 167: ...he names of all available CFC charts will appear The desired CFC chart for processing can be selected via a double click of the mouse The CFC program will start and the chart will be displayed If no chart is available yet you can create a new chart via the menu Create CFC Chart Run Time Properties The functions to be implemented in CFC may be divided into four task levels Measured values This task...

Page 168: ... constantly be created by the cyclical processing filling the buffer unnecessarily On the other hand the interlocking condition at the moment of a switching operation may not be processed at the right time since measured value processing is done cyclically every 600 ms Table 5 4 Selection guide for function modules and task levels Function Modules Description Run Time Level MW_BEARB Meter processi...

Page 169: ...put signal CMD_INF Test X CONNECT Connection X X X D_FF D flipflop X X X DI_TO_BOOL Double point to boolean conversion X X X LIVE_ZERO Live zero non linear curve X LOWER_SETPOINT Lower limit X NAND NAND gate X X X NEG Negator X X X NOR NOR gate X X X OR OR gate X X X RS_FF RS flipflop X X X SR_FF SR flipflop X X X TIMER Timer X X LONG_TIMER Long timer max 1193 h X X UPPER_SETPOINT Upper limit X X_...

Page 170: ... inputs can be made visible by selecting the module title block pressing the right mouse button selecting the menu option Number Of I Os see Figure 5 37 and then increasing the number Figure 5 37 Example of an OR gate module menu Under the Object Properties menu you may edit the name of the module insert a comment or edit run time properties and connection parameters Connecting modules with each o...

Page 171: ...kewise the CFC chart may be reopened and edited by clicking on Chart selecting the appro priate chart and clicking on Open Please note that certain limits and restrictions exist due to the available memory and processing time required For each of the four PLC task levels there is only a finite processing time available within the processor system Each module each input to a module whether connecte...

Page 172: ...other task levels are within the permissible range Figure 5 40 Read out of the CFC configuration degree of utilization If the limits are exceeded during configuration of the CFC DIGSI 4 issues a warning refer to Figure 5 41 After acknowledgement of this alarm the system utilisation can be viewed as described above Figure 5 41 Warning message on reaching the limits Table 5 6 Processing times in TIC...

Page 173: ...he limit value function outputs are passed on to the OR gate The output of the OR gate is connected to the right border column at annunciation I alarm The limit value message is triggered when the preset limit value is below the setpoint low current in at least one of the three phases The hysteresis of the limit values is fixed and need not be entered 5 of set point plus 0 5 of nominal value Figur...

Page 174: ...43 Interlocking an disconnect switch as an example of a user defined interlock pro tective function Example 3 PLC1 Additional Logic By using slow PLC processing an additional event driven logic condition may be con structed which delivers indications regarding switch gear operating status These in dications may be passed externally via LEDs or relay contacts or used as input sig nals for further l...

Page 175: ...nfiguration 5 47 7SA6 Manual C53000 G1176 C156 2 Figure 5 44 Additional logic as an example for a PLC_1 event driven logic condition Test Oper 1 CB TRIP Test Oper Circuit Breaker Protection TRIP Operation ...

Page 176: ...or replaced to adapt to the actual substation conditions However it is also possible to display other informa tion than the station image on a default display The display for example can be used to view a variety of operational measured values Under normal conditions a preset image is shown as the default display The layout of this default display may be configured by the user In general a single ...

Page 177: ...rovided at the top of the display It can contain the user defined name of the substation or feeder The status bar at the bottom may not be configured Proceed as follows In DIGSI 4 select the default display under the Setting option The Display Ed itor is started and the default display is opened see Figure 5 46 Right click in the title bar and select Open in the context menu which appears The desi...

Page 178: ... matrix can now be selected in a Link dialog window see Figure 5 47 from which the user may click on the desired option and confirm with OK In this manner the user may link the graphical diagram with configuration settings Position text as necessary by clicking on Tools and then Insert Text and then on the text insertion location in the diagram Figure 5 47 DIGSI 4 Selection Window for Switching Eq...

Page 179: ...splay may be selected by clicking View Normal size see Figure 5 48 Save the default display and end the Display Editor session by clicking Display Close Answer the confirmation with Yes Figure 5 48 Default Display in Normal Size View In order to use the default display for further applications e g as a template in other bays or for a control diagram click on Display Template Save as Se lect the de...

Page 180: ...with the actual system conditions Figure 5 49 A preset control display Procedure The creation or alteration of the control display is carried out via the Display Editor of the DIGSI 4 operating program The standard procedure is the same as when creat ing a default display see section 5 4 The prerequisite for the alteration or creation of a control display is the allocation of the switching objects...

Page 181: ...eed to make the respective device controllable for the operator Double click on the device in the active control display see Figure 5 50 Then select Op tions devices in the active dialog window and highlight Object operator controllable In addition to this determine the device which should be controlled first after calling the control display in the SIPROTEC device For this select the option Defau...

Page 182: ...ntains a varying number of tabs depending on the capabili ties of the PC and the relay with setting options for the interfaces Figure 5 51 DIGSI 4 Settings of the PC interface example Serial port on PC In the first tab you enter the communication interface of the PC which is connected to the 7SA6 relay COM1 COM2 etc Manual entry of settings for data format and baud rate need not be made if these v...

Page 183: ...que IEC ad dress assigned to it Only the addresses which are within the current address range and have not yet been occupied are displayed The setting for the maximum message gap is only applicable when the device is to communicate using a modem via one of the interfaces A gap is the maximum allow able time duration of interrupted transmission within one telegram transmission Transfer gaps are cre...

Page 184: ... free communication Signal Idle State For optical connections the signal idle state is preset for light off Modification of the signal idle state is accomplished in the tab for the interface settings see Figure 5 53 Figure 5 53 Settings for an optical interface example Reading and Modi fying Interface Set tings at the Device Reading and partial modification of the most important interface settings...

Page 185: ... operator and service interface can be modified In addition to the settings already mentioned for the opera tor and service interfaces the signal idle state for an optical link may also be read at the device For an electrical interface the response OFF Sig Inactive appears as shown in Figure 5 55 Figure 5 55 Read out of system interface setting values in the device display example FRONT PORT 01 04...

Page 186: ...e generally it is the device with index 1 It synchronizes the other device or other devices for more than 2 ends via the protection communication Thus it can be assured that all devices of the protection system operate on the same time basis Only in case of communication failure each device is influenced by one of the mentioned time sychronization sources Time Synchronization Settings for time syn...

Page 187: ...3 External synchronization using the system interface and the IEC 60870 5 103 protocol 3 IRIG B Time signal External synchronization using IRIG B 4 DCF77 Time signal External synchronization using DCF 77 5 SIMEAS time signal Sync Box External synchronization using SIMEAS Sync Box 6 Pulse via binary input External synchronization with pulse via binary input 7 Fieldbus External synchronization via f...

Page 188: ...vices whose clock is synchronized by the absolute time master you must select one of the options with the supplement or Timing Master No 8 to 14 in Table 5 7 The device only uses the indicated source if it is not supplied with a time from the absolute time master Synchronization Offset The Synchronization Offset Time correction setting allows correlation of the time signal received from the radio ...

Page 189: ...d above or as mentioned above if the synchronization mode is changed if a time jump is anticipated The message itself is stamped with the old time The message Time interruption OFF is triggered when the synchronization is re established e g after a break in reception by the radio clock immediately after a time jump This message is stamped with the new time after the jump thus allowing determinatio...

Page 190: ...Configuration 5 62 7SA6 Manual C53000 G1176 C156 2 ...

Page 191: ...rth Fault Protection in Earthed Systems optional 6 121 6 8 Earth Fault Protection Teleprotection Schemes optional 6 139 6 9 Weak Infeed Tripping 6 156 6 10 External Direct and Remote Tripping 6 160 6 11 Overcurrent Protection 6 162 6 12 High Current Switch On To Fault Protection 6 178 6 13 Earth Fault Detection in Non Earthed Systems 6 180 6 14 Automatic Reclosure Function optional 6 188 6 15 Sync...

Page 192: ...se the key to navigate to the P SYSTEM DATA1 dis play as shown in Figure 6 2 In general an item number appears in the menu list to the right of each selection Nav igation can be accomplished using the item number in place of the and keys This feature is particularly helpful in large menus e g setting lists Based on the ex ample above from the MAIN MENU the SETTINGS display can be reached by press ...

Page 193: ... key A blinking asterisk is an indication that setting modification mode is still open Other modifications can be made to settings even in sub menus if present as long as set ting modification mode is still open The actual modification of settings occurs once setting modification mode is closed see below Exiting the Setting Mode Figure 6 3 Example of setting modification using the front control pa...

Page 194: ...ey to confirm and the user can remain in setting modification mode without down loading modifications Figure 6 4 Ending the setting mode using the front control panel From PC with DIGSI 4 To select a function double click on Settings and then double click on the desired setting function e g Power System Data 1 is selected by double clicking Set tings and then double clicking Power System Data 1 as...

Page 195: ...allowable range is shown To modify a setting click on the setting value which is displayed in the Value column Text Values When a text setting value is selected a pull down menu of possible setting options is displayed To modify the setting simply click on the desired option The pull down menu closes and the new setting value appears in the Value column Numerical Values including When a numerical ...

Page 196: ...ry value entry example Additional Settings Those settings that are modified only in special cases are typically hidden They may be made visible by checking on Display Additional Settings Confirmation Each entry may be confirmed by clicking Apply Valid values are accepted automat ically when another field is selected The final acceptance of a modified setting takes place once the setting mode is ex...

Page 197: ...ty Instrument Transformer Nominal Values In the address 203 Unom PRIMARY and 204 Unom SECONDARY the device is in formed of the primary and secondary rated voltage line voltage of the voltage trans formers In the address 205 CT PRIMARY and 206 CT SECONDARY the primary and secondary rated current phase current of the current transformers are entered Please observe that the rated current transformer ...

Page 198: ...then the parameter in address 214 ϕ Usync Uline is not required If however a transformer with a vector group unequal to zero separates the two voltage sources this setting must be used to compensate the phase shift according to the vector group of the transformer This setting can only be modified with DIGSI 4 under Additional Settings The phase angle setting is defined as follows place Usync at ze...

Page 199: ... Transformer Connection The device contains four current measurement inputs three of which are connected to the set of current transformers The fourth current measuring input I4 may be utilised in various ways Connection of the I4 input to the earth current in the starpoint of the set of current transformers on the protected feeder normal connection refer to Appendix A Fig ure A 31 Address 220 is ...

Page 200: ...tion can be used for the polarisation of the directional earth fault protection refer to Appendix A Figure A 38 or A 39 Address 220 is then set to I4 transformer IY starpoint and address 221 I4 Iph CT according to the ratio of the transformation ratios of the current transformer in the transformer neutral and the set of current transformers on the protected feeder If the I4 input is not required t...

Page 201: ...command duration TMin TRIP CMD is set This applies to all protection and control functions which may issue a trip command This also determines the length of the trip command pulse when a circuit breaker trip test is initiated via the device This setting can only be modified with DIGSI 4 under Additional Settings Under address 241A the maximum close command duration TMax CLOSE CMD is set This appli...

Page 202: ...nt of the pro tected line Neutral Current of the paral lel line Starpoint Curr of earthed power transf Neutral Current of the protected line I4 current transformer is 221 I4 Iph CT 0 010 5 000 1 000 Matching ratio I4 Iph for CT s 207 SystemStarpoint Solid Earthed Peterson Coil earthed Isolated Solid Earthed System Starpoint is 230 Rated Frequency 50 Hz 60 Hz 50 Hz Rated Frequency 235 PHASE SEQ L1 ...

Page 203: ...Functions 6 13 7SA6 Manual C53000 G1176 C156 2 242 T CBtest dead 0 00 30 00 sec 0 10 sec Dead Time for CB test autore closure Addr Setting Title Setting Options Default Setting Comments ...

Page 204: ...one application While all setting groups are stored in the relay only one setting group may be active at a given time If multiple setting groups are not required Group A is the default selection and the rest of this sub section is of no importance If multiple setting groups are desired address 103 Grp Chge OPTION must have been set to Enabled in the relay configuration Refer to Chapter 5 Each of t...

Page 205: ...ory Settings The factory settings may be restored for a modified setting group To restore factory settings to a setting group the name of the setting group whose settings are to be re stored is highlighted Next select the menu option Edit and then click on Reset A confirmation box appears click on Yes to confirm restoration of factory settings Switching between Setting Groups The procedure to swit...

Page 206: ... Function Setting Options Default Setting 302 CHANGE Change Group Group A Group B Group C Group D Binary Input Protocol Group A FNr Setting Title Default Setting 7 Set Group Bit0 Setting Group Select Bit 0 8 Set Group Bit1 Setting Group Select Bit 1 Group A Group A Group B Group B Group C Group C Group D Group D ...

Page 207: ...ion grading The line angle Address 1105 Line Angle may be derived from the line parameters The following applies where RL being the resistance and XL the reactance of the protected line The line pa rameters may either apply to the entire line length or be per unit of line length as the quotient is independent of length Furthermore it makes no difference if the quotients were calculated with primar...

Page 208: ...n 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 by entering the resistance ratio RE RL and the reactance ratio XE XL or by entry of the complex earth residual matching fac tor K0 Which of these two entry options applies was determined ...

Page 209: ...e a close approximation even when the following lines have substantially different earth impedance ratios e g cable after an overhead line Ac cordingly the settings for the address 1116 RE RL Z1 and 1117 XE XL Z1 are determined with the data of the protected line while the addresses 1118 RE RL Z1B Z5 and 1119 XE XL Z1B Z5 apply to the remaining zones Z1B and Z2 up to Z5 as seen from the relay loca...

Page 210: ... The fol lowing table indicates the quadrant and range of the angle which is determined by the signs of the calculated real and imaginary part of K0 In this example the following result is obtained The magnitude and angle of the earth impedance residual matching factors setting for the first zone Z1 and the remaining zones of the distance protection may be differ ent This allows to set the exact v...

Page 211: ...s no difference if the quotients are calculated with primary or secondary values These setting values only apply to the protected line and are entered in the addresses 1126 RM RL ParalLine and 1127 XM XL ParalLine For earth faults on the protected feeder there is in theory no additional distance pro tection or fault locator measuring error when the parallel line compensation is used The setting in...

Page 212: ...PoleOpenCurrent which will definitely not be exceeded when the circuit breaker pole is open is set If parasitic currents e g through induction can be excluded when the circuit breaker is open this setting may be very sensitive Otherwise this setting must be increased correspondingly In most cases the preset value is sufficient This setting can only be modified with DIGSI 4 under Additional Setting...

Page 213: ...must be cor rectly parameterized in the system data Section 6 1 1 address 210 U4 transform er Usync transf as well as the corresponding factors If no synchronism check is to be performed with manual closing set SYN MAN CL without Synchronism check If on the other hand synchronism check is re quired set with Synchronism check If the manual close function of the device is not to be used at all set S...

Page 214: ...i e faults occurring almost simultaneously at different locations in the net work If as shown in the example Figure 6 13 two single phase to ground faults occur on different lines in this example parallel lines the protection relays on the two faulted lines at all four line ends pick up In this example all four relays detect a L1 L2 E fault in other words a two phase to ground fault However each i...

Page 215: ... 3 Overall Fault Detection Logic of the Device The default setting is triple pole 6 1 3 1 Settings Note The indicated secondary current values and values of impedance for setting ranges and default settings refer to IN 1 A For the nominal current 5 A the current values are to be multiplied by 5 The values of impedance are divided by 5 Addresses which have an A attached to its end can only be chang...

Page 216: ...ltage 2 70 V 30 V Pole Open Voltage Threshold 1132A SI Time all Cl 0 01 30 00 sec 0 05 sec Seal in Time after ALL closures 1134 Line Closure Manual Close BI only Current OR Voltage or Manual close BI CBaux OR Current or Manual close BI Current flow or Manual close BI Manual Close BI only Recognition of Line Closures with 1135 Reset Trip CMD with Pole Open Current Threshold only with CBaux AND Pole...

Page 217: ...CB1 aux 3p Open for AR CB Test 371 CB1 Ready CB1 READY for AR CB Test 378 CB faulty CB faulty 381 1p Trip Perm Single phase trip permitted from ext AR 382 Only 1ph AR External AR programmed for 1phase only 383 Enable ARzones Enable all AR Zones Stages 385 Lockout SET Lockout SET 386 Lockout RESET Lockout RESET 530 LOCKOUT LOCKOUT is active 501 Relay PICKUP Relay PICKUP 503 Relay PICKUP L1 Relay PI...

Page 218: ...ppressed 533 IL1 Primary fault current IL1 534 IL2 Primary fault current IL2 535 IL3 Primary fault current IL3 545 PU Time Time from Pickup to drop out 546 TRIP Time Time from Pickup to TRIP 560 Trip Coupled 3p Single phase trip was coupled 3phase 561 Man Clos Detect Manual close signal detected 562 Man Close Cmd CB CLOSE command for manual closing F No Alarm Comments ...

Page 219: ...comparison as well as a displace ment voltage measurement Furthermore special measures are taken to avoid a pick up for low current earth faults in an isolated or resonant earthed system Earth Current 3 I0 For earth current measurement the fundamental sum of the numerically filtered phase currents 3 I0 is monitored to detect if it exceeds the set value parameter 3I0 Threshold address 1203 It is st...

Page 220: ...ltage 3U0 For the neutral displacement voltage recognition the displacement voltage 3U0 is numerically filtered and the fundamental frequency is monitored to recognize whether it exceeds the set threshold 3 U0 The reset threshold is approximately 95 of the pick up threshold For earthed systems the U0 criterion may be disabled by applying the setting Logical Combination for Earthed Systems The curr...

Page 221: ...sed in order to avoid an erroneous pickup as a result of the earth fault initiation transients After a time delay T3I0 1PHAS which can be set the fault detection is released again this is necessary for the distance protection to still be able to detect a double earth fault with one base point on a dead end feeder If however an earth fault is already present in the system it is detected by the dis ...

Page 222: ...to initiate all the necessary procedures for selective clearance of the fault Start the delay times for the directional and non directional final stages Determination of the faulted loops Release of impedance calculation and direction determination Release of tripping command Initiation of supplementary functions Indication output of the faulty phase s Depending on the ordered version the 7SA6 dis...

Page 223: ...he current voltage char acteristic shown in Figure 6 19 The first requirement for every phase pick up is that of the minimum current Iph is exceeded For the evaluation of phase phase loops both relevant phase currents have to exceed this value Above this current the current pick up is voltage dependent with the slope being determined by the settings U I and U I For short circuits with large curren...

Page 224: ... sensitive with high load currents the pick up threshold will be higher This applies in particular if the network star point is earthed low resist ance If only the phase earth loops are evaluated it must be ensured that the over current stage Iph responds in the event of phase phase faults If only one mea suring system picks up it can be decided whether this shall result in a pick up of the phase ...

Page 225: ...tage loops if an earth fault has been detected For phase phase faults only the overcurrent Iph will then pick up This is advantageous in networks with neutral points that have been earthed low resistance i e using earth fault current limiting means so called semi solid earth ing In these cases only earth faults shall be detected by the U I pick up In this net work it is often undesirable that phas...

Page 226: ... value Iph that can be set The angle is determined by the phase to phase voltage and its corresponding current difference A precondition for measuring the phase earth angle is that the associated phase cur rent has exceeded a settable minimum value Iph and that an earth fault according to Section 6 2 1 has been detected or only phase to earth measurements have been stipulated by setting parameters...

Page 227: ...on has a series of pick up modes from which the one matching the respective network conditions best can be selected also see order data in the Appendix If the device does not have an explicit pick up function or if you set DIS ANR Im pedance address 114 for pick up type when configuring the protection functions Section 5 1 all settings dealt with in this section are irrelevant and cannot be select...

Page 228: ...rectly detected and measured according to the preference program also see Section 6 2 3 1 Double Earth Faults in Non earthed Systems In isolated or resonant earthed networks it is possible to control the U I ϕ pick up using phase to phase voltages only address 1601 PROGAM U I Ph E Uphph Ph Ph Uphph Naturally this excludes pick up by single earth faults however it also does not allow a correct doub...

Page 229: ... impedance within a distance zone after pick up The non directional final time DELAY NON DIR address 1603 works for all short circuits if there is no impedance within a distance zone after pick up U I ϕ Pickup The meaning of the settings can be seen from Figure 6 21 Iph section a address 1611 is the minimum current as described in the previous section Iph section c is the overcurrent pick up Figur...

Page 230: ...rea If reactive power has to be tranferred via this line it must be en sured that the maximum reactive current at minimum operating voltage is not within the pick up range i e the short circuit angle range ϕK If in doubt pick up conditions should be checked in accordance with the U I ϕ characteristic An arithmetic short cir cuit calculation is recommended for extensive networks The lower threshold...

Page 231: ... Iph 0 10 4 00 A 0 20 A Iph Pickup minimum current 1612 Uph e I 20 70 V 48 V Undervoltage ph e at Iph 1613 Uph e I 20 70 V 48 V Undervoltage ph e at Iph 1614 Uph ph I 40 130 V 80 V Undervoltage ph ph at Iph 1615 Uph ph I 40 130 V 80 V Undervoltage ph ph at Iph 1616 Iphi 0 10 8 00 A 0 50 A Iphi Pickup minimum current at phi 1617 Uph e Iphi 20 70 V 48 V Undervoltage ph e at Iphi 1618 Uph ph Iphi 40 ...

Page 232: ...d for the calculation The fault evaluation is therefore always done with the measured val ues of the current fault condition Phase Phase Loops To calculate the phase phase loop for instance during a two phase fault L1 L2 Fig ure 6 22 the loop equation is where U I are the complex measured values and Z R jX is the complex line impedance The line impedance is computed to be Figure 6 22 Short circuit...

Page 233: ...arth loop The factor ZE ZL only depends on the line parameters and no longer on the fault dis tance The evaluation of the phase earth loop does not take place as long as the affected phase is switched off during single pole dead time to avoid an incorrect measure ment with the undefined measured values existing in this state A state recognition re fer to Section 6 22 provides the corresponding blo...

Page 234: ...ure Depending on the infeed conditions close in short circuits may cause unfaulted loops to see the fault further away than the faulted loop but still within the tripping zone This would cause three pole tripping and therefore void the possibility of single pole automatic reclosure As a result power transfer via the line would be lost In the 7SA6 this is avoided by the implementation of a loop ver...

Page 235: ...loops are con sidered to be close together when they have the same direction and do not differ by more than a factor 1 5 largest to smallest impedance This is to avoid in case of mul tiple faults with separate fault location the closer fault is eliminated from the evaluation by configured restrictions Furthermore the measurement phase phase can only be carried out if two earth faults are close to ...

Page 236: ...t to switch off one of the faults The second fault may remain in the system as a simple earth fault Which of the faults is switched off depends on the double earth fault preference which is set the same in the whole galvanically connected system With 7SA6 the following double earth fault preferences PHASE PREF 2phe can be selected acyclic L3 before L1 before L2 short form L3 L1 acyclic acyclic L1 ...

Page 237: ...o ZM ZL is a constant line parameter resulting from the geometry of the double circuit line and the nature of the Table 6 8 Evaluation of measured loops for a multiple pick up in non earthed systems Fault detection Loops Evaluated Loop s Setting Parameter 1221 L1 E L2 E L1 L2 L2 E L3 E L2 L3 L1 E L3 E L3 L1 L1 E L3 E L3 E PHASE PREF 2phe L3 L1 acyclic L1 E L2 E L1 L2 L2 E L3 E L2 L3 L1 E L3 E L3 L...

Page 238: ... not be carried out as this would cause se vere overreach The relay located in position II in Figure 6 27 may therefore not be compensated An 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 substantia...

Page 239: ...protection data Sub sec tion 6 1 3 as was the reach of the parallel line compensation Double Earth Faults in Earthed Systems The loop selection for double earth faults is set in address 1221A 2Ph E faults Phase Phase Earth fault detection This setting can only be modified with DIGSI 4 under Additional Settings In general the Block leading Ø blocking of the leading phase presetting is favourable be...

Page 240: ...e delay T3I0 1PHAS is not active anymore an earth fault ocurring then in a different phase can only be a double earth fault Line Energization onto a Dead Fault To determine the reaction of the distance protection during closure of the circuit break er onto a dead fault the parameter in address 1232 SOTF zone is used The setting Inactive specifies that there is no special reaction i e all distance ...

Page 241: ...3 3 Settings Note The indicated secondary current values and values of impedance for setting ranges and default settings refer to IN 1 A For the nominal current 5 A the current values are to be multiplied by 5 The values of impedance are divided by 5 Addresses which have an A attached to its end can only be changed with DIGSI 4 in Additional Settings RLoad prim Umin 3 IL max 0 9 110 kV 3 525 A 108...

Page 242: ...20 PHASE PREF 2phe L3 L1 acyclic L1 L3 acyclic L2 L1 acyclic L1 L2 acyclic L3 L2 acyclic L2 L3 acyclic L3 L1 cyclic L1 L3 cyclic all loops L3 L1 acyclic Phase preference for 2ph e faults 1221A 2Ph E faults block leading ph e loop block lagging ph e loop all loops only phase phase loops only phase earth loops block leading ph e loop Loop selection with 2Ph E faults Addr Setting Title Setting Option...

Page 243: ...p L23E 3693 Dis Pickup L123 Distance Pickup L123 3694 Dis Pickup123E Distance Pickup123E 3701 Dis Loop L1 E f Distance Loop L1E selected forward 3702 Dis Loop L2 E f Distance Loop L2E selected forward 3703 Dis Loop L3 E f Distance Loop L3E selected forward 3704 Dis Loop L1 2 f Distance Loop L12 selected forward 3705 Dis Loop L2 3 f Distance Loop L23 selected forward 3706 Dis Loop L3 1 f Distance L...

Page 244: ...oop L31 3755 Dis Pickup Z2 Distance Pickup Z2 3758 Dis Pickup Z3 Distance Pickup Z3 3759 Dis Pickup Z4 Distance Pickup Z4 3760 Dis Pickup Z5 Distance Pickup Z5 3771 Dis Time Out T1 DistanceTime Out T1 3774 Dis Time Out T2 DistanceTime Out T2 3777 Dis Time Out T3 DistanceTime Out T3 3778 Dis Time Out T4 DistanceTime Out T4 3779 Dis Time Out T5 DistanceTime Out T5 3780 Dis TimeOut T1B DistanceTime O...

Page 245: ... coordinate system the directional characteristic however limits the tripping range to the desired quadrants refer to Direction Determination below The R reach may be set separately for the phase 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 an additional tilt α exists which may be used to prevent overre...

Page 246: ...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 6 30 This is taken into account when computing the dire...

Page 247: ...pedance as well as the load transferred across the line prior to fault in ception Accordingly the directional characteristic includes a safety margin with re spect to the borders of the first quadrant in the R X diagram Figure 6 31 As each zone may be set Forward Reverse or Non Directional there is a sep arate mirrored directional characteristic for the forward and reverse direction Table 6 9 Allo...

Page 248: ...tages are equal to the corresponding generator e m f 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 In the case of a fault located at F1 Figure 6 32a the short circuit is located in the forward direction and the source impedance in the reverse direction For all fault locations right up to the devic...

Page 249: ...heme The pick up range of the Dis tance Protection is determined from the thresholds of the largest set polygon taking into consideration the respective direction Here the loop information is also converted into faulted phase indication Pick up signals are also generated for each zone and converted into phase informa tion e g Dis Pickup L1 Z1 for zone Z1 and phase L1 This means that each phase and...

Page 250: ...terconnected system This diagram should reflect the line lengths with their pri mary reactance X in Ω phase For the reach of the distance zones the reactances X 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 0 00 s The protection clears faults in this range without additional time delay i e the tripping time is the ...

Page 251: ...L 0 85 14 70 Ω 12 49 Ω or secondary Resistance Margin The resistance setting R allows a margin 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 tower footing resistance and others The setting must allow for these fault resistance but should at the same time...

Page 252: ...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 If the in feed comes from the remote end the measured resistance may be increased Independent Zones Z1 up to Z5 By means of the setting parameter MODE each zone can be set Forward or Reverse or Non Directional Address 1301 Op mode Z1 1311 Op ...

Page 253: ...vice is provided with the capability to trip single pole single pole tripping is then possible in the zones Z1 and Z2 While single pole tripping then usually applies to single phase faults in Z1 if the other conditions for single pole tripping are satisfied this may also be selected for the second zone with address 1317A Trip 1pole Z2 Single pole tripping in zone 2 is only possible if this address...

Page 254: ... to 1st AR Z1B equals No In this case the overreaching zone Z1B is not released before and during the 1st automatic reclose cycle Zone Z1 is always released The setting only has an effect when the service condition of the automatic reclose function is input to the device via binary input Enable ARzones FNo 383 power system data 2 6 2 4 3 Settings Note The indicated secondary values of impedance fo...

Page 255: ...ec T2 1phase delay for single phase faults 1316 T2 multi phase 0 00 30 00 sec 0 30 sec T2multi ph delay for multi phase faults 1317A Trip 1pole Z2 NO YES NO Single pole trip for faults in Z2 1321 Op mode Z3 Forward Reverse Non Directional Inactive Reverse Operating mode Z3 1322 R Z3 Ø Ø 0 050 250 000 Ohm 5 000 Ohm R Z3 Resistance for ph ph faults 1323 X Z3 0 050 250 000 Ohm 10 000 Ohm X Z3 Reactan...

Page 256: ...Ohm R Z5 Resistance for ph ph faults 1343 X Z5 0 050 250 000 Ohm 12 000 Ohm X Z5 Reactance for Forward direction 1344 RE Z5 Ø E 0 050 250 000 Ohm 12 000 Ohm RE Z5 Resistance for ph e faults 1345 T5 DELAY 0 00 30 00 sec 0 90 sec T5 delay 1346 X Z5 0 050 250 000 Ohm 4 000 Ohm X Z5 Reactance for Reverse direction Addr Setting Title Setting Options Default Setting Comments ...

Page 257: ... logic is shown in Figure 6 34 using for zone 1 Figure 6 35 for zone 2 and Figure 6 36 for the third zone Zones Z4 and Z5 function according to Figure 6 37 In the case of zones Z1 Z2 and Z1B single pole tripping is possible for single phase faults if the device version includes the single pole tripping option Therefore the event output in these cases is provided for each pole Different trip delay ...

Page 258: ...ip Z1 1p 3771 Dis T1 exp 3801 Dis G trip 3824 Dis trip Z1 3pm 3802 Dis trip 1polL1 Dis FDZ2 L3 Dis FD Z2 L2 Dis FD Z2 L1 1 1 1315 T2 1phase T 0 T 0 1316 T2 multi phase 1 L1 L2 L3 L1 L2 L3 L3 L2 L1 L3 L2 L1 Tripping logic of the distance protection 1 L1 L2 L3 1 L1 L2 L3 Z2 undelayed see figure 6 28 3817 Dis trip Z2 3p 3803 Dis trip 1polL2 3804 Dis trip 1polL3 3805 Dis trip L123 3816 Dis trip Z2 1p ...

Page 259: ...to use the zone Z1B as a rapid auto reclosure stage that only operates for single pole faults if for example only sin gle pole automatic reclose cycles are executed It is possible for the 7SA6 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 integrated teleprotection function refer to Se...

Page 260: ... The actual generation of the commands for the trip relay takes place in the tripping logic of the device refer to Sub section 6 22 4 No Yes 1st AR Z1B 1 1 1 further not available 121 Teleprot Dist Dis Sig active Dis relZ1B T1B L3 Dis relZ1B T1B L2 Dis relZ1B T1B L1 L1 L2 L3 1pole tripping for 2pole faults L2 L1 L3 L1 L1 L2 L3 L2 L3 L3 L2 L1 L1 L2 L3 1 Dis FD Z1B L3 Dis FD Z1B L2 Dis FD Z1B L1 1 1...

Page 261: ...istance protection were already considered with the zone settings Sub sections 6 2 4 2 The parameter in address 1232 SOTF zone which determines the response during switching onto a short circuit was already set as part of the general data of the dis tance protection Sub section 6 2 3 2 Further setting options which affect the tripping are described as part of the tripping logic of the device refer...

Page 262: ...ons in the system out of step trip ping devices are also applied to split the system into islanded networks at selected lo cations when system stability synchronism is lost due to severe unstable power swings The 7SA6 has an integrated power swing supplement which allows both the blocking of trips by the distance protection during power swings power swing blocking and the calculated tripping durin...

Page 263: ...y enters the power swing range PPOL and only later enters the fault detection 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 vec tor enters the power swing polygon and passes through it leaving on the opposite side then the sections of the network seen fro...

Page 264: ...o 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 the power swing function to pick up Trajectory Stability When the impedance vector enters the impedance characteristic during a power swing this is on a point of the elliptical curve that corresponds to steady state instability For release o...

Page 265: ...r swing detected signal is generated the measured impedance must be inside the power swing polygon PPOL A further 4 measuring criteria must be fulfilled G Trajectory continuity The measured R and X values must describe a steady path without a jump from one measured value to the next Refer to Figure 6 41 G Trajectory monotony The impedance trajectory must initially not change R direction Refer to F...

Page 266: ...ted grading time Blocking of only the higher zones Z2 to Z5 block The higher zones Z2 to Z5 are blocked during a power swing Only the first and the overreaching zone Z1 and Z1B remain active Blocking of the first two zones Z1 Z1B Z2 block The first and second zone Z1 and Z2 and the overreaching zone Z1B are blocked during a power swing The higher zones Z3 to Z5 remain active The associated measure...

Page 267: ...006 which should be set to Yes if required presetting is No In the event of power swing tripping it is sensible to set P S Op mode All zones block for the power swing blocking to avoid premature tripping by the distance protection 6 3 3 Settings 6 3 4 Information Overview Addr Setting Title Setting Options Default Setting Comments 2002 P S Op mode all zones blocked Z1 Z1B blocked Z2 to Z5 blocked ...

Page 268: ...he scope of functions Figure 6 44 Distance protection for two ends with two 7SA6 devices each of them having one protection data interface transmitter receiver Using three ends at least one 7SA6 device with two protection data interfaces is re quired Thus a communication chain can be formed The number of devices address 147 NUMBER OF RELAY must correspond to the number of ends of the protected obj...

Page 269: ...nd on the quality of transmission and that they are prolonged in case of a reduced transmission quality and or an increased operating time Figure 6 46 shows some examples for communication connections In case of a direct connection the distance depends on the type of the optical fibre Table 6 10 lists the options available Different types of modules can be installed in the device For ordering info...

Page 270: ...transmission operates properly again the devices will automatically switch back to the teleprotection scheme Operating time jumps that for example can occur in case of switchings in the communication network can be recognized and corrected by the device After at least 2 seconds the operating times are measured again 7SA6 7SA6 typical 1 5 km with 62 5 125 µm Multimode fibre FO5 with ST connector at...

Page 271: ...ay vary The data must be identical at both ends of a communication route The setting depends on the features of the communication media As a general rule it can be said that the higher the transmission rate the shorter the response time of the teleprotection scheme The devices measure and monitor the transmission times Deviations are corrected as long as they are within the permissible range These...

Page 272: ...a interface corresponds to the projected communication link Figure 6 47 Distance Protection topology for 2 ends with 2 devices example 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 6 47 compare also with Figure 6 44 and 6 45 The indices of the devices and the...

Page 273: ...otection system are conclusive Each device index can only be used once Each device index must be allocated unambiguously to a device ID Each device index must be the index of a local device once The device with index 1 is the source for the absolute time management absolute time master During startup of the protection system the above listed conditions are checked If one out of these conditions is...

Page 274: ...n interface 1 4502 CONNEC 1 OVER Direct connection with fibre optic cabel Communication converter with 64 kBit s Communication converter with 128 kBit s Communication converter with 512 kBit s Direct connection with fibre optic cabel Connection 1 over 4505A PROT 1 T DELAY 0 1 30 0 ms 30 0 ms Prot 1 Maximal permissible delay time Addr Setting Title Setting Options Default Setting Comments 4701 ID O...

Page 275: ...ual Device tables are unequal 3235 Par different Differences between common parameters 3236 PI1 PI2 error Different PI for transmit and reveive 3239 PI1 TT alarm Prot Int 1 Transmission time to high 3243 PI1 with Prot Int 1 Connected with relay ID F No Alarm Comments F No Alarm Comments 3457 Ringtopology System operates in a closed Ringtopology 3458 Chaintopology System operates in a open Chaintop...

Page 276: ...ur high priority signals arrive at the device via the binary inputs Remote Trip1 to Remote Trip4 transmitted to the devices at the other ends and can be re transmitted or processed at the receiving side with the output functions RemoteTrip1 rec to RemoteTrip4 rec If the remote signals are to be used for direct remote tripping they must be allocated at the send side via CFC with the function that i...

Page 277: ...input 3567 Rem Signal19 Remote Signal 19 input 3568 Rem Signal20 Remote Signal 20 input 3569 Rem Signal21 Remote Signal 21 input 3570 Rem Signal22 Remote Signal 22 input 3571 Rem Signal23 Remote Signal 23 input 3572 Rem Signal24 Remote Signal 24 input 3573 Rem Sig 1recv Remote signal 1 received 3574 Rem Sig 2recv Remote signal 2 received 3575 Rem Sig 3recv Remote signal 3 received 3576 Rem Sig 4re...

Page 278: ...emote signal 17 received 3590 Rem Sig18recv Remote signal 18 received 3591 Rem Sig19recv Remote signal 19 received 3592 Rem Sig20recv Remote signal 20 received 3593 Rem Sig21recv Remote signal 21 received 3594 Rem Sig22recv Remote signal 22 received 3595 Rem Sig23recv Remote signal 23 received 3596 Rem Sig24recv Remote signal 24 received F No Alarm Comments ...

Page 279: ... Protection is set with normal zone grading characteristic An additional fast overreaching zone Z1B is available for teleprotection schemes Signal transmis sion and trip release methods depend on the teleprotection scheme At least one re verse looking distance zone may be required for some teleprotection schemes It is recommended to use zone Z3 for this purpose The 7SA6 permits PUTT Pickup Permiss...

Page 280: ...phase faults occur on different lines in the system Where the digital protection data interface is used the signal transmission is always phase segregated The signal transmission schemes are also suited to three terminal lines teed feeders In this case signal transmission channels are required from each of the three ends to the each of the others in both directions Phase segregated transmission is...

Page 281: ...s at the two line ends The distance protection is set in such a way that the first zone reaches up to approximately 85 of the line length In three end lines Z1 is also set to approx 85 of the shorter line section at least however up to the T point The overreach zone Z1B is not relevant for this signal transmission scheme but it can be controlled by the automatic reclosure see also Subsection 6 14 ...

Page 282: ...t has one or two opposite ends If at one line end there is weak or zero infeed so that the distance protection does not pick up the circuit breaker can still be tripped This weak infeed tripping is referred to in Section 6 9 Figure 6 51 Logic diagram of the permissive underreach transfer trip PUTT scheme with pick up one line end 4007 Dis T Rec Ch1 L1 4006 DisTel Rec Ch1 Dis Z1 L1 Dis Z1 L2 Dis Z1...

Page 283: ...tection 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 In the case of three terminal lines Z1 is also set to approximately 85 of the shortest line section but at least beyond the tee off point Z1B must securely reach beyond the longer line section eve...

Page 284: ... PU Z1 L2 Dis PU Z1 L3 Dis PU Z1 Dis forward 2103 Send Prolong T 0 T 0 T 0 T 0 Dis T RecCh1L1 Dis T RecCh1L3 Dis T RecCh1L2 1 1 1 Dis Rel Z1B L2 Dis Rel Z1B L3 Weak Infeed Tripping Dis Rel Z1B L1 DisTel Rec Ch1 Dis T Rec Ch2 Three Terminals Two Terminals Three Term Two Term 1 2102 Type of Line 1 Dis T SEND L1 Dis T SEND L2 Dis T SEND L3 Dis T SEND FNo 4003 FNo 4006 FNo 4010 FNo 4007 FNo 4008 FNo 4...

Page 285: ...rolonged by TS settable under address 2103A Send Pro long to compensate for possible differences in the pick up time at the two line ends The distance protection is set such that the first zone reaches up to approxi mately 80 of the line length On three terminal lines Z1 is also set to approximately 80 of the shorter line section but at least beyond the tee off point The overreaching zone Z1B is n...

Page 286: ...is recognized inside Z1B in the forward direc tion 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 terminal lines Z1B must be set to reliably reach beyond the longer line section even with intermediate infeed via the tee point The first zone is set in accordance with the normal time g...

Page 287: ...ipped with one or two protection data interfaces signal transmission is always phase segregated In the case of faults in the transmission path the overreaching zone Z1B can be acti vated by an automatic reclose device via the binary input Enable ARzones and address 1357 1st AR Z1B set to Yes refer to Figure 6 38 bottom The influence of signals resulting from transients during clearance of external...

Page 288: ...lep OFF Dis T SEND L1 Dis T SEND L2 Dis T SEND L3 Dis T SEND FNo 4003 FNo 4006 FNo 4010 FNo 4007 FNo 4008 FNo 4009 FNo 4052 FNo 4057 FNo 4058 FNo 4059 FNo 4056 Dis T Carr Fail FNo 4005 Dis RecFail FNo 4055 Dis T Rec L1Dev2 Dis T Rec L2Dev2 Dis T Rec L3Dev2 FNo 4088 FNo 4089 FNo 4090 Dis T Rec L1Dev3 Dis T Rec L2Dev3 Dis T Rec L3Dev3 FNo 4091 FNo 4092 FNo 4093 Protection Data Topol complete FNo 346...

Page 289: ...signal is only active when the protection has al ready issued a trip command This ensures the release from the opposite line end even when the fault was cleared locally very fast by the independent zone Z1 Sequence Figure 6 58 shows the logic diagram of the signal comparison scheme for one line end On lines with two ends the signal transmission may be phase segregated Send and receive circuits in ...

Page 290: ...case the device contains a special function This Weak Infeed Function echo function is referred to in Sub section 6 6 1 11 It is activated when a signal is received from 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 that has only weak or no infe...

Page 291: ...1L2 1 1 1 Z4 instantaneous trip L3 DisTel Rec Ch1 DisTel Rec Ch2 Three terminals Two terminals Three terminals 1 2102 Line Config 1 TRIP Command T 0 T 0 T 0 1 1 1 1 1 1 Dis Telep OFF Dis T SEND L1 Dis T SEND L2 Dis T SEND L3 Dis T SEND Transient Blocking Section 6 6 1 10 Echo function Section 6 6 1 11 FNr 4003 FNr 4006 FNr 4010 FNr 4007 FNr 4008 FNr 4009 FNr 4052 FNr 4057 FNr 4058 FNr 4059 FNr 405...

Page 292: ...tion the monitoring frequency f0 is transmitted If the unblock frequency fU is faultlessly received from the opposite end a release sig nal is routed to the trip logic Accordingly it is a prerequisite for fast tripping that the fault is recognized inside Z1B in the forward direction at both line ends The distance protection is set such that the overreaching zone Z1B reaches beyond the opposite sta...

Page 293: ...on of the signal neither the un block signal e g Dis T UB ub 1 nor the block signal Dis T UB bl 1 is re ceived at the receiving end In this case the release Unblock 1 is issued after a security delay time of 20 ms and passed onto the receive logic This release is how ever removed after a further 100 ms via the timer stage 100 100 ms When the trans mission is functional again one of the two receive...

Page 294: ...s Two terminals 1 1 Trip command T 0 T 0 T 0 1 1 1 1 1 1 Dis PICKUP Unblock 1 Unblock 2 Unblock L1 Unblock L2 Unblock L3 T 0 2108 TV from unblock logic Figure 6 61 from unblock logic Figure 6 61 Dis Telep OFF Dis T SEND L1 Dis T SEND L2 Dis T SEND L3 Dis T SEND Transient blocking section 6 6 1 10 Echo function Section 6 6 1 11 Two terminals Three terminals FNr 4052 FNr 4057 FNr 4058 FNr 4059 FNr 4...

Page 295: ...0 to receive circuit Figure 6 60 Dis T UB 1 L2 0 20 ms 100 100 ms 1 Unblock L2 0 10 s Dis T UB ub 1 0 20 ms 100 100 ms 1 Unblock 1 0 10 s Dis T UB Fail1 Dis T UB 1 L3 0 20 ms 100 100 ms 1 Unblock L3 0 10 s 1 Dis T UB bl 2 Dis T UB ub 2 0 20 ms 100 100 ms 1 Unblock 2 0 10 s Dis T UB Fail1 1 FNr 4032 FNr 4033 FNr 4034 FNr 4030 FNr 4031 FNr 4035 FNr 4032 FNr 4080 FNr 4081 ...

Page 296: ...the signal must be transmitted via the protected line with power line carrier PLC and the attenuation of the transmitted signal could be so severe at the fault location that reception at the other line end cannot necessarily be guaranteed Figure 6 62 shows the operation scheme Faults inside the overreaching zone Z1B which is set to approximately 120 of the line length will initiate tripping if a b...

Page 297: ... margin heading Controlled Zone Z1B On lines with two ends 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 send signal is transmitted to both opposite ends The receive signal are then com bined with the logical OR function as in the case of an internal fault no blocking signal must be received from any l...

Page 298: ...2 Three terminals Two terminals Three terminals 1 1 1 1 DisEnableZ1B T1B L2 DisEnableZ1B T1B L3 DisEnableZ1B T1B L1 2109 TrBlk Wait Time T T 2110 TrBlk BlockTime Transient Block Transient Block Dis Telep off Dis T SEND L1 Dis T SEND L2 Dis T SEND L3 Dis T SEND Dis T BL Stop L3 Dis T Trans Blk Two terminals Three terminals Two terminals Three terminals Two terminals Three terminals 1 FNr 4003 FNr 4...

Page 299: ...ircuits can also be tripped rapidly without any special measures as the non feeding end cannot gen erate a blocking signal 6 6 1 8 Pilot Wire Comparison The following scheme is suited for conventional transmission media 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 pilo...

Page 300: ...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 wire failure is recognized inter nally The other stages of the Distance Protection continue operating according t...

Page 301: ...1B must be set longer than the pickup time Ta of the protection devices of the outgoing lines is blocked after the pickup of an inferior protection The pickup signal is sent according to Figure 6 65 via the re ceive input 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 protec...

Page 302: ...blocking schemes 6 6 1 11 Measures for Weak and Zero Infeed In cases where there is weak or no infeed present at one line end the distance pro tection will not pick up Neither a trip nor a send signal can therefore be generated there The permissive overreach schemes with release signals would not even be able to trip at the strong infeed end without time delay unless special measures are em ployed...

Page 303: ...lt de tection the RS flip flop in Figure 6 67 latches the fault detection condition until the sig nal receive condition resets thereby barring the release of an echo The echo can in any event be blocked via the binary input Dis T BlkEcho If the conditions for an echo signal are met a short delay Trip Echo DELAY is ini tially activated This delay is necessary to avoid transmission of the echo if th...

Page 304: ...ssive underreach transfer trip with pickup as re ferred to in Subsubsection 6 6 1 1 PUTT Permissive underreach transfer trip with zone accelera tion Z1B as referred to in Subsubsection 6 6 1 2 POTT Permissive overreach transfer trip as referred to in Sub subsection 6 6 1 4 Directional Comparison Pickup Directional comparison pickup as referred to in Subsubsection 6 6 1 5 Unblocking Unblocking with...

Page 305: ...eprotection modes over protection interface are only active if the parameter 121 Teleprot Dist has been set to POTT over Protection Interface in all devices of the setup DistanceProtection Prerequisites For all applications of teleprotection schemes except PUTT it must be ensured that the fault detection of the distance protection in the reverse direction has a greater reach than the overreaching ...

Page 306: ...me between the pickup of the Distance Protection function and the trip signal of zone Z1B Transient Blocking The parameters TrBlk Wait Time and TrBlk BlockTime serve the transient blocking with the permissive overreaching schemes PUTT and UNBLOCKING With permissive underreach transfer trip they are of no consequence This setting can only be modified with DIGSI 4 under Additional Settings The time ...

Page 307: ...mpulse duration Trip EXTENSION address 2503A can be set to adapt to the circumstances of the signal transmission equipment It must be long enough to ensure that the receive signal is recognized even with different pick up times by the protection devices at the line ends and different response times of the transmission equipment Generally a setting of approximately 50 ms presetting is sufficient Th...

Page 308: ...on for Distance prot is 2102 Type of Line Two Terminals Three Terminals Two Terminals Type of Line 2103A Send Prolong 0 00 30 00 sec 0 05 sec Time for send signal prolonga tion 2107A Delay for alarm 0 00 30 00 sec 10 00 sec Time Delay for Alarm 2108 Release Delay 0 000 30 000 sec 0 000 sec Time Delay for release after pik kup 2109A TrBlk Wait Time 0 00 30 00 sec 0 04 sec Transient Block Duration e...

Page 309: ...hannel 2 4036 Dis T UB bl 2 Dis Tele Unblocking BLOCK Channel 2 4040 Dis T BlkEcho Dis Tele BLOCK Echo Signal 4050 Dis T on off BI Dis Teleprotection ON OFF via BI 4052 Dis Telep OFF Dis Teleprotection is switched OFF 4054 Dis T Carr rec Dis Telep Carrier signal received 4055 Dis T Carr Fail Dis Telep Carrier CHANNEL FAILURE 4056 Dis T SEND Dis Telep Carrier SEND signal 4057 Dis T SEND L1 Dis Tele...

Page 310: ...rrier RECEPTION L1 Device2 4089 Dis T RecL2Dev2 Dis Tele Carrier RECEPTION L2 Device2 4090 Dis T RecL3Dev2 Dis Tele Carrier RECEPTION L3 Device2 4091 Dis T RecL1Dev3 Dis Tele Carrier RECEPTION L1 Device3 4092 Dis T RecL2Dev3 Dis Tele Carrier RECEPTION L2 Device3 4093 Dis T RecL3Dev3 Dis Tele Carrier RECEPTION L3 Device3 F No Alarm Comments ...

Page 311: ...otected feeder onto a short circuit any stage or several stages may be switched to undelayed tripping If a stage is not required it can be deactivated 6 7 1 Method of Operation Measured Value The earth current is the negative sum of the three phase currents i o w IE 3 I0 IL1 IL2 IL3 Depending on the version ordered and the configured application for the fourth current input I4 of the device the ea...

Page 312: ...rmines whether during energization of the feeder onto a fault tripping with this stage shall be non delayed Yes or not No and 3I0 InrushBlk which is used to switch the inrush stabilization rush blocking on Yes or off No Figure 6 69 Logic diagram of the 3I0 stage Definite Time High Set Current Stage 3I0 The logic of the high set current stage 3I0 is the same as that of the 3I0 stage 3I0 is therefor...

Page 313: ...ram The different setting addresses are referred to in more detail in the setting information Sub section 6 7 2 It is also possible to implement this stage as a further definite time stage In this case 3I0p PICKUP is the pick up threshold and Add T DELAY the definite time delay The inverse time characteristic is then effectively bypassed Figure 6 70 Logic diagram of the 3I0P stage inverse time ove...

Page 314: ... time direction by a deter mined constant time T forw U0inv The different characteristics and their un derlying formulae are shown in the Technical Data Section 10 5 Figure 10 5 Figure 6 72 illustrates the functional principle 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 in...

Page 315: ... a binary input Figure 6 72 Directional zero voltage time protection with non directional back up stage Phase Current Stabilization Non symmetrical load conditions in multiple earthed systems or different current transformer errors can result in a zero sequence current This zero sequence current could cause faulty pick up of the earth current stages if low pick up thresholds are set To avoid this ...

Page 316: ...rent are used for the frequency analysis As soon as the harmonic content is greater than the set val ue the affected stage is blocked Direction Determination with Zero Sequence System TThe direction determination is carried out with the measured current IE 3 I0 which is compared to a polarization voltage UP which results from the measured voltage UE 3 U0 The direction determination UP may also be ...

Page 317: ...e signals must also have a minimum magnitude of 3I2 or 3U2 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 operate This gives the selective fault clearance by the distance protection preference over trip ping by the earth fault protection The earth fault protection can a...

Page 318: ...ed the setting No is applied The earth fault protection should be blocked during single pole automatic reclose dead time to avoid pick up with the false zero sequence values arising during this state address 3103 BLOCK 1pDeadTim A setting of Yes is therefore only required if single pole tripping is possible Otherwise the setting No presetting remains Definite Time Stages First of all the mode for ...

Page 319: ...ration Section 5 1 ad dress 131 that was selected If an inverse overcurrent stage is not required the ad dress 131 is set to Earth Fault O C Definite Time The 3I0P stage can then be used as a fourth definite time stage refer to Definite Time Stages above or deactivated In the case of the IEC curves address 131 Earth Fault O C TOC IEC the following alternatives are available in the address 3151 IEC...

Page 320: ...e setting Add T DELAY address 3147 is added to the time of the set curve Inverse Time Overcurrent Stage with Logarithmic Inverse Characteristic For the inverse time overcurrent stage with logarithmic inverse characteristic the op erating mode is initially set Op mode 3I0p address 3140 This stage can be set to operate Forward usually towards line or Reverse direction usually towards bus bar or Non ...

Page 321: ...Please take into consideration that the formulae is based on the zero sequence voltage U0 not on 3U0 The function is illustrated in the Technical Data Sec tion 10 5 Figure 10 5 Figure 6 76 shows the most important parameters U0inv minimum displaces the voltage controlled characteristic in direction of 3U0 The set value is the asymptote for this characteristic t In Figure 6 76 a shows an asymptote ...

Page 322: ...sually determined with the earth current IE 3I0 as the measured value the angle of which is compared to a polarizing quantity Sub section 6 7 1 The desired polarizing signal s is set in POLARIZATION address 3160 The presetting with Uo and IY generally also applies when only UE 3U0 is used as a polarizing signal If there is no transformer star point current IY connected to the device auto matically...

Page 323: ...in the system does not lead to a pick up Teleprotection with Earth Fault Protection The earth fault protection in the 7SA6 may be expanded to a directional comparison protection using the integrated teleprotection logic Additional information regarding the available teleprotection schemes and their mode of operation may be obtained from Section 6 8 If this is to be used certain preconditions must ...

Page 324: ...k up of the stages in the case of unsymmetrical load conditions or different current transformer measuring errors in earth systems the earth current stag es are stabilized by the phase currents the pick up thresholds are increased as the phase currents increase refer also to Figure 6 73 By means of the setting in address 3104A Iph STAB Slope the preset value of 10 for all stages can be jointly cha...

Page 325: ...or Teleprot schemes 3105 3IoMin Teleprot 0 003 1 000 A 0 500 A 3Io Min threshold for Teleprot schemes 3170 2nd InrushRest 10 45 15 2nd harmonic ratio for inrush restraint 3171 Imax InrushRest 0 50 25 00 A 7 50 A Max Current overriding inrush restraint 3172 SOTF Op Mode with Pickup non directional with Pickup and direction with Pickup and direction Instantaneous mode after Swit chOnToFault 3173 SOT...

Page 326: ... Directional Inactive Inactive Operating mode 3141 3I0p PICKUP 0 05 25 00 A 1 00 A 3I0p Pickup 3141 3I0p PICKUP 0 003 25 000 A 1 000 A 3I0p Pickup 3147 Add T DELAY 0 00 30 00 sec 1 20 sec Additional Time Delay 3148 3I0p Telep BI NO YES NO Instantaneous trip via Teleprot BI 3149 3I0p SOTF Trip NO YES NO Instantaneous trip after Swit chOnToFault 3150 3I0p InrushBlk NO YES NO Inrush Blocking 3142 3I0...

Page 327: ...d Time delay U0inv 3185 T rev U0inv 0 00 32 00 sec 1 20 sec T reverse Time delay U0inv 3160 POLARIZATION with U0 and IY dual polari zed with IY transformer star point current with U2 and I2 negative sequence with U0 and IY dual polarized Polarization 3162A Dir ALPHA 0 360 338 ALPHA lower angle for forward direction 3163A Dir BETA 0 360 122 BETA upper angle for forward direction 3164 3U0 0 5 10 0 V...

Page 328: ...d OFF 1332 E F BLOCK Earth fault protection is BLOCKED 1333 E F ACTIVE Earth fault protection is ACTIVE 1345 EF Pickup Earth fault protection PICKED UP 1354 EF 3I0 Pickup E F 3I0 PICKED UP 1355 EF 3I0 Pickup E F 3I0 PICKED UP 1356 EF 3I0 Pickup E F 3I0 PICKED UP 1357 EF 3I0p Pickup E F 3I0p PICKED UP 1358 EF forward E F picked up FORWARD 1359 EF reverse E F picked up REVERSE 1361 EF Trip E F Gener...

Page 329: ...igh frequency channels via pilot cables power line carrier or microwave radio links can be used for this purpose If the same transmission channel as for the transmission by the distance protection section 6 6 is used the teleprotection scheme must also be the same If the device is equipped with an optional protection data interface digital communication lines can be used for signal processing thes...

Page 330: ...mission media Principle The directional comparison scheme is a permissive scheme In Figure 6 78 the oper ation scheme is shown 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 remote end the trip signal is passed on to the tripping relay Accord ingly it is a ...

Page 331: ...s 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 refer to Sub section 6 8 1 4 On feeders with only a single sided infeed or where the system starpoint is only earthed behind one line end the line end without zero sequenc...

Page 332: ...een set to Direction Comparison over Protection Interface in all devices of the setup In the event of an error the indication Par different is output Two terminals EF Telep off EF TeleprotBLK EF Pickup EF forward 3203 Send Prolong T 0 EF Enable Trip EF Rec Ch1 EF Rec Ch2 Three terminals Two terminals Three terminals 1 3202 Line Config 1 Trip command Transient blocking 1 1 EF Tele SEND EF TeleprotO...

Page 333: ... EF Tele SEND FNo 1313 FNo 1318 FNo 1319 FNo 1381 FNo 1384 Topol complete FNo 3464 0132 1 1 Dir Comp over PI Directional Comp PU Teleprot E F 0 Dir Comp over PI Directional Comp PU 0132 Teleprot E F 1 TRIP Command EF TeleTransBlk FNo 1386 1 1 from PI EF Rec L1 Dev2 EF Rec L2 Dev2 EF Rec L3 Dev2 FNo 1394 FNo 1395 FNo 1396 Echo Rec Dev2 EF Rec L1 Dev3 EF Rec L2 Dev3 FNo 4248 FNo 1397 FNo 1398 Echo R...

Page 334: ...cent state or during an earth fault in the reverse direction the monitoring frequency f0 is transmit ted If the unblock frequency fU is faultlessly received from the opposite end a release sig nal is routed to the trip logic A pre condition for fast fault clearance is therefore that the earth fault is recognized in the forward direction at both line ends The send signal can be prolonged by TS para...

Page 335: ...ther 100 ms If the interference signal disappears again the quiescent state is reached again after a further 100 ms reset delay of the timer 100 100 ms On three terminal lines the unblock logic can be controlled via both receive channels The occurrence of erroneous signals resulting from transients during clearance of ex ternal faults or from direction reversal resulting during the clearance of fa...

Page 336: ...uted in parallel with 1384 EF Tele SEND only a short delay to allow for signal transmission is required before the directional E F trips Trip ping is possible with this scheme even if no signal is received from the opposite line end It is therefore mainly used for long lines when the signal must be transmitted across the protected feeder by means of power line carrier PLC and the attenuation of th...

Page 337: ...ts 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 It prolongs the blocking signal by the transient blocking time TrBlk BlockTime address 3210 if it has been present for the minimum duration equal to the waiting time TrBlk Wait Time address 3209 It lies in the nature of the blocking...

Page 338: ...ctional unblocking scheme If a fault in the reverse direction is detected within the waiting time TrBlk Wait Time address 3209A following fault detection the transmit circuit and the trip release are inhibited This blocking is maintained for the duration of the transient blocking time TrBlk BlockTime address 3210A also after the reset of the blocking criterion In the case of the blocking scheme th...

Page 339: ...ction can also be activated ECHO and TRIP refer also to Section 6 9 This set ting is common to the teleprotection function for the distance protection and for the earth fault protection The received signal at the line end that has no earth current is returned to the other line end as an echo by the echo function The received echo signal at the other line end enables the release of the trip command...

Page 340: ... the duration of which can be set with the parameter Trip EXTENSION After transmission of the echo impulse the transmission of a new echo is prevented for at least 20 ms This prevents from repetition of an echo after the line has been switched off The echo function is not required for the blocking scheme and is therefore ineffective Figure 6 86 Logic diagram of the echo function for the earth faul...

Page 341: ...g is not relevant in that case The earth fault directional comparison pickup scheme is only effective if the parameter 132 Teleprot E F has been set to Directional Comparison over Protection Interface in all devices of the setup Earth Fault Protection Prerequisites In the application of the comparison schemes absolute care must be taken that both line ends recognize an external earth fault earth f...

Page 342: ... The send signal prolongation Send Prolong address 3203 must ensure that the transmitted signal reliably reaches the opposite line end even if tripping is very fast at the sending line end and or the signal transmission time channel delay is relatively long In the case of the permissive schemes Dir Comp Pickup and UNBLOCKING this signal prolongation only comes into effect if the device has already...

Page 343: ...o function may be activated under address 2501 FCT Weak In feed ECHO only or deactivated OFF With this switch it is also possible to acti vate the weak infeed tripping ECHO and TRIP refer also to Section 6 9 The comments above regarding the setting of the current stage 3IoMin Teleprot address 3105 must be noted as well as the margin heading Earth Fault Protection Prerequisites The echo delay time ...

Page 344: ...C 3202 Line Config Two Terminals Three Terminals Two Terminals Line Configuration 3203A Send Prolong 0 00 30 00 sec 0 05 sec Time for send signal prolonga tion 3207A Delay for alarm 0 00 30 00 sec 10 00 sec Unblocking Time Delay for Alarm 3208 Release Delay 0 000 30 000 sec 0 000 sec Time Delay for release after pik kup 3209A TrBlk Wait Time 0 00 30 00 sec 0 04 sec Transient Block Duration exter n...

Page 345: ... 1384 EF Tele SEND E F Telep Carrier SEND signal 1386 EF TeleTransBlk E F Telep Transient Blocking 1387 EF TeleUB Fail1 E F Telep Unblocking FAILURE Channel 1 1388 EF TeleUB Fail2 E F Telep Unblocking FAILURE Channel 2 1389 EF Tele BL STOP E F Telep Blocking carrier STOP signal 1390 EF Tele BL Jump E F Tele Blocking Send signal with jump 1391 EF Rec L1 Dev1 EF Tele Carrier RECEPTION L1 Device1 139...

Page 346: ...nd In Figure 6 89 the logic diagram of the weak infeed tripping is shown It may be acti vated in address 2501 FCT Weak Infeed Weak Infeed MODE ECHO and TRIP or deactivated OFF 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 Sub section 6 6 1 11 and 6 8 1 5 The tripping function can be blocked at...

Page 347: ...P L1 CB closed L1 1 W I Pickup L1 BLOCK Weak Inf UL2 UL2 2505 UNDERVOLT S R Q PICKUP L2 CB closed L2 1 UL3 UL3 2505 UNDERVOLT S R Q PICKUP L3 CB closed L3 1 with earth fault protection with dist protection applies to PUTT and POTT with unblockschemes the unblock signals apply acc to Fig 6 61 applies to direc comp with unblock schemes the unblock signals apply 4203 Dis T RecCh1L2 4208 Dis T RecCh1L...

Page 348: ...e end is activated There is however no tripping at the line end with missing or weak infeed condition As the weak infeed measures are dependent on the signal reception from the opposite line end they only make sense if the protection is coordi nated with teleprotection refer to Section 6 6 and or 6 8 The receive signal is a functional component of the trip condition Accordingly the weak infeed tri...

Page 349: ...arm Comments 4203 BLOCK Weak Inf BLOCK Weak Infeed Trip function 4221 WeakInf OFF Weak Infeed Trip fct is switched OFF 4222 Weak Inf BLOCK Weak Infeed Trip function is BLOCKED 4223 Weak Inf ACTIVE Weak Infeed Trip function is ACTIVE 4231 WeakInf PICKUP Weak Infeed Trip function PICKED UP 4232 W I Pickup L1 Weak Infeed Trip function PICKUP L1 4233 W I Pickup L2 Weak Infeed Trip function PICKUP L2 4...

Page 350: ...n 6 5 On conventional transmission paths one transmission channel per desired transmission direction is required for remote tripping at the remote end For example fibre optic connections or voice frequency modulated high frequency channels via pilot cables power line carrier or microwave radio links can be used for this purpose in the following ways If the trip command of the distance protection i...

Page 351: ...s the set minimum trip command duration TMin TRIP CMD which was set for the device in general in address 240A Sub section 6 1 1 Reliable operation of the circuit breaker is therefore ensured even if the initiating signal pulse is very short 6 10 3 Settings 6 10 4 Information Overview Addr Setting Title Setting Options Default Setting Comments 2201 FCT Direct Trip ON OFF OFF Direct Transfer Trip DT...

Page 352: ...iately blocked and the emergency operation is activated If the overcurrent protection is configured as back up overcurrent protection it func tions independently of the other protective and monitoring functions therefore also in dependent of the distance protection The back up overcurrent protection could for in stance be used as the only short circuit protection if the voltage transformers are no...

Page 353: ...ge earth fault currents may occur If the fourth current input I4 is used e g for a power transformer star point current or for the earth current of a parallel line the device derives the earth current from the phase currents Naturally in this case also all three phase currents derived from a set of three star connected current transformers must be available and connected to the device Definite Tim...

Page 354: ...ics was already done during the configuration of the protection functions Furthermore an additional constant time delay T Ip Add address 2646 may be selected which are added to the current dependant time derived from the IDMT characteristic The available char acteristics are shown in the technical data Section 10 5 Figure 10 1 to 10 3 Figure 6 92 shows the logic diagram The setting parameter addre...

Page 355: ...TF 2670 Yes No further stages 3I0P 1 E IE 2652 T 3I0p Time Dial T 0 t I IP 1 L1 2642 T Ip Time Dial 2646 T Ip Add T 0 2660 IEC Curve t I IL3 IL2 IL1 L2 L3 2640 IP 2656 T 3I0p Add 2650 3I0p PICKUP switch onto fault T 0 2680 SOTF Time DELAY I 3I0 p Tele BI Ip Pickup L3 Ip Pickup L2 Ip Trip L3 Ip Trip L2 Ip Pickup L1 Ip Trip L1 3I0p Trip 3I0p Pickup 7106 BLOCK O C Ip 7110 O C InstTRIP ...

Page 356: ...e two sets of current transformers are connected in parallel such that the current sum IF IA IB represents the current flowing towards the line isolator The stub protection is an overcurrent protection which is only in service when the state of the line isolator indicates the open condition via a binary input I STUB ENABLE The binary input must therefore be operated via an auxiliary contact of the...

Page 357: ...n be determined via setting parameter for which stage s the rapid tripping following closure on to a dead fault applies Refer also to the logic diagrams in Figures 6 91 6 92 and 6 94 and Subsection 6 1 3 margin Circuit Breaker Status Fault Detection and Trip Logic The fault detection signals of the individual phases and earth and the individual stag es are combined in such a manner that both the p...

Page 358: ...ickup L2 Ip Pickup L2 I STUB Pickup L2 6 91 6 92 6 94 O C Pickup L2 7163 I Pickup L3 I Pickup L3 Ip Pickup L3 I STUB Pickup L3 6 91 6 92 6 94 O C Pickup L3 7164 I Pickup E I Pickup E Ip Pickup E I STUB Pickup E 6 91 6 92 6 94 O C Pickup E 7165 I Pickup L1 I Pickup L2 I Pickup L3 I Pickup E 6 91 6 91 6 91 6 91 O C PICKUP I 7191 I Pickup L1 I Pickup L2 I Pickup L3 I Pickup E O C PICKUP I 7192 Ip Pic...

Page 359: ...rrect On long cables where large inrush currents may arise or on transformers a short time delay setting may be reasonable The time delay depends on the severity and duration of the transient overcurrents as well as on which stages were selected for the fast switch onto fault clearance High Set Overcurrent Stages Iph 3I0 The I stages Iph address 2610 and 3I0 address 2612 along with the I stages or...

Page 360: ...ues An analogous calculation can be done for earth faults whereby the maximum earth fault current that flows during an earth fault at the end of the line is decisive The set time delays are pure additional delays which do not include the operating time measuring time The parameter I Telep BI address 2614 determines whether the delay times T Iph address 2611 and T 3I0 address 2613 may be bypassed v...

Page 361: ... 6 7 The time delay T Iph address 2621 which has to be set is derived from the grading plan of the system If implemented as emergency overcurrent protection shorter trip ping time delays one grading time margin longer than the fast tripping stage are ad visable as this function is only activated when the local measured voltage fails The time T 3I0 address 2623 can usually be set with a smaller tim...

Page 362: ...implemented as emergency overcurrent protec tion shorter tripping times are advisable one grading time margin above the fast trip ping stage as this function is only activated in the case of the loss of the local meas ured voltage The time multiplier setting T 3I0p TimeDial address 2652 can usually be set smaller according to a separate earth fault grading plan In addition to the current dependant...

Page 363: ...as this function is only activated in the case of the loss of the local measured voltage The time multiplier setting TimeDial TD3I0p address 2653 can usually be set smaller according to a separate earth fault grading plan In addition to the current dependant time delay an additional constant time length de lay can be set if required The setting T Ip Add address 2646 for phase currents and T 3I0p A...

Page 364: ...pplications similar considerations as for the other stages apply If the I Stub stage is to trip when switching the line on to a fault with or without a short delay SOTF Time DELAY address 2680 see above and refer to Sub section General the parameter I STUB SOTF address 2635 is set to YES If using the stub protection then set to NO as the effect of this protection function only depends on the posit...

Page 365: ...ry Inverse Extremely Inverse Long time inverse Normal Inverse IEC Curve 2661 ANSI Curve Inverse Short Inverse Long Inverse Moderately Inverse Very Inverse Extremely Inverse Definite Inverse Inverse ANSI Curve 2670 I 3I0 p Tele BI NO YES NO Instantaneous trip via Teleprot BI 2671 I 3I0 p SOTF NO YES NO Instantaneous trip after Swit chOnToFault 2630 Iph STUB 0 10 25 00 A 1 50 A Iph STUB Pickup 2631 ...

Page 366: ...kup O C Pickup Only L2 7175 O C Pickup L2E Backup O C Pickup L2E 7176 O C Pickup L12 Backup O C Pickup L12 7177 O C Pickup L12E Backup O C Pickup L12E 7178 O C PU 1p L3 Backup O C Pickup Only L3 7179 O C Pickup L3E Backup O C Pickup L3E 7180 O C Pickup L31 Backup O C Pickup L31 7181 O C Pickup L31E Backup O C Pickup L31E 7182 O C Pickup L23 Backup O C Pickup L23 7183 O C Pickup L23E Backup O C Pic...

Page 367: ...7SA6 Manual C53000 G1176 C156 2 7221 O C TRIP I Backup O C TRIP I 7222 O C TRIP I Backup O C TRIP I 7223 O C TRIP Ip Backup O C TRIP Ip 7235 I STUB TRIP O C I STUB TRIP 2054 Emer mode Emergency mode F No Alarm Comments ...

Page 368: ...circuit following the switching off of large currents practically have no influence on the high current pick up operation Figure 6 95 shows the logic diagram The high current switch on to fault function can be phase segregated or three phase Following manual closure of the circuit breaker it always functions three phase via the release signal SOTF O C Release L123 which is derived from the central...

Page 369: ...c reclosure dead time on a parallel feeder It is recommended to set at least 2 5 times the rated current of the feeder 6 12 3 Settings Note The indicated secondary current values for setting ranges and default settings refer to IN 1 A For the nominal current 5 A the current values are to be multiplied by 5 6 12 4 Information Overview Addr Setting Title Setting Options Default Setting Comments 2401...

Page 370: ...age Determination of the faulted phase by measuring the phase to earth voltages Determination of the direction of the earth fault residual current by high accuracy real and reactive component measurement Pickup The pickup is achieved when the settable threshold for the displacement voltage 3 U0 is exceeded To ensure measurement of stable values all earth fault detection func tions are delayed unti...

Page 371: ...on In this case only the ohmic active residual current which re sults from the losses of the Petersen coil can be used for directional determination This earth fault ohmic current is only a few percent of the capacitive earth fault current In 7SA6 the earth fault direction is determined from a highly accurate calculation of ac tive and reactive power using the definitions where T equals period of ...

Page 372: ...ault detection is partic ularly designed for this purpose and permits an extremely high sensitivity for the direc tional determination of the wattmetric residual current In order to utilize this sensitivity it is recommended that core balance current transformers be used for earth fault de tection in compensated networks As even the core balance transformers have an angle error the protection syst...

Page 373: ...th earth fault detection module and only when these are used in networks with isolated or compensated starpoint In other cas es this section can be passed over Earth fault detection is only possible if address Sens Earth Flt Section 5 1 was set to enabled during the configuration Section 5 1 If the device is equipped with earth fault detector but supposed to operate in an earthed network address 1...

Page 374: ...f tripping is also required for earth faults address 3001 Sens Earth Flt ON a delay time can be set in address 3007 T 3U0 For phase determination Uph e min address 3003 is the criterion for the earth faulted phase when simultaneously the other two phase voltages have exceeded Uph e max address 3004 Accordingly Uph e min must be set lower than the minimum operational phase earth voltage This settin...

Page 375: ...or window type transformers are used Here also use the rule of thumb setting at half the expected measured current whereby only the residual wattmetric current is applicable This residual wattmetric current is provided principally by the losses in the Petersen coil Example The same network as in the previous example is considered to be compen sated by a Petersen coil The coil is matched to the tot...

Page 376: ...f the device ϕ I F2 F1 I1 I2 Addr Setting Title Setting Options Default Setting Comments 3001 Sens Earth Flt Alarm Only ON OFF Alarm Only Sensitive Earth Flt comp isol starp 3002 3U0 1 150 V 50 V 3U0 pickup 3003 Uph e min 10 100 V 40 V Uph e min of faulted phase 3004 Uph e max 10 100 V 75 V Uph e max of healthy phases 3005 3I0 0 003 1 000 A 0 050 A 3I0 Release directional ele ment 3006 T Sens E F ...

Page 377: ... 1263 SensEF ACTIVE Sensitve E F detection is ACTIVE 1271 SensEF Pickup Sensitve E F detection picked up 1272 SensEF Phase L1 Sensitve E F detection Phase L1 1273 SensEF Phase L2 Sensitve E F detection Phase L2 1274 SensEF Phase L3 Sensitve E F detection Phase L3 1276 SensEF Forward Sensitve E F detection Forward 1277 SensEF Reverse Sensitve E F detection Reverse 1278 SensEF undefDir Sensitve E F ...

Page 378: ...head line in block with a transformer or overhead line cable it must be ensured that reclosure can only be performed in the event of a fault on the overhead line In the version with single pole tripping 7SA6 allows phase segregated single pole tripping A single and three pole single and multiple shot automatic reclosure function is integrated depending on the ordered version 7SA6 can also operate ...

Page 379: ...nal transmission logic controls the overreaching zone i e it determines whether an undelayed trip or delayed with T1B is permitted in the event of faults in the overreaching zone i e up to the reach limit of zone Z1B at both line ends simultaneously Whether the automatic reclosure function is ready for reclos ure or not is irrelevant because the teleprotection function ensures the selectivity over...

Page 380: ...eclosure will be of no use here Examples for this in the 7SA6 are the overload pro tection and overvoltage protection Action Times It is often desirable to suppress the readiness for reclosure if the short circuit condition was sustained for a certain time e g because it is assumed that the arc has burned in to such an extent that there is no longer any chance of automatic arc extinction during th...

Page 381: ...is cycle cannot start the automatic reclosure circuit However the 2nd cycle which is also able to start the recloser is activated im mediately This 2nd cycle therefore starts the automatic reclosure circuit the 1st cycle is practically skipped Operating Modes of the Automatic Reclosure Function The dead times in other words the time from fault clearance reset of the trip com mand or indication by ...

Page 382: ... the user definable logic functions CFC further control functions may also be treated like a Manual Close command Interrogation of Circuit Breaker Ready A precondition for automatic reclosure following clearance of a short circuit is that the circuit breaker is ready for at least one TRIP CLOSE TRIP cycle when the automatic reclosure is started i e at the time of the first trip command The circuit...

Page 383: ...er also applies if the CB trips two poles following a single pole trip command The device can only detect this if the auxiliary contacts of each pole are connected in dividually The device immediately initiates three pole coupling thus resulting in a three pole trip command If the CB auxiliary contacts indicate that at least one further pole has opened during the dead time following a single pole ...

Page 384: ... Trip page 207 If the fault has been cleared successful reclosure the reclaim time runs out and all functions return to their quiescent state The system fault has ended If the fault is not cleared unsuccessful reclosure the short circuit protection issues a final trip with the protection stage that is valid without reclosure Any fault during the reclaim time also leads to a final trip After unsucc...

Page 385: ...ve However if the first reclosure attempt was unsuccessful the reclosure function is not blocked but instead the next reclose cycle is started The appropriate dead time starts with the reset of the trip command or opening of the circuit breaker pole aux iliary contact criterion The circuit breaker receives a new close command after expiry of the dead time At the same time the reclaim time is start...

Page 386: ... activated The automatic reclosure function then checks the discon nected line for no voltage The line must have been without voltage for at least an ad equate measuring time during the dead time If this was not the case the reclosure is blocked dynamically This no voltage check on the line is of advantage if a small generator e g wind generator is connected along the line Reduced Dead Time RDT If...

Page 387: ...the automatic reclosure function at line end II decides in dependently if and when reclosure is sensible and is therefore allowed and when it is not The criterion is the voltage on the line at end II which is fed from end I following reclosure there Reclosure therefore takes place at end II as soon as it is apparent that voltage has been re applied to the line from end I In the illustrated case th...

Page 388: ... Close Command transfer Remote CLOSE With close command transmission the dead times are only set at one line end The other or the others in case of lines with more than two end s is are set to adaptive dead time These ends respond to the received close command from the transmitting end The transmission of the close command by the transmitting line end is delayed until it is sure that the local rec...

Page 389: ...y do so in the case of single phase faults in the event of multiple phase faults these stages do not operate This input is not required if no overreaching stage is used e g differential protection or comparison mode with distance protection see also above under subtitle Selectivity before Reclos ure 381 1p Trip Perm The external reclosure device allows 1 pole tripping logic inversion of 3 pole cou...

Page 390: ...ure device and the trip signals F No 511 from 7SA6 see figure 6 107 usually suffice Figure 6 106 Connection example with external reclosure device for 1 3 pole reclosure with mode selector switch Figure 6 107 Connection example with external reclosure device for 3 pole reclosure 7SA6 L external reclosure device 1 pole 3 pole 1 3 pole L Selector switch L L L L Relay PICKUP Relay TRIP 3ph Relay TRIP...

Page 391: ...In other cases this input information is superfluous The trip commands decide whether the dead time for single pole or three pole reclose cycles is activated or whether the reclosure is blocked in the event of a three pole trip depending on the set dead times Figure 6 108 for example shows the interconnection between the internal automatic reclosure function in the 7SA6 and an external protection ...

Page 392: ...eaching stages of the external protection are again enabled by AR 1 CycZoneRel F No 2889 and if applicable by further cycles Figure 6 108 Connection example with external protection device for 1 3 pole reclosure AR control mode with TRIP Figure 6 109 Connection example with external protection device for 3 pole reclosure AR control mode with TRIP 7SA6 AR Start Tripping L1 Tripping L2 Tripping L3 L...

Page 393: ... PICKUP 2 Protection Devices with 2 Automatic Reclosure Functions If redundant protection is provided for a line and each protection operates with its own automatic reclosure function a certain signal exchange between the two combinations is necessary The connection example in figure 6 111 shows the necessary cross connections 7SA6 Pick up L1 Pick up L2 Pick up L3 Tripping L external protection de...

Page 394: ...all circumstances Figure 6 111 Connection example for 2 protection devices with 2 automatic reclosure func tions 2nd Second protection 7SA6 Relay TRIP 1pL1 Relay TRIP 3ph Relay TRIP 1pL2 Relay TRIP 3ph Relay TRIP 1pL3 Relay TRIP 3ph L L automatic reclosure internal AR function BI BI BI BI Trip L1 Trip L2 Trip L3 BI BI BI BI Protective function AR Start L Trip L1 Trip L2 Trip L3 SO SO SO SO 2nd pro...

Page 395: ...uit breaker is signalled to the device through the binary input CB1 Ready F No 371 If no such signal is available leave the setting under address 3402 CB 1 TRIP No because no automatic reclosure would be possible at all oth erwise If circuit breaker readiness can be interrogated the setting CB 1 TRIP Yes should be applied Furthermore the circuit breaker ready state can also be interrogated prior t...

Page 396: ...ection with pickup requires the connection of a start signal from the external device to the 7SA6 otherwise an evolv ing fault can only be detected with the external trip command even if with PICKUP was set here The reaction in response to evolving faults can be selected under address 3407 EV FLT MODE blocks AR means that no reclosure takes place after detection of an evolving fault This is always...

Page 397: ...ubtitle Processing the Circuit Breaker Auxiliary Contacts The forced three pole trip is also activated when only three pole cycles are allowed but a single pole trip is signalled externally via a binary input The forced three pole trip is unnecessary if only a common three pole control of the CB is possible Dead Line Check Reduced Dead Time Under address 3431 the dead line check or the reduced dea...

Page 398: ... If the command does not appear until after the action time has expired there is no reclosure Depending on the configuration of the protection func tions see section 5 1 the action time may also be omitted this particularly applies when an initiating protection function has no fault detection signal only trip signal The dead times are determined by the reclosure command of the device at the line e...

Page 399: ...pole tripping It determines whether auto matic reclosure should be started at all with the first cycle This address is included mainly for the sake of uniformity of the parameters for all the reclosure cycles and must be set to Yes for the first cycle If several cycles are used it is possible to control in control mode with PICKUP the effect of the individual cycles with this parameter and various...

Page 400: ...e here Normally the setting constraints are similar to address 3457 1 AR Tdead3Trip Under address 3459 1 AR CB CLOSE it can be determined whether circuit breaker ready must be interrogated before this first reclosure With the setting Yes the dead time may be extended if the circuit breaker is not ready for a CLOSE TRIP cycle when the dead time expires At most the dead time can be extended by the C...

Page 401: ... in 4th cycle is allowed at all Address 3484 4 AR T ACTION action time for the 4th cycle Address 3486 4 AR Tdead 1Flt dead time after 1 phase starting Address 3487 4 AR Tdead 2Flt dead time after 2 phase starting Address 3488 4 AR Tdead 3Flt dead time after 3 phase starting Address 3489 4 AR Tdead1Trip dead time after 1 pole tripping Address 3490 4 AR Tdead3Trip dead time after 3 pole tripping Add...

Page 402: ... 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 Tdead 2Flt 0 01 1800 00 sec 1 20 sec Dead time after 2phase faults 3455 1...

Page 403: ...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 reclosing 3482 3 AR SynRequest YES NO NO Request for synchro check after 3pole AR 3483 4 AR START YES NO NO AR start allowed in this cycle 3484 4 AR T ACTION 0 01 300 00 sec 0 20 sec Action time 3486 4 AR Tdead 1...

Page 404: ...breaker not ready This information indicates to the operational information system that in the event of an upcoming sys tem fault there will be a final trip i e without reclosure If the automatic reclosure is already started this information does not appear AR not ready F No 2784 The automatic reclosure is not ready for reclosure at the moment In addition to the AR is blocked F No 2783 mentioned a...

Page 405: ...715 Trip 1pole AR AR External 1pole trip for AR start 2716 Trip 3pole AR AR External 3pole trip for AR start 2727 AR RemoteClose AR Remote Close signal 2731 Sync release AR Sync release from ext sync check 2737 BLOCK 1pole AR AR Block 1pole AR cycle 2738 BLOCK 3pole AR AR Block 3pole AR cycle 2739 BLK 1phase AR AR Block 1phase fault AR cycle 2740 BLK 2phase AR AR Block 2phase fault AR cycle 2741 B...

Page 406: ... Tdead 3pFlt AR dead time after 3phase fault running 2844 AR 1stCyc run AR 1st cycle running 2845 AR 2ndCyc run AR 2nd cycle running 2846 AR 3rdCyc run AR 3rd cycle running 2847 AR 4thCyc run AR 4th or higher cycle running 2848 AR ADT run AR cycle is running in ADT mode 2851 AR CLOSE Cmd AR Close command 2852 AR Close1 Cyc1p AR Close command after 1pole 1st cycle 2853 AR Close1 Cyc3p AR Close comm...

Page 407: ...oltage transformers Figure 6 112 Synchronism check on closing If a power transformer is situated between the feeder voltage transformers and the bus bar voltage transformers Figure 6 113 its vector group can be compensated for by the 7SA6 relay so that no external matching transformers are necessary The synchronism check function in the 7SA6 usually operates in conjunction with the integrated auto...

Page 408: ... condition can be set If closing is permitted under syn chronous as well as under asynchronous system conditions a frequency difference below 0 01 Hz is treated as a synchronous condition a higher frequency difference value can then be set for closing under asynchronous system conditions The synchronism check function only operates when it is requested to do so This re quest can come from the inte...

Page 409: ...sure at one line end only dead line and at the other only synchronism will be permitted Dead line or dead bus closing For release of the closing command to energize a voltage free line from a live bus bar the following conditions are checked Does the feeder voltage Uline lie below the set value Dead Volt Thr Does the bus bar voltage Ubus lie above the set value Live Volt Thr but be low the maximum...

Page 410: ... upto the next instant of voltage phase synchronism from the rate of change of angle and the frequency dif ference The closing command is then released at the instant when the remaining time upto the next instant of synchronism equals the closing time of the breaker 6 15 2 Applying the Function Parameter Settings Preconditions When setting the general power system data Power system data 1 refer to...

Page 411: ...bus bar is regarded as being definitely live is set under address 3503 Live Volt Thr for live line or live bus check and for the lower voltage limit of synchronism check It must be set below the minimum ex pected operating voltage under normal conditions Setting is in volts secondary When operating the device from a personal computer using DIGSI 4 setting may be in sec ondary or primary values Dep...

Page 412: ...fference between the voltages is set under address 3512 Max Freq Diff the permissible phase angle difference under address 3513 Max Angle Diff The further release conditions for automatic reclosing are set under addresses 3515A to 3519 3515A SYNC CHECK synchronism check the bus bar Ubus and the feeder Uline must both be live Live Volt Thr address 3503 the conditions for synchro nism Max Volt Diff ...

Page 413: ...rth voltage is decisive The permissible frequency difference between the voltages is set under address 3532 MC maxFreq Diff the permissible phase angle difference under address 3533 MC maxAngleDiff The release conditions for manual closing are set under addresses 3535A to 3539 3535A MC SYNCHR synchronism check the bus bar Ubus and the feeder Uline must both be live Live Volt Thr address 3503 the c...

Page 414: ... 0 V 2 0 V Maximum voltage difference 3512 Max Freq Diff 0 03 2 00 Hz 0 10 Hz Maximum frequency difference 3513 Max Angle Diff 2 60 10 Maximum angle difference 3515A SYNC CHECK YES NO YES Live bus live line and Sync before AR 3516 Usync U line YES NO NO Live bus dead line check before AR 3517 Usync U line YES NO NO Dead bus live line check before AR 3518 Usync U line YES NO NO Dead bus dead line c...

Page 415: ...1 Release signal to an external automatic reclosure device 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 Addr Setting Title Setting Options Default Setting Comments F No Alarm Comments 2901 Sync on Switch on synchro check function 2902 Sync off Switch off synchro check function 2903 BLOCK Sync BLOCK synchro check fu...

Page 416: ... limit 2948 Sync fdiff Sync Freq diff greater than limit 2949 Sync ϕ diff Sync Angle diff greater than limit 2951 Sync release Synchronism release to ext AR 2961 Sync CloseCmd Close command from synchro check 2970 Sync f bus Sync Bus frequency fn 3Hz 2971 Sync f bus Sync Bus frequency fn 3Hz 2972 Sync f line Sync Line frequency fn 3Hz 2973 Sync f line Sync Line frequency fn 3Hz 2974 Sync U syn Syn...

Page 417: ... Furthermore the device calculates the positive sequence system voltage and the negative se quence system voltage so that the symmetrical components are also monitored The phase voltages UL1 E UL2 E and UL3 E the phase to phase voltages UL1 L2 UL2 L3 and UL3 L1 as well as the positive sequence system can also be used for the undervoltage protection These voltage protection functions can be combine...

Page 418: ...tes the positive sequence system voltage according to its defining equation U1 1 3 UL1 a UL2 a2 UL3 with a ej120 The resulting single phase AC voltage is fed to the two threshold stages U1 and U1 see Figure 6 115 Combined with the associated time delays these stages form a two stage overvoltage protection for the positive sequence system Here too the drop off to pick up ratio can be set The overvo...

Page 419: ...time to avoid pick up with the false negative sequence values arising during this state If the device cooperates with an external automatic reclosure function or if a sin gle pole tripping can be triggered by a different protection system working in parallel the overvoltage protection for the negative sequence system must be blocked via a binary input during single pole tripping Overvoltage Zero S...

Page 420: ...ltage and calculate the tri ple zero sequence voltage 3 U0 Uph Udelta U4 As the voltage transformation of the voltage transformer set is usually the factor is Uph Udelta 3 3 3 1 73 For more details see Power System Data 1 in Section 6 1 1 margin heading Voltage Transformer Connection address 0211 Figure 6 116 Logic diagram of the overvoltage protection for zero sequence voltage Freely Selectable S...

Page 421: ...t breaker it is switched on at the outgoing side For the undervoltage protec tion this results in a pick up state being present if the voltage transformers are on the outgoing side If this pick up must be reset the current can be used as an additional criterion current supervision CURR SUP to achieve this result Undervoltage will then only be detected if together with the undervoltage condition th...

Page 422: ...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 for automatic reclosure using the internal automatic re closure function the stages of the undervoltage protection are automatically blocked in the disconnected phase so that it does not respo...

Page 423: ...d 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 6 21 1 3 or if the trip of the mcb for the voltage transformer is indicated via the binary input FAIL Feeder VT internal blocking Figure 6 118 Logic diagram of the undervoltage protection for positive sequence voltage sys tem During...

Page 424: ... nominal phase earth voltage 0 1 s to 0 2 s are sufficient for the time delay T Uph e ad dress 3705 Overvoltage Phase Phase Basically the same considerations apply as for the phase voltage stages These stag es may be used instead of the phase voltage stages or be used addionally The ad dress 3711 Uph ph is set to On Off or Alarm Only As phase to phase voltages will be detected phase to phase value...

Page 425: ...at are to be expect ed not only the time delay T 3U0 address 3724 must be greater but also the reset ratio 3U0 Reset Ratio address 3723 must also be as large as possible Usually the presetting is sufficient This setting can only be modified with DIGSI 4 under Ad ditional Settings Similar considerations apply if this voltage stage is used for a different voltage at the measuring input U4 When setti...

Page 426: ... Address 3761 Uph ph is set to On Off or Alarm Only As phase to phase voltages are monitored the phase to phase values are used for the settings Uph ph address 3762 and Uph ph address 3764 The corresponding times delay are T Uph ph address 3763 und T Uphph ad dress 3765 If the voltage transformers are located on the line side the measuring voltages will missing if the line is disconnected To avoid...

Page 427: ...o 3711 Uph ph OFF Alarm Only ON OFF Operating mode Uph ph over voltage prot 3712 Uph ph 2 0 220 0 V 150 0 V Uph ph Pickup 3713 T Uph ph 0 00 30 00 sec 2 00 sec T Uph ph Time Delay 3714 Uph ph 2 0 220 0 V 175 0 V Uph ph Pickup 3715 T Uph ph 0 00 30 00 sec 1 00 sec T Uph ph Time Delay 3719A Uphph RESET 0 50 0 98 0 98 Uph ph Reset ratio 3721 3U0 or Ux OFF Alarm Only ON OFF Operating mode 3U0 or Ux ov...

Page 428: ...e 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 30 00 sec 2 00 sec T Uph ph Time Delay 3764 Uph ph 1 0 175 0 V 0 17 0 V Uph ph Pickup 3765 T Uphph 0 00 30 00 sec 1 00 sec T Uph ph Time Delay 3768 CURR SUP Uphph ON OFF ON Current supervision Uph ph 3771 U1 OFF Alarm Onl...

Page 429: ... 10223 U2 OFF U2 Overvolt is switched OFF 10224 U2 BLK U2 Overvolt is BLOCKED 10225 Uph e OFF Uph e Undervolt is switched OFF 10226 Uph e BLK Uph e Undervolt is BLOCKED 10227 Uph ph OFF Uph ph Undervolt is switched OFF 10228 Uph ph BLK Uphph Undervolt is BLOCKED 10229 U1 OFF U1 Undervolt is switched OFF 10230 U1 BLK U1 Undervolt is BLOCKED 10231 U ACTIVE Over Under Voltage protection is ACTIVE 102...

Page 430: ...10292 U2 TimeOut U2 TimeOut 10293 U2 TimeOut U2 TimeOut 10294 U2 TRIP U2 TRIP command 10300 U1 Pickup U1 Pickup 10301 U1 Pickup U1 Pickup 10302 U1 TimeOut U1 TimeOut 10303 U1 TimeOut U1 TimeOut 10304 U1 TRIP U1 TRIP command 10310 Uph e Pickup Uph e Pickup 10311 Uph e Pickup Uph e Pickup 10312 Uph e PU L1 Uph e Pickup L1 10313 Uph e PU L2 Uph e Pickup L2 10314 Uph e PU L3 Uph e Pickup L3 10315 Uph ...

Page 431: ...Functions 6 241 7SA6 Manual C53000 G1176 C156 2 10330 Uphph TimeOut Uphph TimeOut 10331 Uphph TimeOut Uphph TimeOut 10332 Uphph TRIP Uphph TRIP command F No Alarm Comments ...

Page 432: ...the circuit breaker even with very fast circuit breakers Filtering of the measured values and the number of impedance calculations are automatically adapted to the number of stabi lized measured value pairs in the determined data window If a sufficient data window with stabilized values could not be determined the alarm Flt Loc invalid is is sued The evaluation of the measured values in the short ...

Page 433: ...tion of the protection functions Section 5 1 in Special Cases page 3 For more information about the analog output settings please refer to Subsection 6 20 Note The distance can only be applicable in the form of kilometres miles or percent if the relevant line section is homogeneous If the line is composed of line sections with different reactance per unit length characteristic e g overhead line ca...

Page 434: ...sitive and zero phase sequence components of the symmetrical components are used in the compensation Load compensation can be switched on or off for the fault locator address 3806 Load Compensat Off switching is useful for example during relay testing in or der to avoid influences caused by the test quantities Figure 6 119 Fault currents and voltages on double end fed lines 6 17 2 Applying the Fun...

Page 435: ...urrent input I4 with the correct polarity and the parameter for the fourth current input I4 transformer has been set to In paral line address 220 in the power system data 1 refer also to Sub sec tion 6 1 1 under Current Transformer Connection and the current transformer ratio I4 Iph CT address 221 in the power system data 1 has been set correctly refer also to Sub section 6 1 1 under Current Trans...

Page 436: ...ting Options Default Setting Comments 3802 START Pickup TRIP Pickup Start fault locator with 3805 Paral Line Comp NO YES YES Mutual coupling parall line com pensation 3806 Load Compensat NO YES NO Load Compensation 3811 Tmax OUTPUT BCD 0 10 180 00 sec 0 30 sec Maximum output time via BCD ...

Page 437: ...ator Loop L2E 1125 FL Loop L3E Fault Locator Loop L3E 1126 FL Loop L1L2 Fault Locator Loop L1L2 1127 FL Loop L2L3 Fault Locator Loop L2L3 1128 FL Loop L3L1 Fault Locator Loop L3L1 1132 Flt Loc invalid Fault location invalid 1133 Flt Loc ErrorK0 Fault locator setting error K0 angle K0 1143 BCD d 1 BCD Fault location 1 1144 BCD d 2 BCD Fault location 2 1145 BCD d 4 BCD Fault location 4 1146 BCD d 8 ...

Page 438: ... 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 com mand 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 pro tection itself recognizes the interruption ...

Page 439: ...and compared with the set threshold Besides the three phase currents two further current detectors are provided in order to allow a plausibil ity check see Figure 6 122 The earth current residual current IE 3 I0 is preferably used as plausibility current If the residual current from the star point of the current transformer set is connected to the device this is used for 3 I0 If the residual curre...

Page 440: ...soon as the current disappears even if the associated auxiliary contact does not yet indicate that the circuit breaker has opened Figure 6 123 This gives preference to the more reli able current criterion and avoids overfunctioning due to a defect e g in the auxiliary contact mechanism or circuit This interlock feature is provided for each individual phase as well as for three pole trip It is poss...

Page 441: ...mmand is connected to the 7SA6 by two separate wire pairs in order to achieve dual channel initiation of the breaker failure protection 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 re lease must then not be assigned to any physical input of the device during configu ration The ...

Page 442: ...ked via the binary input BLOCK BkrFail e g during testing of the feeder protection relay Additionally an internal blocking option is provided Figure 6 125 Breaker failure protection with common phase initiation 1 CB Aux L1 Start L123 CB Aux L2 CB any pole closed S R Q FNr 351 FNr 352 L1 L2 L3 1 CB Aux L3 FNr 353 CB 3p Closed FNr 379 CB 3p Open FNr 380 Start internal w o l BF Start 3pole Start L123...

Page 443: ...y input BF re lease must then not be assigned to any physical input of the device during configu ration If the external protection device does not provide a general fault detection signal a general trip signal can be used instead Alternatively the parallel connection of a sep arate set of trip contacts can produce such a release signal as shown in Figure 6 127 The starting condition logic for the ...

Page 444: ...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 fail protection by the central function control of the de vice refer to Section 6 22 2 The three phase starting signal Start L123 is generated if trip signals appear in more than one pole regardless from which protection function P...

Page 445: ...rt L3 1 Start internal w o I BF START 3pole Start L123 Start only L1 Start only L2 Start only L3 BF release not allocated allocated 1 Configuration Internal blocking 2 1 1 1 1 1 BF Start w o I Start internal 3pole Start internal L1 Start internal L2 Start internal L3 L1 CB pole L1 closed Yes No 3909 Chk BRK CONTACT 1 L2 Yes No 1 L3 Yes No 1 L2 L3 L1 CB any pole closed Yes No 1 1 1 BF Start FNo 143...

Page 446: ...gle pole tripping If different delay times are required after a single pole trip and three pole trip by the feeder protection it is possible to use the timer stages T1 1pole and T1 3pole ac cording to Figure 6 130 Figure 6 129 Single stage breaker failure protection with common phase initiation Figure 6 130 Single stage breaker failure protection with different delay timers With two stage breaker ...

Page 447: ...cuit breaker is not operational Figure 6 132 Circuit breaker not operational Transfer Trip to the Remote End Circuit Breaker The 7SA6 has the facility to give an additional intertrip signal to the circuit breaker at the remote line end in the event that the local feeder circuit breaker fails For this a suitable protection signal transmission link is required e g via communication cable power line ...

Page 448: ...uation and to transmit a trip signal to the remote end s of the protected object to clear the fault For this purpose the output command BF EndFlt TRIP is available to trigger a signal transmission device e g power line carrier radio wave or optical fibre if applicable together with other commands that need to be transferred The end fault is recognized when the current continues flowing although th...

Page 449: ...uxiliary contacts indicate a different status If pole discrepancy is detected this is annunciated by a fault detection signal This sig nal identifies the pole which was open before the trip command of the pole discrepan cy supervision occurred Figure 6 135 Function block diagram of pole discrepancy supervision 6 18 2 Applying the Function Parameter Settings General The breaker failure protection a...

Page 450: ...bus bar or bus bar section and if signal transmission is possible the breaker at the remote end s of the protected object In the 7SA6 after a further delay time T2 address 3906 the adjacent circuit breakers i e the breakers of the bus bar zone and if signal transmission is possible the breaker at the remote end are tripped provided the fault has not yet been cleared An example of the time se quenc...

Page 451: ...ses 3904 T1 1pole and 3905 T1 3pole but set address 3903 1p RETRIP T1 to No to avoid a single pole trip to the bus bar And set T2 address 3906 to or equal to T1 3pole Be sure that the correct trip commands are assigned to the desired trip relay s The delay times are determined from the maximum operating time of the feeder circuit breaker the reset time of the current detectors of the breaker failu...

Page 452: ... of the feed er protection or by the bus bar protection the fault is a bus bar fault as determined from the location of the current transformers the fault current will continue to flow be cause the fault is fed from the remote end of the feeder circuit The time T EndFault address 3922 is started when during the fault detection con dition of the feeder protection the circuit breaker auxiliary conta...

Page 453: ...itle Setting Options Default Setting Comments 3901 FCT BreakerFail ON OFF ON Breaker Failure Protection is 3902 I BF 0 05 20 00 A 0 10 A Pick up threshold I 3903 1p RETRIP T1 NO YES YES 1pole retrip with stage T1 local trip 3904 T1 1pole 0 00 30 00 sec 0 00 sec T1 Delay after 1pole start local trip 3905 T1 3pole 0 00 30 00 sec 0 00 sec T1 Delay after 3pole start local trip 3906 T2 0 00 30 00 sec 0...

Page 454: ... failure is switched OFF 1452 BkrFail BLOCK Breaker failure is BLOCKED 1453 BkrFail ACTIVE Breaker failure is ACTIVE 1461 BF Start Breaker failure protection started 1493 BF TRIP CBdefec BF Trip in case of defective CB 1472 BF T1 TRIP 1pL1 BF Trip T1 local trip only phase L1 1473 BF T1 TRIP 1pL2 BF Trip T1 local trip only phase L2 1474 BF T1 TRIP 1pL3 BF Trip T1 local trip only phase L3 1476 BF T1...

Page 455: ... a warning alarm is given in order to allow a timely load reduction When the sec ond temperature threshold i e the final overtemperature or tripping temperature is reached the protected object is disconnected from the network The overload protec tion can however also be set on Alarm Only In this case only an alarm is output when the final overtemperature is reached The overtemperature is calculate...

Page 456: ...s at the same time the current at which the e func tion of the overtemperature has its asymptote It is not necessary to determine the trip ping temperature since it results automatically from the final rise temperature at k IN Manufacturers of electrical machines usually state the permissible continuous current If no data are available k is set to 1 1 times the rated current of the protected objec...

Page 457: ...utput before the tripping temperature is reached so that a trip can be avoided by early load reduction or by switching over The percentage is referred to the tripping temperature The current overload alarm setpoint I ALARM address 4205 is stated as a factor of the rated device current and should be set equal to or slightly below the permissible continuous current k IN It can also be used instead o...

Page 458: ... 6 19 4 Information Overview Addr Setting Title Setting Options Default Setting Comments 4201 Ther OVERLOAD OFF ON Alarm Only OFF Thermal overload protection 4202 K FACTOR 0 10 4 00 1 10 K Factor 4203 TIME CONSTANT 1 0 999 9 min 100 0 min Time constant 4204 Θ ALARM 50 100 90 Thermal Alarm Stage 4205 I ALARM 0 10 4 00 A 1 00 A Current Overload Alarm setpoint 4206 CALC METHOD Theta Max Average Theta...

Page 459: ...ss 236 see also Subsection 6 1 1 on the basis of the configured reactance per unit length Address 1110 or 1112 see also Subsection 6 1 3 Fault current Imax i e the maximum of 3 phase currents during clearance of the last fault primary in Ampere on the basis of the configured primary and secondary nominal current Address 205 and 206 see also Subsection 6 1 1 The operational nominal values are the n...

Page 460: ...he following For analog output 1 at mounting location B Port B1 Address 5001 20 mA B1 value in to be indicated at 20 mA or Address 5003 or 5004 20 mA B1 value in kilometres or miles that is to be indicated at 20 mA For analog output 2 at mounting location B Port B2 Address 5011 20 mA B2 value in to be indicated at 20 mA or Address 5013 or 5014 20 mA B2 value in kilometres or miles that is required...

Page 461: ...0 5 mA 19 34 mA Theoretically this corresponds to a value of 48 35 km Maximum Fault Current Set the conversion factor and the maximum output time for the maximum fault current For Analog output 1 at mounting location B Port B1 Address 5002 20 mA B1 value in Amps to be indicated at 20 mA Address 5009 Tmax OUTPUT B1 maximum output time of the value For Analog output 2 at mounting location B Port B2 ...

Page 462: ...5013 20 mA B2 1 0 1000 0 km 50 0 km 20 mA B2 correspond to 5014 20 mA B2 1 0 1000 0 Miles 50 0 Miles 20 mA B2 correspond to 5016 MIN VALUE B2 0 0 5 0 mA 4 0 mA Output value B2 valid from 5017 NEG VALUE B2 1 00 22 50 mA 19 84 mA Output value B2 for negative values 5018 OVERFLOW B2 1 00 22 50 mA 22 50 mA Output value B2 for overflow 5019 Tmax OUTPUT B2 0 10 180 00 sec 5 00 sec Maximum output time B2...

Page 463: ...A D2 correspond to 5036 MIN VALUE D2 0 0 5 0 mA 4 0 mA Output value D2 valid from 5037 NEG VALUE D2 1 00 22 50 mA 19 84 mA Output value D2 for negative values 5038 OVERFLOW D2 1 00 22 50 mA 22 50 mA Output value D2 for overflow 5039 Tmax OUTPUT D2 0 10 180 00 sec 5 00 sec Maximum output time D2 Addr Setting Title Setting Options Default Setting Comments ...

Page 464: ...ort dips in the auxiliary supply voltage do not affect the serviceability of the device refer to Sub section 10 1 2 in the technical data The processor monitors the offset and reference voltage of the ADC analogue to dig ital converter In the case of inadmissible deviations the protection is blocked per manent faults are alarmed Buffer Battery The charging state of the internal battery buffer whic...

Page 465: ...rrent proportional ratio errors of the input transducers into account which are particularly prevalent during large fault currents Figure 6 139 The reset ratio is ap prox 97 This failure is alarmed by Failure Σ I Figure 6 139 current sum monitoring Measured Value Acquisition Voltages Four measuring inputs are available in the voltage circuits three for phase earth volt ages as well as one input fo...

Page 466: ...ts of the current and voltage trans formers as well as incorrect terminations important during commissioning are large ly recognized by the device and alarmed To this end the measured values are cycli cally checked in the background as long as no fault detection is present Current Symmetry During normal system operation a certain degree of current symmetry can be as sumed This symmetry is checked ...

Page 467: ...n a certain degree of voltage symmetry can be as sumed The symmetry is monitored in the device with a magnitude comparison The smallest phase voltage is compared to the largest Non symmetry is detected when Umin Umax BAL FACTOR U as long as Umax BALANCE U LIMIT Umax is the largest and Umin is the smallest of the three voltages The symmetry factor BAL FACTOR U provides a measure of the voltage unsy...

Page 468: ...being registered at the same time this indicates the presence of a non symmetrical failure in the voltage transformer secondary circuit The unsymmetry of the voltage is detected by the fact that either the zero sequence voltage or the negative sequence voltage exceed a settable value FFM U min The current is assumed to be sufficiently symmetrical if both the zero sequence as well as the negative s...

Page 469: ...nd 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 current magnitude criterion is resorted to A three pole system voltage failure is detected in this case if all three phase earth voltages are smaller than the threshold FFM U max 3ph all three phase current amplitudes ar...

Page 470: ...ase to earth voltages are smaller than FFM U max 3ph at least one phase current is greater than PoleOpenCurrent or at least one CB pole is closed selectable no protection function has picked up this condition persists for a settable time T V Supervision default setting 3 sec This time T V Supervision is required to prevent that a voltage failure is detected be fore the protection picks up If a fai...

Page 471: ...mum voltage drops across the two binary inputs UC 2 UBImin As at least 19 V is necessary per binary input the monitoring can only be used if the trip control voltage is greater than 38 V Figure 6 144 Trip circuit supervision operating principle with two binary inputs The monitoring with two binary inputs not only detects interruptions of the trip circuit and failure of the control voltage but also...

Page 472: ... relay of the protec tion according to Figure 6 146 The circuit breaker auxiliary contact is bridged by means of a high ohmic shunt resistor R The control voltage of the circuit breaker should be at least twice the minimum voltage drop across the binary input UC 2 UBImin As at least 19 V are required for the bi nary input the supervision function can be used if the trip control voltage is greater ...

Page 473: ... time delay Figure 6 147 Logic diagram of the trip circuit supervision with one binary input 6 21 1 5 Response to Failures Depending on the nature of the detected failure an alarm is issued the processor sys tem is rebooted or the device is taken out of service Following three unsuccessful re start attempts the device is also taken out of service The device healthy relay live also resets and alarm...

Page 474: ...ocess device out of service LED flashes D OK2 resets Program memory internal EPROM reboot attempt 1 LED ERROR D OK2 resets Parameter memory internal EEPROM or RAM reboot attempt 1 LED ERROR D OK2 resets Sampling frequency internal clock reboot attempt 1 LED ERROR D OK2 resets 1 A 5 A setting jumper settings 1 A 5 A incorrect alarm protection out of service Error1A 5Awrong 192 Error A D conv 181 LE...

Page 475: ...as allocated Voltage failure single two phase Fuse failure monitor external voltage trans formers alarm distance protection blocked VT Fuse fail 10 s 169 as allocated Voltage failure three phase Extrem primary plant or connection alarm distance protection blocked Fail U meas 168 as allocated Trip circuit supervision external trip circuit or control voltage failure alarm FAIL Trip cir 6865 as alloc...

Page 476: ...ing s should be reduced In address 2901 MEASURE SUPERV the measured value monitoring can be switched ON or OFF Table 6 14 Group alarms Group alarms Composed of FNo Designation FNo Meaning 161 Fail I Superv 162 163 Fail ΣI Fail I balance 164 Fail U Superv 165 167 168 Fail ΣUphe Fail U balance Fail U absent 160 Alarm Sum Event 162 163 165 167 168 169 170 361 171 177 193 3464 183 184 185 186 187 188 ...

Page 477: ... symmetrical testing Fuse Failure Monitor Three Phase In address 2913A FFM U max 3ph the minimum voltage threshold is set If the measured voltage drops below this threshold and a simultaneous current jump which exceeds the limits according to address 2914A FFM Idelta 3p is not detected while all three phase currents are greater than the minimum current required for the impedance measurement by the...

Page 478: ...ddress 4003 Alarm Delay If 7SA6 is the only device connected in the trip circuit a delay of 1 s to 2 s is sufficient as the trip circuit supervision is not active during a detected system fault If however trip con tacts from other devices are connected in parallel in the trip circuit the fail alarm must be delayed such that the longest trip command duration can be reliably bridged 6 21 3 Settings ...

Page 479: ...ervision 0 00 30 00 sec 3 00 sec Delay Voltage Failure Supervi sion 2921 T mcb 0 30 ms 0 ms VT mcb operating time Addr Setting Title Setting Options Default Setting Comments Addr Setting Title Setting Options Default Setting Comments 4001 FCT TripSuperv ON OFF OFF TRIP Circuit Supervision is 4002 No of BI 1 2 2 Number of Binary Inputs per trip circuit 4003 Alarm Delay 1 30 sec 2 sec Delay Time for...

Page 480: ...rot ON OFF via system port 140 Error Sum Alarm Error with a summary alarm 144 Error 5V Error 5V 160 Alarm Sum Event Alarm Summary Event 177 Fail Battery Failure Battery empty 181 Error A D conv Error A D converter 182 Alarm Clock Alarm Real Time Clock 190 Error Board 0 Error Board 0 183 Error Board 1 Error Board 1 184 Error Board 2 Error Board 2 185 Error Board 3 Error Board 3 186 Error Board 4 Er...

Page 481: ... VT Fuse Failure alarm instantaneous 171 Fail Ph Seq Failure Phase Sequence 195 Fail Conductor Failure Broken Conductor 196 Fuse Fail M OFF Fuse Fail Monitor is switched OFF 197 MeasSup OFF Measurement Supervision is switched OFF F No Alarm Comments 6854 TripC1 TripRel Trip circuit superv 1 Trip Relay 6855 TripC1 Bkr Rel Trip circuit superv 1 Breaker Relay 6856 TripC2 TripRel Trip circuit superv 2...

Page 482: ...e selected to trip without time delay following manual closure as described in the corresponding sections In this regard refer also to Sub section 6 1 3 under the margin heading Cir cuit Breaker Status The manual close command must be routed to the device via a binary input In order to be independent of the duration that the switch is closed the command is set to a defined length in the device adj...

Page 483: ...is is for example of assistance for the echo function in comparison schemes with distance protection refer to Subsection 6 6 1 11 the echo function in the earth fault directional comparison pick up refer to Subsection 6 8 1 5 weak infeed tripping refer to Subsection 6 9 1 the high current instantaneous tripping 6 12 1 the plausibility check before automatic reclosure refer to Subsection 6 14 1 the...

Page 484: ...or the auxiliary contact of pole L2 CB Aux L3 FNo 353 for the auxiliary contact of pole L3 The inputs FNo 379 and FNo 380 are not used in this case If the circuit breaker can be switched individually two binary inputs are sufficient if both the series connected NO contacts and the series connected NC contacts of the aux iliary contacts of the three poles are available In this case series circuit o...

Page 485: ...t with FNo R Binary input is allocated 3 L2 L1 L3 Connection in Series NC Contacts Connection in Series NO contacts CB 3p Open CB 3p Closed CB Aux L3 CB Aux L2 CB Aux L1 L1 closed any pole open L2 closed L3 closed L1 open L2 open L3 open any pole closed FNr 351 FNr 352 FNr 353 FNr 379 FNr 380 R 351 R 351 R 352 R 352 R 353 R 353 R 379 R 379 R 380 R 380 1130 3 1131 1134 Line Closure PoleOpenVoltage ...

Page 486: ...site for a number of internal and external con sequential functions The following belong to the internal functions which are control led by the general fault detection Initiation of a fault event report trip log from the pick up to the reset of the general fault detection the fault messages are stored in the trip log Initialisation of the fault recording the storage of analogue and binary traces c...

Page 487: ...tivated or the internal automatic reclosure function is ready for reclosure after single pole tripping In all other cases tripping is always three pole The binary input 1p Trip Perm is derived from an external automatic reclose device and is equivalent to the logic inver sion of a three pole coupling signal This signal is present as long as the external reclosure is ready for single pole automatic...

Page 488: ...ading Ph i e single pole tripping of the leading phase or 1pol lagging Ph i e single pole tripping of the lagging phase The standard set ting is 3pole tripping for two phase faults presetting Table 6 15 shows a summary of the conditions under which single pole or three pole tripping results Table 6 15 Single and three pole tripping depending on the type of fault Fault type from protection function...

Page 489: ...of the circuit breaker position feedback Subsection 6 22 2 and the current flow The residual current PoleOpenCurrent that is certainly undershot when the circuit breaker pole is open is set in address 1130A Address 1135 Reset Trip CMD de termines under which conditions a trip command is reset If CurrentOpenPole is set the trip command is reset as soon as the current disappears It is important that...

Page 490: ... lock out function is not es tablished when an automatic reclosure is still expected to come In the most simple case the output alarm LOCKOUT FNo 530 can be allocated to the output which trips the circuit breaker without creating further links Then the trip ping command is sealed until the lock out is reset via the binary reset input Naturally it has to be ensured in advance that the close coil at...

Page 491: ...tion 5 1 address 133 Also when closing the breaker via the binary input Manual Close FNo 356 or via the integrated automatic reclosure the contact is interrupted so that no breaker alarm can be sent Further optional closing commands which are not sent via the device cannot be taken into consideration Closing commands for control can be linked to the alarm suppres sion via the user defined logic fu...

Page 492: ...r these messages are restricted to faults occurring on the protected feeder no trip no flag Figure 6 156 shows the logic diagram of this function Figure 6 156 Logic diagram of the trip dependent messages Switching Statistics The number of trips initiated by the device 7SA6 are counted If the device is capable of single pole tripping a separate counter for each circuit breaker pole is provided Prot...

Page 493: ...ing marshalling as stated in Sub section 5 2 3 The test is initiated via the keypad and display on the front of the device or from a PC with DIGSI 4 The procedure is described in Section 7 3 Figure 6 157 shows the se quence of a trip close test cycle The timer setting values are according to Sub section 6 1 1 for Trip Close Command Duration and Circuit Breaker Test If the auxiliary contacts of the...

Page 494: ...as well as the spontaneous mes sages that are displayed via the LCD on the front of the device following a fault are stored following each fault detection of a protection function with PICKUP or if stor age only takes place if a trip command is issued with TRIP No trip no flag feature 6 22 7 Settings Fault display TRIP CLOSE t TMin TRIP Cmd TMax CLOSE CMD T CBtest dead 0240 0242 0241 Addr Setting ...

Page 495: ...9 CB1 TEST close CB1 TEST CLOSE command 7345 CB TEST running CB TEST is in progress 7346 CB TSTstop FLT CB TEST canceled due to Power Sys Fault 7347 CB TSTstop OPEN CB TEST canceled due to CB already OPEN 7348 CB TSTstop NOTr CB TEST canceled due to CB was NOT READY 7349 CB TSTstop CLOS CB TEST canceled due to CB stayed CLOSED 7350 CB TST OK CB TEST was succesful CB1tst L1 CB1 TEST trip close Only...

Page 496: ...et locally by operation of the key LED reset on the front of the device from remote via a binary input via one of the serial interfaces automatically on detection of a new fault Condition messages should not be latched Also they cannot be reset until the crite rion to be reported has reset This applies to e g messages from monitoring functions or similar A green LED indicates that the device is in...

Page 497: ... be printed or stored for evaluation at a later time and place The protection device stores the messages of the last eight system faults in the event of a ninth fault the oldest is erased A system fault starts with the recognition of the fault by the fault detection of any pro tection function and ends with the reset of the fault detection of the last protection func tion or after the expiry of th...

Page 498: ...vertemperature If the device is provided with the synchronism and voltage check the characteristic values voltages frequencies differences can be read out If the device is provided with the earth fault detection function for non earthed sys tems the components of the earth current active and reactive component are indi cated as well Table 6 17 Operational measured values Measured values primary se...

Page 499: ... overtemperature Uline Usync Udiff line voltage busbar voltage and voltage magnitude difference for synchro check kV fline fsync fdiff line voltage busbar voltage and frequency difference for synchro nism check Hz ϕdiff magnitude of the phase angle dif ference between line and busbar for sychronism check IEEa IEEr active and reactive component of earth fault current A mA Table 6 17 Operational mea...

Page 500: ...g Use to detect about operating conditions If a preset limit value set point is exceeded an alarm is generated This alarm can also be allocated to output relays and LEDs In contrast to the actual protection functions the monitoring function operates in the back ground therefore it may not pick up if measured values are changed spontaneously in the event of a fault and if protection functions are p...

Page 501: ... new system fault thereby not requiring an acknowledgment In addition to storage of the fault recording by the protection fault detection a recording may also be initiated via binary input the integrated keypad and display or via the serial PC or service in terface The data can be retrieved via the serial interfaces by means of a personal computer and evaluated with the protection data processing ...

Page 502: ...our On The Hour or if it is to be synchronized with a different point in time 15 After Hour 30 After Hour or 45 After Hour If the settings for averaging are changed then the measured values stored in the buffer are deleted and new results for the average calculation are only available after the set time period has passed Set Points The settings are entered under Measurement Measurement in the sub ...

Page 503: ...0 The pre and post fault times are additive If the time for the binary input is set to the duration of the storage is as long as the binary input is initiated static the maximum length however still is MAX LENGTH address 410 6 23 5 Settings Addresses which have an A attached to its end can only be changed with DIGSI 4 in Additional Settings Average Calculation Min Max Values Addr Setting Title Set...

Page 504: ...igger 412 POST REC TIME 0 05 0 50 sec 0 10 sec Captured Waveform after Event 415 BinIn CAPT TIME 0 10 5 00 sec 0 50 sec Capture Time via Binary Input F No Alarm Comments 963 IL1dmd I L1 demand 964 IL2dmd I L2 demand 965 IL3dmd I L3 demand 833 I1dmd I1 positive sequence Demand 834 Pdmd Active Power Demand 1052 Pdmd Forw Active Power Demand Forward 1053 Pdmd Rev Active Power Demand Reverse 835 Qdmd ...

Page 505: ...nimum 840 IL2d Max I L2 Demand Maximum 841 IL3d Min I L3 Demand Minimum 842 IL3d Max I L3 Demand Maximum 843 I1dmdMin I1 positive sequence Demand Minimum 844 I1dmdMax I1 positive sequence Demand Maximum 845 PdMin Active Power Demand Minimum 846 PdMax Active Power Demand Maximum 847 QdMin Reactive Power Demand Minimum 848 QdMax Reactive Power Demand Maximum 849 SdMin Apparent Power Demand Minimum 8...

Page 506: ...wer Minimum Reverse 1043 Pmax Rev Active Power Maximum Reverse 1044 Qmin Forw Reactive Power Minimum Forward 1045 Qmax Forw Reactive Power Maximum Forward 1046 Qmin Rev Reactive Power Minimum Reverse 1047 Qmax Rev Reactive Power Maximum Reverse 880 SMin Apparent Power Minimum 881 SMax Apparent Power Maximum 882 fMin Frequency Minimum 883 fMax Frequency Maximum 1048 PFminForw Power Factor Minimum F...

Page 507: ...se L2 dmd 275 SP IL3 dmd Set Point Phase L3 dmd 276 SP I1dmd Set Point positive sequence I1dmd 277 SP Pdmd Set Point Pdmd 278 SP Qdmd Set Point Qdmd 279 SP Sdmd Set Point Sdmd PF Lower setting limit for Power Factor 285 cosϕ alarm Power factor alarm F No Alarm Comments F No Alarm Comments 4 Trig Wave Cap Trigger Waveform Capture 203 Wave deleted Waveform data deleted FltRecSta Fault Recording Star...

Page 508: ...ction 5 3 6 24 1 Types of commands Two types of commands can be issued with this device Control commands Internal pseudo commands Control Commands These commands operate binary outputs and change the power system status Commands for the operation of circuit breakers asynchronous the synchro check can be implemented via CFC by applying the synchronism check and closing con trol function as well as ...

Page 509: ...selected for each command Switching authority local remote Switching direction control target state present state Zone controlled bay interlocking logic using CFC System interlocking centrally via SICAM Double operation interlocking against parallel switching operation Protection blocking blocking of switching operations by protective functions Fixed commands Timeout monitoring time between comman...

Page 510: ...arked with a parameter in the routing matrix For all commands the user can select the operation mode with interlocking normal mode or without interlocking test mode for local commands by reprogramming the settings with password check for automatic commands via command processing with CFC mittels Entriegelung skennungen for local remote commands using an additional interlocking disable command via ...

Page 511: ...and tags that were set with a tagging command Other internal commands such as manual entry or abort are not checked i e carried out independent of the interlocking Figure 6 158 Example of a message when closing the circuit breaker Q0 Standard Interlocking The standard interlocking includes the checks for each device which were set during the configuration of inputs and outputs see Section 5 2 4 un...

Page 512: ...Sw Auth REMOTEy n LOCAL DIGSI AUTO Switching Authority Switching Mode Switching Mode 52 Close 52 Open feedback Indication On Off Switching Authority Switching Mode Event Condition Starting With Version 4 2 of Command SCHEDULED ACT y n 1 Source REMOTE also includes SAS LOCAL Command via substation controller REMOTE Command via telecontrol system to substation controller and from substation con trol...

Page 513: ...ent of commands to Local Remote Digsi The messages which relate to commands with the origin Command Issued Local Remote DIGSI must be send independent of the routing configuration on the serial digital interface to the initiating point The acknowledgement of commands is therefore not executed by a response indica tion as it is done with the local command but by ordinary command and feedback in for...

Page 514: ...mand was as expected in other words positive The minus is a neg ative confirmation and means that the command was not fulfilled as expected Command Output and Switching Relays The command types needed for tripping and closing of the switchgear or for raising and lowering of transformer taps are described in Section 5 2 and Subsection 5 2 1 n ...

Page 515: ...ailed knowledge about the device functions is not required at this point However the configuration of the device covered in Chapter 5 especially configuration of the input and output functions is assumed to have already taken place Please note that the examples shown are general and may differ in wording or details from the device at hand Also depending on the model variant some of the functions d...

Page 516: ...in the LCD on the front of the device Display on the screen of a PC running the DIGSI 4 program connected to the op erating or service interface of the device Transfer to a master station using one of the serial system interfaces if available Light Emitting Diodes The green light emitting diode with the label RUN lights continuously during normal operation The red LED with the label ERROR indicate...

Page 517: ...this menu the messages can be reached by entering the associated selection number or by selecting the desired entry using the and keys and moving further with the key This procedure is described in more detail below Figure 7 1 Selection of messages on the operator control panel example PC Interfaces A personal computer running the DIGSI 4 program can be connected to the operat ing interface on the...

Page 518: ...nformation Trip Log these are fault messages from the last eight network faults that were proc essed by the device Sensitive Earth Fault Log Earth fault messages if the device has sensitive earth fault detection For networks with non earthed star point or star point earthed by a Peterson coil Switching statistics these values include a counter for the trip commands initiated by the device accumula...

Page 519: ...only issued as ON to indicate an event or as ON and OFF to designate the beginning and end of a condition From the DeviceFront With the device ready for operation first press the key The MAIN MENU appears The first menu item Annunciation is marked Press the key to enter the ANNUNCIATION menu see Figure 7 1 Here select the menu item Event Log already marked The EVENT LOG table ap pears If no messag...

Page 520: ...equence shown in Figure 7 6 Figure 7 6 Display of spontaneous messages in the device display example The spontaneous messages can be acknowledged by pressing the key After ac knowledgment the default display is shown Protection function that picked up e g distance protection with phase information Protection function that is tripped e g 3pole distance protection only devices with graphic display E...

Page 521: ...ermediate infeed Retrieved messages The messages for the last eight network faults can be retrieved The definition of a net work fault is such that the time period from fault detection up to final clearing of the system fault is considered to be one network fault If auto reclosure occurs then the network fault ends after the last reclosing shot which means after a successful or final unsuccessful ...

Page 522: ... to move back into the TRIP LOG level or press the key to go back to the MAIN MENU From PC with DIGSI 4 Click on Annunciation The options appear in the data window see Figure 7 2 Double click on the desired message group in the data window in this case the Trip Log A list appears in the data window as shown in Figure 7 8 By double clicking on an entry in the list view the associated contents of th...

Page 523: ...ce ready for operation first press the key The MAIN MENU appears The first menu item Annunciation is marked Press the key to enter the ANNUNCIATION sub menu see Figure 7 1 Using the key select the sub menu item Earth Fault Messages and move to the earth fault logs using the key The EARTH FAULT MESSAGES selection ap pears In this sub menu the indications for the last 3 network faults can be selecte...

Page 524: ...up in the data window in this case the EARTH FAULT MESSAGES A list of the earth fault logs appears in the data window as shown in Figure 7 11 By double clicking on an entry in the list view the associated contents of the network fault is displayed in another window The entries are chronologically listed with the newest message appearing first Figure 7 11 DIGSI 4 Selection of Earth Fault Log with a...

Page 525: ...nfirming with the key the safety question Are you sure ap pears The response YES is the default Figure 7 13 Confirm with the key if the message group should really be erased If the message group should not be erased press the key so that the response NO is highlighted and confirm this an swer with the key Before confirming with the key the responses can be tog gled between YES and NO using the and...

Page 526: ...ur PC as every file 7 1 1 6 General Interrogation From PC with DIGSI 4 The present condition of a SIPROTEC device can examined by using DIGSI 4 to view the contents of the General Interrogation annunciation The messages are found by double clicking on Annunciation see Figure 7 2 double clicking on General Interrogation and double clicking on the date and time that appear in the right window All of...

Page 527: ...itiated by a protective element of the device the magnitude of interrupted current for each circuit breaker pole is determined and stored The cur rent magnitudes are added to previously interrupted currents and the accumulated values are stored In devices with automatic reclosure the number of reclosure commands is counted i e separately according to single pole if available and three pole automat...

Page 528: ...r a password is entered the cur sor blinks and the number value is highlighted in a box The number can be overwritten using the number keys If the new value is outside of the allowable range either above or below then the maximum or minimum limit value appears at the bottom edge of the screen Confirm the change with the key Figure 7 17 Setting statistics values from the device front example From P...

Page 529: ... Secondary values are values measured at the device terminals or values calculated from the latter values 7 1 3 1 Measured Values Read out of Measured Values In the 7SA6 with maximum functionality the measured values as shown in Table 7 1 are available The displacement voltage 3U0 is either measured directly 3U0 3 Uen if Uen is con nected to the voltage input U4 or calculated from 3U0 UL1 E UL2 E ...

Page 530: ...V V rated operational voltage 3 2 4 UX voltage at the measuring input U4 kV V rated operational voltage 3 2 U1 U2 pos and neg seq voltages kV V rated operational voltage 3 2 RL1 E RL2 E RL3 E RL1 L2 RL1 L2 RL3 L1 operational resistance of all phase loops Ω Ω XL1 E XL2 E XL3 E XL1 L2 XL2 L3 XL3 L1 operational reactance of all phase loops Ω Ω S P Q apparent real and reactive power MVA MW MVAR 3 UN I...

Page 531: ... IL2d IL3d I1d average values of the phase currents and the positive sequence current UL1 E UL2 E UL3 E U1 phase earth voltages and positive sequence voltage UL1 L2 UL2 L3 UL3 L1 3U0 phase phase voltages and zero sequence voltage PForw PRev QForw QRev S active and reactive power separately according to Demand Forward and Demand Reverse as well as apparent power Pd Qd Sd average values of active re...

Page 532: ... secondary 13 Impedance Sec Operational impedance secondary 21 Percent Operational measured values in percent of operational nominal quantities 31 Demand Long term average values in primary values 32 Min Max Demand Minimum and maximum average values with date and time indication of moment of occurrence in primary values 33 U I Min Max Minimum and maximum values of voltages and currents with date a...

Page 533: ... and down in the table of measured value groups using the and keys Use the key to return to the MEASUREMENT sub menu Use the key to return to the MAIN MENU From PC with DIGSI 4 The measured value groups are found under Measurement Figure 7 2 with a double click as shown in Figure 7 21 left Figure 7 21 Measurement window in DIGSI 4 example The measured values are categorized into the following grou...

Page 534: ...o 5 2 and or with the user definable logic CFC according to Section 5 3 If a measured value is not available then instead of the measured value 3 dots ap pear If the value is undefined e g cos ϕ when no current is flowing then ap pears 3 horizontal bars If the measured value overruns then 3 asterisks are viewed Double click on the desired measured value group e g Primary The next sub group is disp...

Page 535: ...ement groups Select Other with another double click In the next level double click on Energy By double clicking on an item in the list in the right part of the window another window is opened viewing the corresponding content of the counter group 7 1 3 3 Setting Set Points SIPROTEC 7SA6 enables the user to set limit points or set points for some impor tant measured and metered values If one of the...

Page 536: ...nd confirmation with the current value appears in a frame with a flashing cursor The current value must be overwritten with the desired new value using the numeric keys If the permissible range for the setting value is exceeded to the top or the bottom the maximum or minimum set point value appears at the bottom of the display when the value is entered Press the key The new value now appears in th...

Page 537: ...n the list in the right part of the window the set points are loaded Mark the number of the value which is to be changed With a right mouse click open the context menu and click on Set as shown in Figure 7 24 A password inquiry password No 5 for individual settings occurs Next the dialog field Set Me tered Value is opened Enter the desired value in the entry field Then click on OK The entered valu...

Page 538: ... No 5 for individual parameters appears After en try of the password and confirmation with the query Are you sure with the default answer Yes appears Figure 7 25 Confirm with the key if the corre sponding measured values should really be reset A message in the display will then show the answer Change ok If you do not want to reset the measured values press the key so that the answer No is marked a...

Page 539: ...ame time To reset values back to zero first click onto the required group energy or minimum maximum values in the MEASUREMENT submenu Open the context menu with a right mouse click and select Reset After having entered the password N 5 changing parameters the reset process is initiated Note When selecting Reset all values are reset to zero This procedure cannot be un done ...

Page 540: ...ic records The records are identified with a network fault number a fault record number and the date and time By double clicking on an fault record in the list view in the right side of the window one of the above programs is opened and the selected waveform data are loaded See also DIGSI 4 Operating Handbook order no E50417 H1176 C097 Subsection 8 3 3 Figure 7 26 Retrieval of fault records in DIG...

Page 541: ...ing voltage value Figure 7 27 SIGRA 4 Diagrams in the four possible views example During configuration any signal can be selected in its properties to be displayed in the fault record See chapter 5 2 3 Further details about the many possibilities that SIGRA 4 offers can be found in the SIGRA handbook Order No E50417 H1176 C070 7 1 4 2 Saving the Fault Records Storage of Fault Recording Data Oscill...

Page 542: ...rce the internal clock should be set was al ready determined in Section 5 7 Date and Time Stamping Once the device is not supplied with power the internal time clock RTC continues working by taking its pow er from the integrated buffer battery Right after the running up of the device it displays a plausible time The time then is changed automatically by the synchronization source linked to the dev...

Page 543: ...evice power up if synchronization is lost that is if the cyclical synchronization is interrupted for a time longer than the set tolerance time Error Time Corrective action If an external synchronizing source is being used check the source and the connection Item 3 is displayed if the RTC had a valid value upon device start up but the time was neither manually set nor synchronized since Corrective ...

Page 544: ...in the IRIG B mode Without healthy or external time synchronisation the free running date and time can also be relatively adjusted 23 59 59 using the entry field Diff time This input possibility is not to be confused with the parameter Offset see Section 5 7 which affects the specific general offset to the received synchronization time of the radio clock receiver e g local time vs GMT time Setting...

Page 545: ...e front panel From PC with DIGSI 4 To manually change the date and time of the device Click on Device in the menu bar as shown in Figure 7 30 Select the command Set Clock Figure 7 30 Selecting the command Set Clock in DIGSI 4 A dialog field Set clock date in device is opened The displayed values are the present date and time The day of the week is automatically derived from the date and cannot be ...

Page 546: ... C156 2 Figure 7 31 Dialog Field Set clock date in device If the time offset or tolerance time is to be changed when the clock alarm failed dou ble click onto Settings Figure 7 32 to select the function Figure 7 32 Dialog Field Settings in DIGSI 4 example ...

Page 547: ...uble click onto Time Synchronization and the window Time Synchronization Time Format appears There the user can change the alarm delay Fault indication after and the time offset in the field Offset to time sig nal Figure 7 33 Dialogue Field Time Synchronization Time Format ...

Page 548: ...device is ready for operation first press the key The MAIN MENU ap pears Using the key select the menu item Settings and switch to the settings with the key The selection SETTINGS appears Using the key select the item Change Group and move to the selection of groups with the key The sub menu CHANGE GROUP appears as shown in Figure 7 34 The first Address 301 is marked The address displays the setti...

Page 549: ...ection window in DIGSI 4 example Double click on Settings to find Change Group in the data window Figure 7 35 right CHANGE GROUP 01 02 0301 ACTIVE GROUP Group A The currently active setting group is dis played under Address 301 The setting group can be changed under Ad dress 302 by pressing the key after en tering the password two possible alternatives are displayed in a new window each time Using...

Page 550: ...est Operation Depending on the type of protocol all messages and measured values transferred to the central control system can be identified with an added message test operation bit while the device is being tested onsite test mode This identification prevents the messages from being incorrectly interpreted as resulting from an actual power system disturbance or event As another option all message...

Page 551: ...y If the mode is changed the footer shows the message Control Ex ecuted for a short time Use the key to return to the TEST DIAGNOSE level press the key to return to the MAIN MENU The procedure for changing the Block Data Transmission mode is the same See Fig ure 7 38 simplified Figure 7 38 Applying a Block of Data Transmission from the Front Panel simplified The settings for the test mode and the ...

Page 552: ...local device generating the corresponding transmission signals The signals are transmitted to the opposite line end with the added message Test Mode The signals received at the opposite line end are mirrored i e they are sent back phase segregated from the opposite line end as own signals marked with Test Mode The local device receives these mirrored test signals and adds them to its own teleprote...

Page 553: ...ing this mode Every mode can be determined seper ately Press the key Answer the question Are you sure with Yes confirm with If the feeder is still current carrying or if the circuit breaker is signalled to be closed by the auxiliary contacts the device will refuse tag setting for this mode and will show a corresponding message on the display When the mode has been confirmed testing and revision wo...

Page 554: ...window Doubleclick Taggings A dialogue box Tagging is opened Figure 7 42 Figure 7 42 Tagging dialogue box In the Designation column the different modes have been listed Actual refers to the current state with OFF meaning that the mode is not effective ON meaning that it is effective By clicking one of buttons under Setpoint you can change the desired mode In a se curity query you will be requested...

Page 555: ... Having entered the password confirm with the OK button If the feeder is still current carrying or if the circuit breaker has been signalled closed by the auxiliary contacts the device refuses tag setting for this mode and displays a corresponding message on the monitor When the mode has been confirmed testing and revision works can be done as de scribed above As the mode set has been saved as tag...

Page 556: ... device has picked up and that the circuit breaker is ready The device indicates the status of the test sequence with corresponding messages in the display or on the monitor of a PC If the device refuses to run or terminates the test sequence it is likely that one of the preconditions for the execution of the test cycle has not been satisfied The reason for the refusal or termination is also shown...

Page 557: ...ault response Yes Figure 7 44 This must be confirmed by pressing the key if the circuit breaker is definitely closed If circuit breaker auxiliary contacts are connected and marshalled the device rejects the test cycle when the auxiliary contacts indicate that the circuit breaker is not closed CB TEST running Circuit breaker test in progress CB TSTstop FLT Circuit breaker test cannot be started as ...

Page 558: ...ogue window is opened in which the desired test sequence can be marked for selection Following a double click a prompt for the entry of password No 4 for test and diag nosis appears After entry of the password and confirmation with Ok the test sequence is executed In the spontaneous event window the execution of the test is displayed with the cor responding control responses and messages ENTER ENT...

Page 559: ...Control During Operation 7 45 7SA6 Manual C53000 G1176 C156 2 Figure 7 45 Circuit breaker trip test in DIGSI 4 ...

Page 560: ...g device indicates an invalid position in the 7SA6 All subsequent control operations to the equipment are inter locked Control from a 7SA6 to a power system equipment can originate from four sources Local operation using the operator control panel Operation with a PC via the operating interface and DIGSI 4 Binary inputs Remote operation using the system interface Switching priority for the four co...

Page 561: ...If the process has not been confirmed within one minute or if it was interrupted the blinking activitiy still indicating the required position goes back to the corresponding actual status Under normal conditions the control display shows the new actual status after a tripped switching command At the lower screen end the message End of Com mand appears For switching commands with feedback the messa...

Page 562: ...splayed first Use the and keys to move to the desired switch Figure 7 48 Control of Switching Devices from the Operator Control Panel example Select the switch to be controlled using the and keys and press the key Enter Password No 1 for interlocked switching and acknowledge with the key Note if the switching mode is NON INTERLOCKED Test Sub section 7 4 7 all switching operations are only possible...

Page 563: ... in the display Refer to Sub section 7 4 4 The key can be used to return to BREAKER SWITCH Press the key to return to the MAIN MENU From PC with DIGSI 4 When the Online window in DIGSI 4 is opened with a double click the operating functions for the device appear in the left part of the window Clicking on Control dis plays the associated function selection in the data window See Figure 7 50 Figure ...

Page 564: ...imulated Normally operating devices are switched in the interlocked Normal mode The configured interlocking conditions are checked before a control command is car ried out As soon as a control command is entered in the Scheduled column Pass word No 1 for interlocked switching is requested for safety reasons Further control possibilities remain possible until the control dialog field is closed or t...

Page 565: ...osition indication for a switching device With a 7SA6 ready for operation first press the key The MAIN MENU appears Using the key select the menu item Control and go to the control functions with the key The selection CONTROL appears By pressing the key the BREAKER SWITCH sub menu is entered see Figure 7 52 Select the item Man Overwrite using the key and move to the next selection using the key MA...

Page 566: ...This type of separation is also necessary for instance if a switch position feedback message is not functioning properly refer to Sub section 7 4 2 The menu item SET STATUS is used to perform the decoupling The menu displays a list of all planned switching devices and associated status infor mation identified by a letter The letters have the following meanings T Device is tagged manually overwritt...

Page 567: ...ch means the message input was de coupled from the system The output block is active O so the command output is also de coupled from the system For the disconnect switch and the ground switch no limita tions are set Select the desired change option using the and keys and confirm with the key A safety inquiry appears Are you sure If the response is YES and provided the return routing is allowed the...

Page 568: ... the key The selection INTERLOCK appears See Figure 7 55 Figure 7 55 Example of Interlocking Conditions for Switching Equipment Front Panel From PC with DIGSI 4 Interlocking is set for each switching device during project planning see Sub section 5 2 4 using the matrix and the dialog box Object Properties Readout of the actively set interlocking is always possible across the entire path without a ...

Page 569: ...ENU appears Using the key select the menu item Control and move to editing the control func tions with the key The selection CONTROL appears Select the item Tagging with the key and switch to the next selection using the key The selection TAGGING appears See Figure 7 56 The status of the tagging is displayed Tagging Display or changed using Tagging Set Figure 7 56 Tagging Equipment from the HMI ME...

Page 570: ...ure 7 57 Setting Switching Authority with the Operator Control Panel Pressing the key opens a selection window in which the options LOCAL REMOTE are offered Choose the desired option using the and keys and confirm with the key Acknowledge the subsequent message pressing the key Use the key to return to the SWITCH AUTH level the key to return to the MAIN MENU From PC with DIGSI 4 For safety reasons...

Page 571: ...enu item Switch Mode with the key and switch to the next se lection using the key The selection SWITCH MODE appears see Figure 7 58 Figure 7 58 Operating Menu for Switching Mode Using Front Panel Pressing the key opens a selection window in which the options INTERLOCKED NON INTERLOCKED are offered Make the choice using the and keys and confirm with the key Acknowledge the safety inquiry that follo...

Page 572: ...mmand denial These messages and the associ ated causes are listed in Table 7 6 together with other messages for the control of de vice functions Table 7 6 Possible Control Messages Message Text Message Cause System Error Interruption by system error Man Overwrite OK Return routing carried out Man Overwrite Fail Return routing cannot be carried out Control Abort OK Command interruption carried out ...

Page 573: ...issing BinaryInp Ignored Recording block set Chatter Active Flutter block is active Setting active Refusal because parameter loading process is running Status Change OK Status command executed Status Change Fail Status command cannot be executed Change OK Marking executed Change Failed Marking cannot be executed Checking Interlock Command is sent to the central unit to check system interlocking Se...

Page 574: ...Control During Operation 7 60 7SA6 Manual C53000 G1176 C156 2 lease processing of functions in the CFC This command processing is determined during project planning and configuration of the matrix n ...

Page 575: ...on of the power system Installation of the 7SA6 is described in this chapter Hardware modifications that might be needed in certain cases are explained Connection verifications required before the device is put in service are also given Commissioning tests are provided Some of the tests require the protected object line transformer etc to carry load 8 1 Mounting and Connections 8 2 8 2 Checking th...

Page 576: ...t one M4 screw for the device ground The cross sectional area of the ground wire must be greater than or equal to the cross sectional area of any other control conductor connected to the device Furthermore the cross section of the ground wire must be at least 2 5 mm2 G Connect the plug terminals and or the screwed terminals on the rear side of the de vice according to the wiring diagram for the pa...

Page 577: ...phic display housing width 1 2 as an example SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA610 RUN ERROR MENU ESC LED ENTER F4 F1 F2 F3 Annunciation Meas Val MAIN MENU 01 05 Annunciation Measurement Elongated 1 2 Trip log Holes SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA631 RUN ERROR MENU ESC LED CTRL ENTER F4 F1 F2 F3 Annunciation Meas Val Remote Normal Local Test Schlossplatz 21 kV 1000 A Elongated Trip ...

Page 578: ... lo cated centrally at the top and bottom also have to be removed The 4 respectively 6 slots in the mounting flange are revealed and can be accessed G Fasten the device to the mounting brackets with four or six screws G Replace the four or six covers G Tighten the mounting brackets to the rack using eight screws G Connect the ground on the rear plate of the device to the protective ground of the r...

Page 579: ...SA610 with a four line display in a rack or cubicle housing width 1 3 of 19 inch rack as an example SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA610 RUN ERROR MENU ESC LED ENTER F4 F1 F2 F3 Annunciation Meas Val MAIN MENU 01 04 Annunciation 1 Measurement 2 Trip log Mounting bracket Mounting bracket ...

Page 580: ...1 with graphic display in a rack or cubicle housing width 1 2 of 19 inch rack as an example SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7SA631 RUN ERROR MENU ESC LED CTRL ENTER F4 F1 F2 F3 Annunciation Meas Val Remote Normal Local Test Schlossplatz 21 kV 1000 A Trip log Mounting bracket Mounting bracket ...

Page 581: ...ews For dimensions refer to Figure 10 11 to 10 13 in Section 10 22 G Connect the ground of the device to the protective ground of the panel The cross sectional area of the ground wire must be greater than or equal to the cross sec tional area of any other control conductor connected to the device Furthermore the cross section of the ground wire must be at least 2 5 mm2 G Connect solid low impedanc...

Page 582: ...tion chamber in such a way that the screw thread fits in the hole of the lug Section 2 3 has pertinent information regarding wire size lugs bending radii etc G For mounting the detached operator panel please observe the following G The removal of the 4 covers located at the corners of the front cover reveal 4 elon gated holes in the mounting bracket G Insert the operator panel into the panel cut o...

Page 583: ...s regarding the factor 221 I4 Iph CT may again be found in Subsection 6 1 1 Voltages The Figures A 40 to A 47 show examples of the voltage transformer connection op tions For the normal connection as shown in Figure A 40 the 4th voltage measuring input U4 is not used Correspondingly the address 210 must be set to U4 transformer Not connected The factor in address 211 Uph Udelta must however be set...

Page 584: ...e dedicated to the purpose of changing setting groups when four groups are to be switched One binary input must be set for Set Group Bit 0 the other input for Set Group Bit 1 If either of these input functions is not assigned then it is considered as not controlled To control two setting groups one binary input set for Set Group Bit 0 is sufficient since the binary input Set Group Bit 1 which is n...

Page 585: ...so allow the detection of a trip circuit failure when the circuit break er auxiliary contact 1 Aux1 is open and the command relay contact has reset The value of this resistor must be such that in the circuit breaker open condition therefore Aux1 is open and Aux2 is closed the circuit breaker trip coil TC is no longer picked up and binary input BI1 is still picked up if the command relay contact is...

Page 586: ...stant current with BI on 1 7 mA UBI min Minimum control voltage for BI 19 V for delivery setting for nominal voltage of 24 48 60 V 73 V for delivery setting for nominal voltage of 110 125 220 250 V UCTR Control voltage for trip circuit RCBTC DC resistance of circuit breaker trip coil UCBTC LOW Maximum voltage on the circuit breaker trip coil that does not lead to tripping IBI HIGH 1 8 mA from SIPR...

Page 587: ...Installation and Commissioning 8 13 7SA6 Manual C53000 G1176 C156 2 The closest standard value of 39 kΩ is selected the power is PR 110 V 39 kΩ 0 5 kΩ è ø æ ö 2 39 kΩ PR 0 3 W ...

Page 588: ...able connections between stations must always be checked on their effect on high voltage The pilot wires of the pilot cables must stand external strains The worst electrical fault that may occur to the connected pilot cables is generated in the pilot wire system by an earth fault The short circuit current induces a longitudinal voltage into the pilot wires lying parallel to the high voltage line T...

Page 589: ...panel surface mounting via a plug in jumper X40 The assignment of the plug in jumper to the type of contact and the location of the jumper is described in Subsubsection 8 1 3 3 see Processor Board C CPU 2 Nominal Currents The input transformers of the device are set to a nominal current of 1 A or 5 A with jumpers The position of the jumpers are set according to the name plate sticker The assignmen...

Page 590: ...ion of the jumpers on the printed circuit board of the central proc essor unit C CPU 2 is described in Subsubsection 8 1 3 3 see Processor Board C CPU 2 and the position of the jumpers on the interface modules in Subsubsection 8 1 3 4 Both jumpers must always be plugged in the same way As delivered from the factory the resistors are switched out 8 1 3 2 Disassembly of the Device If changes on jump...

Page 591: ...f the plug connector Carefully draw out the plug connector This action does not apply to the device version with detached operator panel How ever on the central processor unit C CPU 2 the 7 pole plug connector X16 behind the D subminiture connector and the plug connector of the ribbon cable connected to the 68pole plug connector on the rear side must be removed o Disconnect the ribbon cables betwe...

Page 592: ...e 1 3 after removal of the front cover simplified and scaled down Slot 5 Slot 19 7SA610 A E J BI1 to BI5 7SA610 B F K BI6 and BI7 BI1 to BI5 1 3 4 Input output printed circuit board C I O 2 Input output printed circuit board C I O 11 Processor printed circuit board C CPU 2 Binary inputs BI 1 3 4 1 Binary inputs BI ...

Page 593: ...d down 1 2 3 Slot 5 Slot 19 Slot 33 Binary inputs BI BI6 to Input output printed circuit board C I O 1 Input output printed circuit board C I O 2 Processor printed circuit board C CPU 2 1 2 3 BI13 4 Input output printed circuit board C I O 11 5 Input output printed circuit board B I O 2 7SA6 1 A E J BI1 to BI5 Binary inputs BI BI8 to 1 5 4 BI20 7SA6 1 B F K BI1 to BI5 BI6 and BI7 ...

Page 594: ...ut p c b C I O 1 Input output p c b C I O 2 Processor p c b C CPU 2 Slot 5 Slot 33 Binary Inputs BI BI6 to 1 3 Slot 19 Slot 33 BI14 to Slot 19 BI22 to 2 2 BI29 BI13 BI21 4 Input output p c b C I O 11 5 Input output p c b B I O 2 BI14 to 1 2 3 BI21 7SA6 2 B F K BI1 to BI5 BI21 to 1 5 4 BI33 7SA6 2 C G L BI1 to BI5 BI6 and BI7 7SA6 2 A E J BI1 to BI5 BI6 to BI13 2 2 BI8 to BI20 5 Binary Inputs BI Bi...

Page 595: ...8 2 the quiescent state of the life contact according to Table 8 3 and the selected op erating voltage of the binary inputs BI1 to BI5 according to Table 8 4 and the integrat ed interface RS232 RS485 according to Table 8 5 to 8 7 Figure 8 12 Processor printed circuit board C CPU 2 with jumper settings required for the module configuration F1 X21 2 1 X51 3 1 2 X53 3 1 2 X52 1 2 3 4 X40 3 1 2 1 2 X5...

Page 596: ...r Nominal Voltage 24 to 48 VDC 60 to 125 VDC 110 to 250 VDC 115 VAC X51 none 1 2 2 3 X52 none 1 2 and 3 4 2 3 X53 none 1 2 2 3 X55 none none 1 2 Table 8 3 Jumper setting for the quiescent state of the life contact on the processor printed circuit board C CPU 2 Jumper Open in the quiescent state Closed in the quiescent state Presetting X40 1 2 2 3 2 3 Table 8 4 Jumper settings of the control voltag...

Page 597: ... on 25 pole Note For a direct connection to DIGSI 4 with interface RS232 jumper X111 must be plugged in position 2 3 If there are no external matching resistors in the system the last devices on a RS485 bus must be configured via jumpers X103 and X104 Note Both jumpers must always be plugged in the same way Currently no function is assigned to the jumper X90 The presetting is 1 2 The terminating r...

Page 598: ...Installation and Commissioning 8 24 7SA6 Manual C53000 G1176 C156 2 Figure 8 13 Termination of the RS 485 interface external 390 Ω 220 Ω 390 Ω 5 V A A B B ...

Page 599: ...ard for the input output boards C I O 1 and C I O 10 is illustrated in Figure 8 14 and Figure 8 15 Figure 8 14 The input output board C I O 1 with the jumpers necessary for the control of settings H L M X22 X21 H L M X24 X23 H L M X26 X25 H L M X28 X27 H L M X30 X29 H L M X32 X31 H L M X34 X33 H L M X36 X35 X40 3 1 2 X71 AD0 H L X72 AD1 X73 AD2 ...

Page 600: ... goes for binary output BO9 Figure 8 10 slot 19 With version 7SA6 2 A E J housing size 1 1 with 24 binary outputs this goes for binary output BO9 and BO17 Figure 8 11 slot 33 left und slot 19 right With version 7SA6 2 B F K housing size 1 1 with 32 binary outputs this goes for binary output BO9 BO17 and BO25 Figure 8 11 slot 33 left slot 19 right und slot 19 left With version 7SA6 2 M P R housing ...

Page 601: ...ed circuit board for Jumper Open in quiescent state NO Closed in quiescent state NC Presetting A E J slot 19 BO9 X40 1 2 2 3 1 2 Table 8 9 Jumper settings for the contact mode of outputs BO9 BO17 and BO25 on the input output board C I O 1 housing size 1 1 Device version 7SA6 2 printed circuit board for Jumper Open in quiescent state NO Closed in quiescent state NC Presetting A E J slot 33 left BO9...

Page 602: ...to BI29 on the binary in put output boards C I O 1 or C I O 10 for housing size 1 1 Binary Inputs Jumper Threshold 17 V 1 Threshold 73 V 2 Threshold 154 V 3 Slot 33 left Slot 19 right Slot 19 left BI6 BI14 BI22 X21 X22 L M H BI7 BI15 BI23 X23 X24 L M H BI8 BI16 BI24 X25 X26 L M H BI9 BI17 BI25 X27 X28 L M H BI10 BI18 BI26 X29 X30 L M H BI11 BI19 BI27 X31 X32 L M H BI12 BI20 BI28 X33 X34 L M H BI13...

Page 603: ...ssary for the setting check The contact of the relay for the binary output BO6 can be configured as NO or NC con tact see also General Diagrams in Appendix A Section A 2 Mounting location for housing size 1 3 in Figure 8 9 slot 19 for housing size 1 2 in Figure 8 10 slot 33 for housing size 1 1 in Figure 8 11 slot 33 right X61 1A 5A 3 2 1 T8 T6 T7 T5 X64 1A 5A 3 2 1 X63 5A 1A 1 2 3 X62 5A 1A 1 2 3...

Page 604: ...ensitive earth current input in put transformer T8 The jumpers X71 X72 and X73 on the input output board C I O 2 are for setting the bus address and must not be changed Table 8 15 lists the jumper presettings Mounting location for housing size 1 3 in Figure 8 9 slot 19 for housing size 1 2 in Figure 8 10 slot 33 for housing size 1 1 in Figure 8 11 slot 33 right Jumper Quiescent state open NO conta...

Page 605: ...d for the input output board C I O 11 is illustrated in Figure 8 17 Figure 8 17 The input output board C I O 11 with the jumpers necessary for the control of settings T8 T10 T11 T9 X60 AD2 L X62 1A 5A 1 2 3 X63 1A 5A 1 2 3 X61 1A 5A 1 2 3 X64 1A 5A 1 2 3 X65 IEE IE X73 1 2 3 AD1 X72 1 2 3 AD0 X71 H 1A 5A 1 2 3 X21 1 X22 1 L M H L M H ...

Page 606: ...ormer X61 to X64 and one common jumper X60 However there is no jumper X64 for the version with sensitive earth current input in put transformer T8 For normal earth current inputs the jumper X65 is plugged in position IE and for sen sitive earth current inputs in position IEE The jumpers X71 X72 and X73 on the input output board C I O 11 are for setting the bus address and must not be changed Table...

Page 607: ...re 8 18 The input output board B I O 2 with the jumpers necessary for the setting check Check for control voltages of binary inputs BI8 to BI20 for housing size 1 2 according to Table 8 18 BI8 to BI33 for housing size 1 1 according to Table 8 19 1 2 3 X21 1 2 3 X23 1 2 3 X25 1 2 3 X27 3 2 1 X22 3 2 1 X24 3 2 1 X26 3 2 1 X28 3 2 1 X29 3 2 1 X30 3 2 1 X31 3 2 1 X32 3 2 1 X33 X73 1 2 3 X72 1 2 3 X71 ...

Page 608: ...mper Threshold 17 V1 Threshold 73 V2 Slot 19 BI8 X21 1 2 2 3 BI9 X22 1 2 2 3 BI10 X23 1 2 2 3 BI11 X24 1 2 2 3 BI12 X25 1 2 2 3 BI13 X26 1 2 2 3 BI14 X27 1 2 2 3 BI15 X28 1 2 2 3 BI16 X29 1 2 2 3 BI17 X30 1 2 2 3 BI18 X31 1 2 2 3 BI19 X32 1 2 2 3 BI20 X33 1 2 2 3 Table 8 19 Jumper setting of control voltages of the binary inputs BI8 and BI33 on the binary input output boards B I O 2 for version 7S...

Page 609: ...ing locations are shown in Figures 8 9 to 8 11 Table 8 20 Jumper setting of printed circuit board addresses of the binary input output boards B I O 2 for housing size 1 2 Jumper Mounting location Slot 19 X71 1 2 X72 2 3 X73 1 2 Tabelle 8 21 Jumper setting of printed circuit board addresses of the binary input output boards B I O 2 for housing size 1 1 Jumper Mounting location Slot 19 right Slot 33...

Page 610: ...2 with interface modules Please note the following G Only interface modules of devices with panel flush mounting and cubicle mounting as well as of mounting devices with detached operator panel can be exchanged In terface modules of devices in surface mounting housings with double level termi nals must be exchanged in our manufacturing centre G Use only interface modules that can be ordered in our...

Page 611: ...rding to RS232 standard DIN 66020 is not available Modem signals are not required since communi cation to SIPROTEC devices is always carried out in the half duplex mode Use connetion cable with ordering number 7XV5100 4 Jumper setting 1 2 this setting makes the modem signal available i e for a direct RS232 connection between the SIPROTEC device and the modem this setting can Table 8 22 Exchangeabl...

Page 612: ...re located on the corresponding interface module that is mounted to the processor input output board C CPU 2 Figure 8 19 shows the print ed circuit board of the C CPU 2 and the order the modules are mounted The module for interface RS485 is illustrated in Figure 8 21 the module for Profibus in Figure 8 22 For the configuration of the terminating resistors both jumpers have to be plugged in the sam...

Page 613: ...bus interface module must be disconnected Figure 8 23 Termination of interface RS485 external Analog Output Module The analog output module AN20 is provided with 2 isolated channels with a current range from 0 to 20 mA unipolar maximum 350 Ω The mounting location on the processor circuit board C CPU 2 is B and or D de pendent on the version see Figure 8 19 Figure 8 24 Interface module with the ana...

Page 614: ...cable between the processor module C CPU 2 and the front cover into the socket of the front cover For the version with detached operator panel the latter is to be ignored Instead the plug connector of the ribbon cable connected to a 68pole plug connector on the rear side of the device must be plugged into the plug connector of the processor circuit board C CPU 2 The 7 pole plug connector X16 conne...

Page 615: ...rection The data output of one device must be connected to the data input of the other device and vice versa The data cable connections are designated in sympathy with DIN 66020 and ISO 2110 see also Table 8 24 TxD data transmit RxD data receive RTS request to send CTS clear to send DGND signal chassis ground The cable shield is to be grounded at both ends so that potential differences cannot caus...

Page 616: ... do not Analog Outputs Both analog values are directed as current via a 9 pole D subminiature female con nector The outputs are isolated Time Synchronization Interface 5 VDC 12 VDC or 24 VDC time synchronization signals can be processed optionally if the connections are realized as indicated in Table 8 26 assigned but not available Table 8 25 Pin assignments for the D subminiature female connector...

Page 617: ...rence The fibres guar antee electrical isolation between the connections Transmit and receive connections are identified with the symbols for transmit and for receive The character idle state for the optical fibre interface is Light off If this setting is to be changed use the operating program DIGSI 4 as described in Section 5 6 Warning Laser injection Do not look directly into the fibre optic el...

Page 618: ...and receiving connections are identified with the symbols for transmit and for receive The visual check of the assignment of the transmission and receive channels is relevant If using more than one device the connections of all protection data interfaces are checked according to the topology selected Communication converter Optical fibres are usually used for the connections between the devices an...

Page 619: ...ay be installed for the purposes of sec ondary testing and isolation of the device Of particular importance are test switches in current transformer circuits Be sure these switches short circuit the current trans formers when they are in the test mode open o The short circuit feature of the current circuits of the device are to be checked An ohmmeter or other test equipment for checking continuity...

Page 620: ...t movement of the ammeter merely indicates the charging current of capacitors o Remove the voltage from the power supply by opening the protective switches o Disconnect the measuring equipment restore the normal power supply connections o Apply voltage to the power supply o Close the protective switches for the voltage transformers o Verify that the voltage phase rotation at the device terminals i...

Page 621: ... screw of the device must be connected solidly to the protective earth conductor before any other electrical connection is made Hazardous voltages can be present on all circuits and components connected to the supply voltage or to the measuring and test quantities Hazardous voltages can be present in the device even after disconnection of the supply voltage storage capacitors Wait for at least 10 ...

Page 622: ...nal function if messages are transmitted correctly Do not apply this test function in the real operating mode of the device The system interface test is carried out Online using DIGSI 4 G Double click on the Online directory to open the required dialogue box G Click on Test and the functional options appear on the right side of the window G Double click on Generate indications shown in the list vi...

Page 623: ...med Test in Message Direction For all information that is transmitted to the central station the following is tested in Status Scheduled G Make sure that each checking process is carried out carefully without causing any danger see above and refer to DANGER G Click on Send and check whether the transmitted information reaches the central station and shows the desired reaction Test in Command Direc...

Page 624: ...ne using DIGSI 4 in the online operating mode G Open the Online directory by double clicking the operating functions for the de vice appear G Click on Test the function selection appears in the right half of the screen G Double click in the list view on Hardware Test The dialogue box of the same name opens see Figure 8 26 Figure 8 26 Dialogue box for hardware test example Structure of the Test Dia...

Page 625: ...om the internal device func tions and can only be operated by the hardware test function This implies that a switching signal to an output relay from e g a protection function or control command cannot be executed G Ensured that the switching of the output relay can be executed without danger see above under DANGER G Each output relay must be tested via the corresponding Scheduled cell in the di a...

Page 626: ...hange the condition is successfully performed for all hardware components if the Update button is clicked for all hardware components with cyclical updating if the Automatic Update 20sec field is marked Exiting the Procedure To end the hardware test click on Close The dialog box closes The device becomes unavailable for a brief start up period immediately after this Then all hardware com ponents a...

Page 627: ...e device are linked or if two devices have been double linked with a ring topology first check only one link o Both devices at the link ends have to be switched on o Check in the Event Log see also Subsubsection 7 1 1 2 or spontaneous annuncia tions see Subsubsection 7 1 1 7 for the following G If the message PI1 with protection data interface connected with FNo 3243 is provided with the device in...

Page 628: ...ve the communication converter into test position jumper X32 in position 2 3 G Close the communication converter housing o Reconnect the auxiliary supply voltage for the communication converter o The system interface X 21 or G 703 1 must be active and connected to the commu nication converter Check this by means of the device ready contact of the commu nication converter continuity at the NO conta...

Page 629: ...es Note the above DANGER instruction o Reset the the communication converter to normal position X32 in position 1 2 and close the housing again o Reconnect the supply voltage of the communication converter Perform the above check at the other end with the device being connected there and its corresponding communication converter Continue with Consistency of Topology and Parameterization Consistenc...

Page 630: ... the integration of this protection function in the system must be tested under practical conditions Due to the variety of application options and the available system configurations it is not possible to make a detailed description of the necessary tests It is important to consider the local conditions and the protection and plant drawings It is advised to isolate the circuit breaker of the teste...

Page 631: ...segregated starting possible G single pole starting by trip command of the external protection in phase L1 binary input functions BF Start L1 and possibly BF release in sponta neous or fault messages Trip command depending on configuration G single pole starting by trip command of the external protection in phase L2 binary input functions BF Start L2 and possibly BF release in sponta neous or faul...

Page 632: ...breakers must be checked Here it should be checked for every busbar section that all circuit breakers which are connected to the same busbar section as the feeder circuit breaker under observation are tripped and no other breakers Tripping of the Remote End If the trip command of the circuit breaker failure protection must also trip the circuit breaker at the remote end of the feeder under observa...

Page 633: ... measurements must then be repeated Phase Rotation The phase rotation must correspond to the configured phase rotation in general a clockwise phase rotation If the system has an anti clockwise phase rotation this must have been considered when the power system data was set address 0235 PHASE SEQ refer to Sub section 6 1 1 If the phase rotation is incorrect the alarm 171 Fail Ph Seq FNo 171 is gene...

Page 634: ... of load flow is checked In this case the normal situation is assumed whereby the forward direction measuring direction extends from the busbar towards the line Figure 8 30 P positive if active power flows into the line P negative if active power flows towards the busbar Q positive if reactive power flows into the line Q negative if reactive power flows toward the busbar Figure 8 30 Complex appare...

Page 635: ...put U4 is used for measuring a voltage for overvoltage protection Power System Data 1 address 210 U4 transformer Ux transformer no polarity check is necessary because the polarity is irrelevant here The voltage magnitude was checked according to Subsection 8 3 7 If the input U4 is used for measuring the displacement voltage Uen power system data 1 address 210 U4 transformer Udelta transf the polar...

Page 636: ...therefore measure the same voltage G The program SYNC CHECK Yes address 3515A is set G A request for synchro check measurement is initiated via binary input FNo 2906 Sync Start The synchro check must give close release message Sync release FNo 2951 Figure 8 31 Measuring voltages for synchro check G If not first check whether one of the aforenamed messages 2947 Sync Udiff or 2949 Sync ϕ diff is ava...

Page 637: ...r the test this must also be re stored 8 3 10 Earth Fault Check in a Non earthed System The earth fault check is only necessary if the device is connected to an isolated or res onant grounded system and the earth fault detection is applied The device must therefore be provided with the earth fault detection function according to its ordering code position 16 in ordering code 2 or 3 or 6 or 7 Furth...

Page 638: ...he current measuring input I4 is connected in the star point of the set of current transformers refer also to the con nection circuit diagram in the Appendix Figure A 14 then the correct polarity of the earth current path in general will result automatically If however the current I4 is derived from a separate summation CT e g a core balance CT or from a different point of measurement e g transfor...

Page 639: ...ation must be checked in the fault messages refer also to Sub section 7 1 1 3 the messages EF Pickup and EF forward must at least be present If the directional pick up is not present either the earth current connection or the displacement voltage connection is incorrect If the wrong direction is indicated either the direction of load flow is from the line toward the busbar or the earth current pat...

Page 640: ...sformer sec ondary circuits the connections must be checked and rectified Subsequently the measurement must be repeated Figure 8 33 Polarity check of I4 example with earth current of a parallel line I4 Measured in a Power Transformer Star Point If I4 is the earth current measured in the star point of a power transformer and intended for the earth fault protection direction determination for earthe...

Page 641: ...also to Sub section 7 1 1 3 at least the following alarms must be present EF Pickup and EF forward If the directional pick up alarm is missing a connection error of the earth current connection I4 is present If the wrong direction is indicated the earth current connection I4 has a swapped polarity The connection must be rectified after the test source has been switched off The measurement must the...

Page 642: ...ter clos ing the poles of the circuit breaker the voltage 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 from several 3 to 5 successful switching attempts Set the calculated time under add...

Page 643: ... 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 zone but within the overreach zone Z1B The ...

Page 644: ...imple check of the transmission paths from one line end is possible using the echo function The echo function must be activated at both line ends i e address 2501 FCT Weak Infeed ECHO only with the set ting ECHO and TRIP a trip may result at the line end opposite to the test location A short circuit is simulated outside Z1 with the Permissive Overreach or UN BLOCKING inside Z1B with the Directiona...

Page 645: ...f the simulated fault at the transmitting end the receiving end remains blocked for the additional duration of the transmit prolongation time of the transmitting end Send Prolong address 2103 The transient blocking time of the receiving end TrBlk BlockTime address 2110 will additionally appear if a finite waiting time TrBlk Wait Time address 2109 was set and if this time had been exceeded In case ...

Page 646: ... protection according to Subsection 8 3 13 1 then this Subsection 8 3 13 2 is also of no consequence and may be omitted For the functional check of the earth fault protection signal transmission the distance protection should be disabled to avoid interference of the tests by signals from the dis tance protection address 1201 FCT Distance OFF Directional Com parison Schemes Prerequisites Teleprotec...

Page 647: ...overcurr Teleprot E F in address 132 Section 5 1 is set to a comparison scheme with a blocking sig nal i e Blocking furthermore the setting in address 3201 must be FCT Telep E F ON Naturally the corresponding send and receive signals must also be assigned to the corresponding binary output and input For more information about the blocking scheme see Subsubsection 6 8 1 3 In the case of the blockin...

Page 648: ...d and the response of the circuit breaker at the opposite line end is verified In the case of the distance protection the permissive underreach scheme may be used to trip the remote line end The procedure is then the same as was the case for permissive underreach Sub section 8 3 13 1 under Permissive Underreach Trans fer however the received signal causes a direct trip For the remote transmission ...

Page 649: ... Subsection 8 3 3 all configured switching devices must be switched on and off from the device via the integrated control element The feedback information of the circuit breaker position injected via binary inputs is read out at the device and compared with the actual breaker position For devices with graphic dis play this is easy to do with the control display The switching procedure is described...

Page 650: ...essed by the device as a normal fault recording with the exception that data are not given in the fault messages trip log The exter nally triggered record has a number for establishing a sequence Triggering with DIGSI 4 To trigger oscillographic recording with DIGSI 4 click on Test in the left part of the window Double click the entry Test Wave Form in the list in the right part of the win dow to ...

Page 651: ... the buffers press MAIN MENU An nunciation Set Reset Refer to Subsection 7 1 1 if further assistance is need ed The numbers in the switching statistics should be reset to the values that were ex isting prior to the testing or to values in accordance with the user s practices Set the statistics by pressing MAIN MENU Annunciation Statistic Refer to Sub section 7 1 2 if more information is needed Pre...

Page 652: ...Installation and Commissioning 8 78 7SA6 Manual C53000 G1176 C156 2 ...

Page 653: ... this chapter A procedure for replacing compo nents such as the buffer battery is discussed Troubleshooting advice is provided A procedure for replacing the power supply fuse is described Some comments concern ing the return of a device to the factory are given 9 1 General 9 2 9 2 Routine Checks 9 3 9 3 Maintenance 9 4 9 4 Troubleshooting 9 9 9 5 Corrective Action Repairs 9 12 9 6 Return 9 16 ...

Page 654: ...when a hardware failure is detected The live status relay drops out to provide an alarm by its breaking contact If a prob lem is detected in the external measuring circuits the device normally only provides messages Recognized software failures result in the resetting and restarting of the processor system If such a failure is not resolved by the restart further restart attempts are ini tiated If ...

Page 655: ...on 7 1 1 2 for help in reading the messages o Perform a reset reboot of the device A complete check of the hardware is done The device is effectively out of service during the reset which lasts for about 10 to 15 sec onds To perform the reset from the operator control panel press the key and use the and keys to select the Device Reset under the TEST DIAGNOSE sub menu Press the key enter Password N...

Page 656: ...fault records These are the data under the Annunciation sub menu all items in this sub menu The records and data are lost when the battery is removed The simplest and fastest method is to use the save feature in DIGSI 4 when the program is on line Note All of the protective and control settings including the input output configuration and the CFC logic are not affected by a power supply interrupti...

Page 657: ... set aside the front panel o The battery is located on the bottom front side of the CPU Ê board See Figure 9 1 Figure 9 1 Front view without front panel position of buffer battery simplified and re duced o Remove the old battery from the snap on connector using the plastic battery grip shown in Figure 9 1 o Remove the battery grip from the old battery and place the grip on the new battery o Observ...

Page 658: ... front cover of the operator panel enables the user to fix the battery properly To replace the battery o Read out the device annunciations Usually this is done with a PC via the operator in terface using DIGSI 4 The records and data are lost when the battery is removed Therefore the information in the PC is saved Note All protective and control settings including the input output configuration and...

Page 659: ...ed If the internal system clock is not automatically synchronized via a serial interface then the clock should be set at this point Refer to Subsection 7 2 1 if assistance is needed to set the clock G2 Battery Caution Electrostatic discharges through the connections of the components wiring and con nectors must be avoided Wearing a grounded wrist strap is preferred otherwise touch a grounded metal...

Page 660: ...156 2 Warning The used battery contains Lithium Do not throw the battery into the trash It must be disposed off in line with the applicable regulations Do not reverse the polarity Do not completely discharge Do not throw the bat tery into a fire Explosion hazard ...

Page 661: ...n A 2 of Appendix A o Has the fuse in the power supply not blown The location of the fuse is shown in Fig ure 9 7 If the fuse needs to be replaced see Subsection 9 5 2 If the red ERROR LED is on and the green RUN LED is off then the device has recognized an internal fault Re initializing the device can be attempted see Section 9 2 If you see the following display the device has arrived monitor mod...

Page 662: ... MLFB of the device the serial number of the device BF the firmware version the parameter set version This information is found in the device file of DIGSI 4 as shown in Figure 9 6 Go to the Main Menu and select Parameters Setup Extras MLFB Ver sion The odering number and serial number The ordering number and the serial number can also be read from the name plate on the top of the device Furthermo...

Page 663: ...Routine Checks and Maintenance 9 11 7SA6 Manual C53000 G1176 C156 2 Figure 9 6 Retrieving the device data in the device properties ...

Page 664: ...t insert or extract a printed circuit board unless the device is completely isolated Soldering work must not be done on the printed circuit boards Disassembling the Device The device must be disassembled if work is to be done on the printed circuit boards The procedure below should be used o Prepare area of work Provide a grounded mat for protecting components subject to damage from electrostatic ...

Page 665: ...be detached o Disconnect the ribbon cable between the CPU board and the I O board o The boards can be removed and laid on the grounded mat to protect them from ESD damage A greater effort is required to remove the CPU board from the device designed for sur face mounting because of the type of connectors Replacing the Power Supply Fuse The power supply fuse is located on the CPU board o Keep ready ...

Page 666: ...tor pins Do not use force Make sure the connectors latch For the device versions with detached operator panel this activity can be skipped Connect the ribbon cable from the 68 pin connector at the back of the device to the plug connector of the CPU board The 7pin connector X16 must be plugged behind the D subminiature port The direction in which it is plugged is not relevant since the connection i...

Page 667: ...tor make sure that its lug is plugged properly into the slot of the socket and it does not come out when tightening the knurled nut The knurled nut must not be tightened too strong o Close the protective switches to apply voltage to the power supply If the green RUN LED does not light there is a fault in the power supply The device should be sent to the factory See Section 9 6 Warning Laser inject...

Page 668: ... applicable should be returned to the factory The original transport packaging material should be used for returning a device If al ternative packaging material is used then the device and other contents must be pro vided with protection against shock and vibration according to IEC 60255 21 1 Class 2 and IEC 60255 21 2 Class 1 Before returning a device retrieve and save all of the configuration fu...

Page 669: ...10 6 Earth Fault Protection Teleprotection Schemes optional 10 27 10 7 Weak Infeed Tripping 10 28 10 8 Protection Data Interface and Distance Protection Topology optional 10 29 10 9 External Direct and Remote Tripping 10 30 10 10 Overcurrent Protection 10 30 10 11 High Current Switch On To Fault Protection 10 33 10 12 Earth Fault Detection in a Non Earthed System 10 33 10 13 Automatic Reclosure Fu...

Page 670: ...A for 1 s 100 A for 10 s 15 A continuous dynamic pulse 750 A half cycle Voltage Inputs Nominal voltage UN 80 V to 125 V adjustable Power consumption per phase at 100 V 0 1 VA Overload capability per phase thermal rms 230 V continuous Analog Output for Measured Values and Fault Location Range 0 to 24 mA Connection for flush mounting housing rear panel mounting location B or and D 9 pin D subminitur...

Page 671: ...ed AC DC converter Power consumption quiescient approx 7 VA energized with 7SA610 A E J approx 14 VA with 7SA610 B F K approx 12 VA with 7SA6 1 A E J M N P approx 17 VA with 7SA6 1 B F K approx 17 VA with 7SA6 2 A E J M P R approx 20 VA with 7SA613 A M approx 20 VA with 7SA6 2 B K F N Q S approx 23 VA with 7SA6 2 C G L approx 21 VA plus approx 1 5 VA per interface module Bridging time for failure ...

Page 672: ...g thresholds adjustable with jumpers for nominal voltages 24 48 VDC Upick up 19 VDC 60 110 125 VDC Udrop off 14 VDC for nominal voltages 110 125 Upick up 88 VDC 220 250 VDC Udrop off 66 VDC for nominal voltages 220 250 VDC Upick up 176 VDC Udrop off 117 VDC Current consumption energized approx 1 8 mA independent of the control voltage Maximum permissible voltage 300 VDC Impulse filter on input 220...

Page 673: ... 1 NO Contact high speed 1 Power Relay 2 7SA610 A E J x 7 1 7SA610 B F K x 5 7SA6 1 A E J x 7 7 2 7SA6 1 B F K x 8 4 7SA6 1 M N P x 7 3 1 5 7SA6 2 A E J x 14 7 3 7SA6 2 B F K x 21 7 4 7SA6 2 M P R x 14 3 2 5 7SA6 2 N Q S x 21 3 3 5 7SA6 2 C G L x 11 8 7SA613 A 14 7 3 7SA613 M 14 3 2 5 Switching capability MAKE BREAK 1000 W VA 30 VA 40 W ohmic 25 W VA for L R 50 ms 1000 W VA 1000 W VA Switching vol...

Page 674: ...r Operation with DIGSI 4 Transmission speed min 4800 Baud max 115200 Baud factory setting 38400 Baud parity 8E1 Maximum transmission distance 15 m 50 ft Rear Service Modem Interface optional RS232 RS485 Optical isolated interface for data transfer acc ordered version Operation with DIGSI 4 RS232 Connection for flush mounted case rear panel mounting location C 9 pin DSUB socket for surface mounted ...

Page 675: ... interface for data transfer Profibus RS485 Profibus Optical to a master terminal acc to ordered version RS232 Connection for flush mounted case rear panel mounting location B 9 pin DSUB socket for surface mounted case at the inclined housing on the case bottom 9 pin DSUB socket Test voltage 500 V 50 Hz Transmission speed min 4800 Bd max 38400 Bd factory setting 19200 Bd Maximum transmission dista...

Page 676: ...unting location B for surface mounted case please use the relay with Profibus RS485 interface and separate fibre optic converter Transmission speed to 1 5 MBd recommended 500 kBd Optical wavelength λ 820 nm Laser class 1 acc 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 using glass fibre 62 5 125 µm Maximum transmission di...

Page 677: ...IEC 60255 6 and 22 Product standards EN 50082 2 Generic standard DIN 57435 Part 303 High frequency test 2 5 kV Peak 1 MHz τ 15 µs IEC 60255 22 1 class III 400 surges per s test duration 2 s and VDE 0435 part 303 class III Ri 200 Ω Electrostatic discharge 8 kV contact discharge IEC 60255 22 2 class IV 15 kV air discharge both polarities and IEC 61000 4 2 class IV 150 pF Ri 330 Ω Irradiation with HF...

Page 678: ...decaying wave 50 surges per s duration 2 s Ri 150 Ω to 200 Ω Fast transient surge withstand cap 4 kV to 5 kV 10 150 ns 50 surges per s ability ANSI IEEE C37 90 1 both polarities duration 2 s Ri 80 Ω Radiated electromagnetic interference 35 V m 25 MHz to 1000 MHz ANSI IEEE Std C37 90 2 amplitude and pulse modulated Damped oscillations 2 5 kV peak value polarity alternating IEC 60694 IEC 61000 4 12 ...

Page 679: ...68 3 3 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 rate1 octave min 1 cycle in 3 orthogonal axes Vibration and Shock During Transport Standards IEC 60255 21 and IEC 60068 Vibration sinusoidal IEC 60255 21 1 class 2 5 Hz to 8 Hz 7 5 mm amplitude IEC 60068 2 6 8 Hz to 150 Hz ...

Page 680: ...y cause conden sation to occur 10 1 8 Service Conditions The device is designed for use in an industrial environment or an electrical utility en vironment for installation in standard relay rooms and compartments so that proper installation and electromagnetic compatibility EMC is ensured In addition the follow ing are recommended All contactors and relays that operate in the same cubicle cabinet ...

Page 681: ...size 1 3 9 5 kg 20 9 pounds size 1 2 11 kg 24 2 pounds size 1 1 19 kg 41 9 pounds 7SA63 in flush mounting housing size 1 2 6 kg 13 2 pounds size 1 1 10 kg 22 0 pounds in surface mounting housing size 1 2 11 kg 24 2 pounds size 1 1 19 kg 41 9 pounds UL listing UL recognition 7SA6 0 A Models with threaded terminals 7SA6 J Models with plug in terminals 7SA6 1 A 7SA6 K 7SA6 2 A 7SA6 L 7SA6 B 7SA641 P ...

Page 682: ... 1 2 8 kg 17 6 pounds size 1 1 12 kg 26 4 pounds detached operator panel 2 5 kg Degree of protection acc IEC 60529 for the device in surface mounted case IP 51 in flush mounted case and with version with detached operator panel front IP 51 rear IP 50 for human safety IP 2x with closed protection cover ...

Page 683: ... blocking of leading phase earth and phase phase release of all associated loops release of only phase to earth loops release of only phase to phase loop For double earth fault in isolated or resonant grounded 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 Fault Detection Earth current 3I0 0 05 A to...

Page 684: ...ation the corresponding direction Drop off to pick up ratio approx 1 05 Secondary values based on IN 1 A for IN 5 A they must be multiplied with 5 Distance Measurement Characteristic polygonal 5 independent and 1 controlled zone Setting ranges polygon IPh min current phases 0 10 A to 4 00 A1 steps 0 01 A X reactance reach 0 05 Ω to 250 00 Ω 2 steps 0 001 Ω R resistance tolerance phase phase0 05 Ω ...

Page 685: ...ms 60 Hz with fast relays approx 12 ms 50 Hz 10 ms 60 Hz with high speed relays Drop off time approx 30 ms Stage timers 0 00 s to 30 00 s steps 0 01 s for all zones separate time setting possibilities for single phase and multi phase faults for the zones Z1 Z2 and Z1B Time expiry tolerances 1 of set value or 10 ms The set times are pure delay times Emergency Operation In case of measured voltage f...

Page 686: ...opposite line end Underreach Schemes Method Permissive Underreach Transfer Trip PUTT with overreaching zone Z1B PUTT Pickup Direct transfer trip Send signal prolongation 0 00 s to 30 00 s steps 0 00 s Underreach Schemes via Protection Data Interface optional Method Permissive Underreach Transfer Trip PUTT with overreaching zone Z1B Send signal prolongation 0 00 s to 30 00 steps 0 01 s Overreach sc...

Page 687: ...s The set times are pure delay times 10 5 Earth Fault Protection in Earthed Systems optional Characteristics Definite time stages definite 3I0 3I0 3I0 Inverse time stage IDMT 3I0P one of the characteristics according to Figure 10 1 to 10 12 can be selected Voltage dependent stage U0 inverse characteristic according to 10 8 Very High Set Stage Pickup value 3I0 0 50 A to 25 00 A1 steps 0 01 A T3I0 0...

Page 688: ...5 00 A 1 steps 0 01 A or 0 003 A to 25 000 A 1 steps 0 001 A Time factor T3I0P 0 05 s to 3 00 s steps 0 01 s or ineffective Additional time delay T3I0Pverz 0 00 s to 30 00 s steps 0 01 s or ineffective Characteristics see Figure 10 1 Tolerances current pickup at 1 05 I 3I0P 1 15 times 5 15 ms for 2 I 3I0P 20 and T3I0P s 1 1 Secondary values based on IN 1 A for IN 5 A the current values must be mul...

Page 689: ...0 s to 32 00 s steps 0 01 s Trev 0 00 s to 32 00 s steps 0 01 s characteristics see Figure 10 5 Tolerances times 1 of set value or 10 ms Drop off to pick up 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 1 Secondary values based on IN 1 A for IN 5 A the current values must be multiplied by 5 Inrush Stabilization Second harmonic content for...

Page 690: ...ge 3U2 0 5 V to 10 0 V steps 0 1 V Forward angle capacitive Alpha 0 to 360 steps 1 inductive Beta 0 to 360 steps 1 Tolerances pick up values 10 of set value or 5 of nominal current or 0 5 V Forward angle 5 Re orientation time after direction change approx 30 ms 1 Secondary values based on IN 1 A for IN 5 A they must be multiplied by 5 ...

Page 691: ...0 20 100 20 10 5 2 0 5 0 2 0 05 s s 1 2 3 5 10 20 0 3 0 1 100 20 10 2 0 05 5 s 0 2 0 5 1 t s 3 3 30 30 3 t 0 14 I Ip 0 02 1 Tp Type A t 13 5 I I p 1 1 Tp t 80 I I p 2 1 T p 0 8 0 1 0 2 0 4 1 6 3 2 0 05 0 8 7 Tp 0 1 0 2 0 4 1 6 3 2 0 8 Tp 0 05 t Trip time Tp Setting value time multiplier I Fault current Ip Setting value current Note For earth fault read 3I0p in stead of Ip and T3I0p instead of Tp 0...

Page 692: ...10 0 5 0 2 0 05 t 8 9341 I I p 2 0938 1 0 17966 è ø ç æ ö D t 0 2663 I I p 1 2969 1 0 03393 è ø ç æ ö D 1 0 3 0 1 1 2 3 5 10 20 100 20 10 5 2 0 5 0 2 0 05 INVERSE SHORT INVERSE D s t s t s I Ip I Ip 1 2 5 10 15 0 5 D s 1 2 5 10 15 0 5 1 0 3 0 1 1 2 3 5 10 20 100 20 10 5 2 0 5 0 2 0 05 t 0 0103 I I p 0 02 1 0 0228 è ø ç æ ö D s s s 1 2 3 5 10 20 0 3 0 1 100 20 10 2 0 05 5 3 5 s t 5 6143 I I p 1 2 1...

Page 693: ...MELY INVERSE D s t s t s I Ip I Ip 1 2 5 10 15 0 5 D s 1 2 5 10 15 0 5 1 0 3 0 1 1 2 3 5 10 20 100 20 10 5 2 0 5 0 2 0 05 s 1 2 3 5 10 20 0 3 0 1 100 20 10 2 0 05 5 s 0 2 0 5 1 t s 3 t 3 922 I I p 2 1 0 0982 è ø ç æ ö D t 5 64 I I p 2 1 0 02434 è ø ç æ ö D t 0 4797 I I p 1 5625 1 0 21359 è ø ç æ ö D 30 3 3 s 30 30 t Trip time D Setting value time multiplier I Fault current Ip Setting value current...

Page 694: ...rse characteristic Figure 10 5 Trip time characteristics of the zero sequence voltage protection U0inv 1 2 3 4 5 6 7 10 20 30 40 0 2 4 6 8 I 3I0P t s T 3I0Pmax T 3I0Pmin 3I0P FACTOR T 3I0P 1 00 1 35 1 70 8 t T3I0Pmax T3I0P ln I 3I0P 0 20 40 60 80 100 120 140 0 1 0 2 0 3 0 4 0 5 0 7 1 2 3 4 5 10 t s 3U0 V 1 V 2 V 3 V 4 V 5 V U0 inverse with U0min parameter U0inv minimum Adr 3183 t 2 s 0 25 U0 V U0m...

Page 695: ...blocking time 0 00 s to 30 00 s steps 0 01 s Waiting time for transient blocking 0 00 s to 30 00 s steps 0 01 s Echo delay time 0 00 s to 30 00 s steps 0 01 s Echo impulse duration 0 00 s to30 00 s steps 0 01 s Time expiry tolerances 1 of set value or 10 ms The set times are pure delay times Overreach schemes via protection data interface optional Methods Directional comparison pickup scheme Send ...

Page 696: ...eception of a carrier signal from the remote end Undervoltage Detection Setting value UPhE 2 V to 70 V steps1 V Drop off to pick up ratio approx 1 05 Pick up tolerances 5 of set value or 0 5 V Times Release delay 0 00 s to 30 00 s steps 0 01 s Release prolongation 0 00 s to 30 00 s steps 0 01 s Time expiry tolerances 1 of set value or 10 ms ...

Page 697: ...ssion distance Connection via communication networks Communication converter see Appendix A Subsection Accessories Supported network interfaces G703 1 with 64 kbits s X21 with 64 or 128 or 512 kbit s Connection to communication converter see table above under module FO5 Transmission speed 64 kbit s with G703 1 512 kbit s or 128 kBit s or 64 kbit s with X21 Max transmission time 0 1 ms to 30 ms ste...

Page 698: ...rcuit Back up overcurrent protection operates independent on any events Characteristics Definite time stages definite IPh 3I0 IPh 3I0 Inverse time stage IDMT IP 3I0P one of the characteristics according to Figure 10 1 to 10 3 see Section 10 5 can be selected High Set Stages Pickup values IPh phases 0 10 A to 25 00 A1 steps 0 01 A or ineffective 3I0 earth 0 05 A to 25 00 A1 steps 0 01 A or ineffect...

Page 699: ... phases 0 10 A to 4 00 A1 steps 0 01 A or ineffective 3I0P earth 0 05 A to 4 00 A1 steps 0 01 A or ineffective Time factors TIP phases 0 05 s to 3 00 s steps 0 01 s or ineffective T3I0P earth 0 05 s to 3 00 s steps 0 01 s or ineffective Additional time delays TIPadd phases 0 00 s to 30 00 s steps 0 01 s T3I0Padd earth 0 00 s to 30 00 s steps 0 01 s Characteristics see Figure 10 1 in Section 10 5 T...

Page 700: ...0 ms The set times are pure delay times with definite time protection 1 Secondary values based on IN 1 A for IN 5 A they must be multiplied by 5 Stub Protection Pick up values IPhSTUB phases 0 10 A to 25 00 A1 steps 0 01 A or ineffective 3I0STUB earth 0 05 A to 25 00 A1 steps 0 01 A Time delays TIPhSTUB 0 00 s to 30 00 s steps 0 01 s or ineffective T3I0STUB 0 00 s to 30 00 s steps 0 01 s or ineffe...

Page 701: ...Sens E F TRIP 0 00 s to 320 00 s steps 0 01 s Measuring tolerance 5 of set value Time tolerance 1 of set value or 10 ms Pick up time min 32 ms Drop off time 26 ms The set times are pure delay times Phase Determination Measuring principle voltage measurement phase earth Earth fault phase Uph min 10 V to 100 V steps 1 V Healthy phases Uph max 10 V to 100 V steps 1 V Messtoleranz 5 of set value Direc...

Page 702: ...g time after dynamic blocking 0 5 s Blocking time after manual closing 0 50 s to 300 00 s 0 steps 0 01 s Start signal monitoring time 0 01 s to 300 00 s steps 0 01 s Circuit breaker supervision time 0 01 s to 300 00 s steps 0 01 s Adaptive Dead Time ADT Reduced Dead Time RDT Dead Line Check Operating modes ADT with voltage measurement or with close command transmission Action time 0 01 s to 300 00...

Page 703: ...60 V phase to phase steps 1 V U for live line live bus check 20 V to 125 V phase to phase steps 1 V Tolerances 2 of pick up value or 2 V Drop off to pick up ratios approx 0 9 U or 1 1 U U Measurement Voltage difference 1 V to 40 V phase to phase steps 0 1 V Tolerance 1 V Synchronous System Conditions ϕ measurement 2 to 60 steps 1 Tolerance 2 f measurement 0 03 Hz to 2 00 Hz steps 0 01 Hz Tolerance...

Page 704: ...e Sequence System U1 Overvoltage U1 2 0 V to 220 0 V steps 0 1 V Time delay TU1 0 00 s to 30 00 s steps 0 01 s Overvoltage U1 2 0 V to 220 0 V steps 0 1 V Time delay TU1 0 00 s to 30 00 s steps 0 01 s Drop off to pick up ratio 0 50 to 0 98 steps 0 01 Pick up time approx 30 ms Drop off time approx 30 ms Tolerances voltages 3 of set value or 1 V times 1 of set value or 10 ms Overvoltage Negative Seq...

Page 705: ...ervoltage UPhPh 1 0 V to 175 0 V steps 0 1 V Time delay TUPhPh 0 00 s to 30 00 s steps 0 01 s Undervoltage UPhPh 1 0 V to 175 0 V steps 0 1 V Time delay TUPhPh 0 00 s to 30 00 s steps 0 01 s Drop off to pick up ratio approx 1 05 Current criterion can be switched on off Pick up time approx 30 ms Drop off time approx 30 ms Tolerances voltages 3 of set value or 1 V times 1 of set value or 10 ms Under...

Page 706: ...ult distance in km miles and requires homogeneous lines 2 Secondary values based on IN 1 A for IN 5 A the impedances are to be divided by 5 10 17 Circuit Breaker Failure Protection optional Circuit Breaker Monitoring Current flow monitoring 0 05 A to 20 00 A1 steps 0 01 A Drop off to pick up ratio approx 0 95 Tolerance 5 of the set value or 0 01 A1 Monitoring of circuit breaker auxiliary contact p...

Page 707: ...20 ms after switch on of measured values Drop off time internal approx 12 ms for sinusoidal measured values overshoot time approx 25 ms maximum Delay times for all stages 0 00 s to 30 00 s steps 0 01 s Tolerance 1 of the set value or 10 ms End Fault Protection With trip command transmission to the remote end Delay times for all stages 0 00 s to 30 00 s steps 0 01 s Tolerance 1 of the set value or ...

Page 708: ...ans of temperaturerise of 3 phases temperature rise from maximum current Tripping Characteristic see Figure 10 6 Drop off Ratios Θ Θtrip drop off with Θalarm Θ Θalarm approx 0 99 I Ialarm approx 0 95 Tolerances Relating to k IN 2 or 10 mA1 class 2 according to IEC 60 255 8 Relating to Tripping time 3 or 1 s class 3 according to IEC 60 255 8 for I k IN 1 25 1 Secondary values based on IN 1 A for IN...

Page 709: ...3 0 1 100 20 10 5 2 0 5 0 2 0 05 min 3 30 30 3 Parameter Setting Value Time Factor 20 200 500 100 50 10 5 2 1 4 6 7 8 50 t τ I k IN è ø æ ö 2 I k IN è ø æ ö 2 1 ln without Previous Load Current I k IN 1 2 3 5 10 12 4 6 7 8 with 90 Previous Load Current t τ I k IN è ø æ ö 2 Ipre k IN è ø ç æ ö2 I k IN è ø æ ö 2 1 ln 50 Parameter Setting Value Time Factor 1000 500 200 100 50 20 10 5 2 1 τ min τ min ...

Page 710: ...teps 0 01 BAL U LIMIT 10 V to 100 V steps 1 V Voltage phase rotation UL1 before UL2 before UL3 as long as UL1 UL2 UL3 40 V 3 Fuse Failure Monitor 3 U0 FFM U OR 3 U2 FFM U non symmetrical voltages AND at the same time 3 I0 FFM I AND 3 I2 FFM I FFM U 10 V to 100 V steps 0 01 V FFM I 0 10 A to 1 00 A1 steps 0 01 A Fuse Failure Monitor all UPh E FFM U max three phase AND at the same time all IPh FFM I...

Page 711: ...perating times total approx Drop off times total approx The operating times refer to the output of commands via accelerated output relays transmission speed 512 kbit s 128 kbit s 64 kbit s 2 ends minimum typical 12 ms 14 ms 14 ms 16 ms 16 ms 18 ms 3 ends minimum typical 13 ms 15 ms 16 ms 19 ms 21 ms 24 ms transmission speed 512 kbit s 128 kbit s 64 kbit s 2 ends minimum typical 10 ms 12 ms 12 ms 1...

Page 712: ... UN Operational measured values of impedances RL1 E RL2 E RL3 E RL1 L2 RL2 L3 RL3 L1 XL1 E XL2 E XL3 E XL1 L2 XL2 L3 XL3 L1 in Ω primary and secondary Operational measured values of power S P Q apparent active and reactive power in MVA MW Mvar primary and SN operational nominal power 3 UN IN Tolerance 1 of SN for I IN and U UN in the range from 50 to 120 1 of PN for I IN and U UN in the range from...

Page 713: ...L1 3U0 PForw PRev QForw QRev S Pd Qd Sd cos ϕ Pos cos ϕ Neg f in primary values Remote measured values for currents IL1 IL2 IL3 of remote end ϕ IL1 ϕ IL2 ϕ IL3 remote versus local in Remote measured values for voltages UL1 UL2 UL3 of remote end ϕ UL1 ϕ UL2 ϕ UL3 remote versus local in Analog Outputs optional Quantity max 4 dependent on order variant Possible measured values IL2 UL2 L3 P Q in Possi...

Page 714: ...the device separate for 1 pole and 3 pole AR separate for 1st AR cycle and for all further cyles Total of interrupted currents caused by 7SA6 pole segregated Maximum interrupted current pole segregated Availability of the transmission availability in min and h Delay time of transmission resolution 0 01 ms Real Time Clock and Buffer Battery Resolution for operational events 1 ms Resolution for faul...

Page 715: ... 34 Mounting plate Side View with screwed terminals 244 9 61 266 10 47 2 29 5 34 Mounting plate 29 30 Side View with plug in terminals Dimensions in mm 1 16 172 6 77 1 34 0 08 1 16 1 18 1 14 172 6 77 266 10 47 244 9 61 0 08 1 34 Values in brackets in inches 146 2 5 75 0 07 255 8 0 3 10 07 0 01 245 1 9 64 0 03 5 0 19 6 0 24 Panel Cut Out 150 5 91 145 5 71 Rear View or M4 105 0 5 4 13 0 01 131 5 0 3...

Page 716: ... 5 0 20 or M4 6 0 24 Panel cut out 255 8 0 3 10 07 0 01 206 5 0 3 8 13 0 01 13 2 7 3 5 4 2 29 5 34 Mounting plate Side view with screwed terminals 244 9 61 266 10 47 2 29 5 34 Mounting plate 29 30 Side view with plug in terminals Dimensions in mm 1 16 172 6 77 1 34 0 08 1 16 1 18 1 14 172 6 77 266 10 47 244 9 61 0 08 1 34 Values in brackets in inches 245 1 9 64 0 04 180 0 5 7 09 0 02 0 29 0 52 0 2...

Page 717: ...19 Figure 10 9 Dimensions 7SA6 for panel flush mounting or cubicle installation size 2 3 300 295 Rear view Panel cut out 296 2 5 or M4 255 8 0 3 245 1 255 0 5 13 2 7 3 5 4 13 2 281 5 0 3 6 5 or M4 5 or M4 Dimensions in mm 105 0 5 F K J P N R Q 5 or M4 Side view with screwed terminals 244 266 2 29 5 172 34 Mounting plate ...

Page 718: ...6 75 0 01 6 0 24 5 0 20 view from the device front Dimensions in mm Values in brackets in inches Side view with screwed terminals 244 9 61 266 10 47 2 29 5 34 Mounting plate 1 16 172 6 77 1 34 0 08 2 29 5 34 Mounting plate 29 30 Side view with plug in terminals 1 16 1 18 1 14 172 6 77 266 10 47 244 9 61 0 08 1 34 446 2 17 56 0 08 245 1 9 64 0 03 or M4 6 0 24 6 0 24 5 0 20 or M4 5 0 20 or M4 6 0 24...

Page 719: ...ting size 1 2 x 19 280 11 02 165 6 50 144 5 76 150 5 91 320 12 60 344 13 54 260 10 24 29 5 1 16 71 2 80 72 2 83 25 266 10 47 Front view Side view 31 45 60 46 1 15 16 30 Dimensions in mm Values in brackets in inches 10 5 0 41 52 2 05 9 0 35 0 98 280 11 02 240 9 45 219 8 62 225 8 86 320 12 60 344 13 54 10 5 260 10 24 29 5 71 72 52 25 266 10 47 Front view Side view 9 1 25 26 50 51 75 76 100 Dimension...

Page 720: ...ure 10 13 Dimensions 7SA6 for panel surface mounting size 1 1 x 19 280 11 02 465 18 31 444 17 48 450 17 72 320 12 60 344 13 54 10 5 Front view 1 50 51 100 200 101 151 150 Dimensions in mm Values in brackets in inches 260 10 24 29 5 71 72 52 25 266 10 47 Side view 1 16 2 80 2 83 2 05 0 98 9 0 35 0 41 ...

Page 721: ... 244 9 61 266 10 47 209 5 8 25 Mounting plate 225 8 86 220 8 66 Side view with screw terminals Side view 12 5 0 49 4 5 0 18 312 8 12 31 Mounting Holes of 300 0 3 11 81 0 01 200 0 3 7 87 0 11 34 1 34 Dimensions in mm 244 9 61 266 10 47 209 5 8 25 29 Mounting plate Side view with plug in terminals 30 312 8 12 31 34 Values in brackets in inches Mounting Plate 1 14 1 18 1 34 100 0 3 3 93 0 11 6 4 0 25...

Page 722: ...17 52 Rear View 25 4 5 0 18 Mounting Holes of Mounting Plate 300 0 3 11 81 0 01 200 0 3 7 87 0 01 300 0 3 11 81 0 01 400 0 3 15 75 0 01 244 9 61 266 10 47 209 5 8 25 Mounting Plate Side View with Screw Terminals 312 8 12 31 34 1 34 Dimensions in mm 244 9 61 266 10 47 209 5 8 25 29 Mounting Plate Side View with Screw Terminals 30 312 8 12 31 34 1 34 Values in brackets in inches 1 14 1 18 6 4 0 25 1...

Page 723: ...or a 7SA6 device n n n n 246 2 9 69 266 10 47 2 0 08 29 5 27 Mounting Plate 225 8 86 220 8 66 Side View Rear View Panel Cut Out 68 pin Connection Cable to Device Length 2 2 m 0 09 221 2 8 70 0 08 5 0 20 6 0 24 255 8 0 3 10 07 0 01 180 0 5 7 07 0 02 206 5 0 3 8 13 0 01 247 2 1 9 73 0 04 1 16 1 06 or M4 4 3 0 17 13 2 0 52 7 3 0 29 ...

Page 724: ...Technical Data 10 56 7SA6 Manual C53000 G1176 C156 ...

Page 725: ...ns of the 7SA6 models are included Connection examples show the proper connections of the device to primary equipment in typical power system configurations Tables with all settings and all information available in a 7SA6 equipped with all options are provided A 1 Ordering Information and Accessories A 2 A 2 General Diagrams A 13 A 3 Connection Examples A 51 A 4 Preset Configurations A 66 A 5 Prot...

Page 726: ...ng Number of Binary Inputs BI and Outputs BO BI Binary Inputs BO Binary Outputs Flush mounting housing 1 3 x 19 5 BI 8 BO 1 Live status contact A Flush mounting housing 1 3 x 19 7 BI 5 BO 1 Live status contact B Surface mounting housing 1 3 x 19 5 BI 8 BO 1 Live status contact E Surface mounting housing 1 3 x 19 7 BI 5 BO 1 Live status contact F Flush mounting housing with plug in terminals 1 3 x ...

Page 727: ... 19 20 BI 8 BO 4 2 Power Relay 1 Live status contact B Surface mounting housing 1 2 x 19 13 BI 16 BO 7 fast 1 Live status contact E Surface mounting housing 1 2 x 19 20 BI 8 BO 4 2 Power Relay 1 Live status contact F Flush mounting housing with plug in terminals 1 2 x 19 13 BI 16 BO 7 fast 1 Live status contact J Flush mounting housing with plug in terminals 1 2 x 19 20 BI 8 BO 4 2 Power Relay 1 L...

Page 728: ...Live status contact F Surface mounting housing 1 1 x 19 33 BI 11 BO 8 4 Power Relay 1 Live status contact G Flush mounting housing with plug in terminals 1 1 x 19 21 BI 24 BO 7 fast 1 Live status contact J Flush mounting housing with plug in terminals 1 1 x 19 29 BI 32 BO 7 fast 1 Live status contact K Flush mounting housing with plug in terminals 1 1 x 19 33 BI 11 BO 8 4 Power Relay 1 Live status...

Page 729: ...7 V 2 2 DC 60 V to 125 V 1 Threshold Binary Input 17 V 2 4 DC 110 V to 250 V 1 AC 115 V Threshold Binary Input 73 V 2 5 Housing Number of Binary Inputs BI and Outputs BO BI Binary Inputs BO Binary Outputs Flush mounting housing 2 3 x 19 21 BI 24 BO 7 fast 1 Live status contact A Flush mounting housing 2 3 x 19 21 BI 24 BO 5 High Speed 1 Live status contact M 1 with plug in jumper one of the 2 volt...

Page 730: ...ary Inputs BO Binary Outputs Housing 1 2 x 19 with screwed terminals 13 BI 16 BO 7 fast 1 Live status contact A Housing 1 2 x 19 with screwed terminals 20 BI 8 BO 4 2 Power Relay 1 Live status contact B Housing 1 2 x 19 plug in terminals 13 BI 16 BO 7 fast 1 Live status contact J Housing 1 2 x 19 plug in terminals 20 BI 8 BO 4 2 Power Relay 1 Live status contact K Housing 1 2 x 19 with screwed ter...

Page 731: ...fast 1 Live status contact B Housing 1 1 x 19 with screwed terminals 33 BI 11 BO 8 4 Power Relay 1 Live status contact C Housing 1 1 x 19 plug in terminals 21 BI 24 BO 7 fast 1 Live status contact J Housing 1 1 x 19 plug in terminals 29 BI 32 BO 7 fast 1 Live status contact K Housing 1 1 x 19 plug in terminals 33 BI 11 BO 8 4 Power Relay 1 Live status contact L Housing 1 1 x 19 with screwed termin...

Page 732: ...tem port Profibus FMS Slave optical single ended ring ST connector 5 System port Profibus FMS Slave optical double ended ring ST connector 6 Analog Output 2 x 0 to 20 mA 7 For further protocols see additional information L 9 Port B System port Profibus DP Slave electrical RS485 0 A System port Profibus DP Slave optical 820 nm double ended ring ST connector 0 B System port DNP3 0 electrical RS485 0...

Page 733: ...ckup U I without power swing option with parallel line compensation 2 J Pickup Z Polygon without power swing option with parallel line compensation 2 K Pickup Z Polygon U I ϕ without power swing option with parallel line compensation 2 L Pickup Z Polygon with power swing option with parallel line compensation 2 N Pickup Z Polygon U I ϕ with power swing option with parallel line compensation 2 P Fu...

Page 734: ...0 nm C53207 A351 D643 1 Profibus FMS RS485 C53207 A351 D603 1 Profibus FMS double ring C53207 A351 D606 1 FO5 with ST connector 820 nm multimode optical fibre maximum length 1 5 km 1 C53207 A351 D651 1 FO6 with ST connector 820 nm multimode optical fibre maximum length 3 km C53207 A351 D652 1 FO7 with ST connector 1300 nm monomode optical fibre maximum length 10 km C53207 A351 D653 1 FO8 with FC c...

Page 735: ...e to aid in the setting of characteristic curves and provide zone dia grams for overcurrent and distance protective devices Option package of the com plete version of DIGSI 4 Connector Type Order No 2 pin C73334 A1 C35 1 3 pin C73334 A1 C36 1 Name Order No Angle Strip Mounting Rail C73165 A63 C200 2 Lithium Battery 3 V 1 Ah Type CR 1 2 AA Order No VARTA 6127 101 501 Interface Cable between PC or S...

Page 736: ...of the complete version of DIGSI 4 SIMATIC CFC 4 Software for graphical setting interlocking latching control conditions and creating additional function is SIPROTEC 4 devices Option package for the complete version of DIGSI 4 DIGSI REMOTE 4 Order No Full version with license for 10 machines 7XS5440 1AA0 SIMATIC CFC 4 Order No Full version with license for 10 machines 7XS5450 0AA0 ...

Page 737: ...ng at the supply Rear Wall R9 R10 BO7 F1 F2 Live status F3 F4 contact 1 2 3 2 Time Synchronisation Q1 Q2 IL1 Q3 Q4 IL2 Q5 Q6 IL3 R13 R14 U4 R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R11 R12 BO8 Sevice Interface C Protection Interface D Q7 Q8 I4 For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 ...

Page 738: ...ct 1 2 3 2 For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 Q1 Q2 IL1 Q3 Q4 IL2 Q5 Q6 IL3 R13 R14 U4 R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 R7 R8 BO5 R1 R2 BO1 R3 BO2 R4 BO3 R9 R10 BI6 R11 R12 BI7 Q7 Q8 I4 System Interface or Analog Output B A Time Synchronisation Sevice Interface C D Front Serial Operating Interface Protection Interface or ...

Page 739: ...L1 Q3 Q4 IL2 Q5 Q6 IL3 R13 R14 U4 R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 K11 K12 BO14 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 1 2 3 2 BO9 Q7 Q8 I4 System Interface or Analog Output B A Time S...

Page 740: ...Q5 Q6 IL3 R13 R14 U4 R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 R1 R2 BO1 R3 BO2 R4 BO3 R9 R10 BI6 R11 R12 BI7 K15 K16 BI20 R5 R6 BO4 R7 R8 BO5 J11 J12 BO12 K10 K12 K13 K14 K11 BI16 BI18 BI19 BI17 K6 K8 K9 K5 K7 BI12 BI14 BI15 BI13 K1 K3 K4 K2 BI8 BI10 BI11 BI9 J7 J9 BO10 J8 BO11 J1 J2 BO6 J3 J4 K18 K17 BO7 BO8 BO9 Power Relay Q7 Q8 I4 System Interface or Analog Output B A ...

Page 741: ...1 Q3 Q4 IL2 Q5 Q6 IL3 R13 R14 U4 R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 K11 K12 BO14 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 BO9 Q7 Q8 I4 System Interface or Analog Output B A Time Synchronis...

Page 742: ... BI5 BI3 K11 K12 BO14 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 1 2 3 2 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P1...

Page 743: ...3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 1 2 3 2 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14 BO23 P15 P16 BO24 H17 H18 BI22 G1 G2 BI23 G4 G6 G5 G3 BI25 BI26 BI24 G7 G8 BI27 G9 G10 BI28 G11 G12 BI29 H6 H7 BO26 H8 BO27 H5 BO28 H9 H10 BO29 H11 H12 BO30 H13 H14 BO31 H15 H16 ...

Page 744: ...l flush mounted or cubicle mounted Earthing at the Rear Wall For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System Interface or Analog Output B A Time Synchronisation Sevice Interface C D Front Serial Operating Interface Protection Interface or Analog Output ...

Page 745: ...BI5 BI3 K11 K12 BO14 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14 BO23 P1...

Page 746: ... 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14 BO23 P15 P16 BO24 H17 H18 BI22 G1 G2 BI23 G4 G6 G5 G3 BI25 BI26 BI24 G7 G8 BI27 G9 G10 BI28 G11 G12 BI29 H6 H7 BO26 H8 BO27 H5 BO28 H9 H10 BO29 H11 H12 BO30 H13 H14 BO31 H15 H16 BO32 cont...

Page 747: ...l flush mounted or cubicle mounted Earthing at the Rear Wall For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System Interface or Analog Output B A Time Synchronisation Sevice Interface C D Front Serial Operating Interface Protection Interface or Analog Output ...

Page 748: ...O1 R3 BO2 R4 BO3 R9 R10 BI6 R11 R12 BI7 K15 K16 BI20 R5 R6 BO4 R7 R8 BO5 J11 J12 BO12 K10 K12 K13 K14 K11 BI16 BI18 BI19 BI17 K6 K8 K9 K5 K7 BI12 BI14 BI15 BI13 K1 K3 K4 K2 BI8 BI10 BI11 BI9 J7 J9 BO10 J8 BO11 J1 J2 BO6 J3 J4 K18 K17 BO7 BO8 BO9 P6 P8 P9 P5 P7 BI25 BI27 BI28 BI26 P1 P3 P4 P2 BI21 BI23 BI24 BI22 P10 P12 P13 P14 P11 BI29 BI31 BI32 BI30 P15 P16 BI33 N1 N2 BO13 N3 N4 P18 P17 BO14 BO15...

Page 749: ...BI5 BI3 K11 K12 BO14 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 1 2 3 2 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14...

Page 750: ...5 BI3 K11 K12 BO14 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14 BO23 P15 ...

Page 751: ...26 25 U4 45 44 UL1 60 UL2 59 UL3 37 36 BI1 34 33 52 35 BI2 BI4 BI5 BI3 42 57 BO3 41 BO4 56 BO5 58 BO2 43 BO1 55 40 1 2 3 2 BO6 53 38 BO8 Earthing Terminal 16 12 27 I4 2 17 3 19 18 4 1 Time Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System Interface or Analog Output B Sevice Interface C D Front ...

Page 752: ...5 44 UL1 60 UL2 59 UL3 37 36 BI1 34 33 52 35 BI2 BI4 BI5 BI3 55 40 BO5 43 58 BO1 42 BO2 57 BO3 54 39 BI6 53 38 BI7 12 27 I4 Earthing Terminal 16 2 17 3 19 18 4 1 TimeTime Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System Interface or Analog Output B Sevice Interface C D Front Serial Operating I...

Page 753: ...1 89 BO12 43 18 BI6 42 17 BI7 40 14 39 41 BI9 BI10 BI8 38 13 BI11 37 12 BI12 36 11 BI13 73 98 BO3 72 BO4 97 BO5 99 BO2 74 BO1 96 71 1 2 3 2 BO6 95 70 BO7 94 69 BO8 85 60 BO15 84 59 BO16 90 65 1 2 3 2 BO9 22 47 I4 Earthing Terminal 26 2 27 3 29 28 4 1 Time Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 ...

Page 754: ...4 59 BI20 97 72 BO4 96 71 BO5 14 39 BO12 62 60 86 85 61 BI16 BI18 BI19 BI17 91 89 88 87 90 BI12 BI14 BI15 BI13 66 64 63 65 BI8 BI10 BI11 BI9 18 17 BO10 42 BO11 12 37 BO6 11 36 38 13 BO7 BO8 BO9 22 47 I4 EarthingTerminal Terminal 26 2 27 3 29 28 4 1 Time Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 ...

Page 755: ...89 BO12 43 18 BI6 42 17 BI7 40 14 39 41 BI9 BI10 BI8 38 13 BI11 37 12 BI12 36 11 BI13 73 98 BO3 72 BO4 97 BO5 99 BO2 74 BO1 96 71 1 2 3 2 BO6 95 70 BO7 94 69 BO8 85 60 BO15 84 59 BO16 90 65 BO9 22 47 I4 Earthing Terminal 26 2 27 3 29 28 4 1 Time Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System...

Page 756: ...O11 173 BO12 75 25 BI6 74 24 BI7 23 22 72 73 BI9 BI10 BI8 71 21 BI11 70 20 BI12 69 19 BI13 148 198 BO3 147 BO4 197 BO5 199 BO2 149 BO1 196 146 1 2 3 2 BO6 195 145 BO7 194 144 BO8 169 119 BO15 168 118 BO16 174 124 1 2 3 2 BO9 90 40 BI14 89 39 BI15 36 35 85 86 BI17 BI18 BI16 84 34 BI19 83 33 BI20 82 32 BI21 139 188 BO18 138 BO19 189 BO20 187 137 BO21 186 136 BO22 185 135 BO23 184 134 BO24 47 97 I4 c...

Page 757: ...all EarthingEarthing Terminal 51 2 52 3 54 53 4 1 Time Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System Interface or Analog Output B Sevice Interface C D Front Serial Operating Interface Protection Interface or Analog Output ...

Page 758: ... 3 2 BO6 195 145 BO7 194 144 BO8 169 119 BO15 168 118 BO16 174 124 1 2 3 2 BO9 90 40 BI14 89 39 BI15 36 35 85 86 BI17 BI18 BI16 84 34 BI19 83 33 BI20 82 32 BI21 139 188 BO18 138 BO19 189 BO20 187 137 BO21 186 136 BO22 185 135 BO23 184 134 BO24 68 18 BI22 67 17 BI23 16 15 65 66 BI25 BI26 BI24 64 14 BI27 63 13 BI28 62 12 BI29 115 164 BO26 114 BO27 165 BO28 163 113 BO29 162 112 BO30 161 111 BO31 160 ...

Page 759: ...de Wall Earthing Terminal 51 2 52 3 54 53 4 1 Time Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System Interface or Analog Output B Sevice Interface C D Front Serial Operating Interface Protection Interface or Analog Output ...

Page 760: ...72 171 174 BI12 BI14 BI15 BI13 125 123 122 124 BI8 BI10 BI11 BI9 23 22 BO10 72 BO11 19 69 BO6 18 68 70 20 BO7 BO8 BO9 190 188 187 186 189 BI25 BI27 BI28 BI26 140 138 137 139 BI21 BI23 BI24 BI22 136 134 185 184 135 BI29 BI31 BI32 BI30 183 133 BI33 34 84 BO13 33 83 85 35 BO14 BO15 BO16 36 86 BO19 40 39 BO17 89 BO18 47 97 I4 Earthing Terminal 51 2 52 3 54 53 4 1 Time IN 12 V IN SYNC COM SYNC COMMON I...

Page 761: ... 71 21 BI11 70 20 BI12 69 19 BI13 148 198 BO3 147 BO4 197 BO5 199 BO2 149 BO1 196 146 1 2 3 2 BO6 195 145 BO7 194 144 BO8 169 119 BO15 168 118 BO16 174 124 BO9 90 40 BI14 89 39 BI15 36 35 85 86 BI17 BI18 BI16 84 34 BI19 83 33 BI20 82 32 BI21 139 188 BO18 138 BO19 189 BO20 187 137 BO21 186 136 BO22 185 135 BO23 184 134 BO24 continued next page continued next page 47 97 I4 190 140 1 2 3 2 BO17 Power...

Page 762: ...de Wall Earthing Terminal 51 2 52 3 54 53 4 1 Time Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System Interface or Analog Output B Sevice Interface C D Front Serial Operating Interface Protection Interface or Analog Output ...

Page 763: ... BO6 195 145 BO7 194 144 BO8 169 119 BO15 168 118 BO16 174 124 BO9 90 40 BI14 89 39 BI15 36 35 85 86 BI17 BI18 BI16 84 34 BI19 83 33 BI20 82 32 BI21 139 188 BO18 138 BO19 189 BO20 187 137 BO21 186 136 BO22 185 135 BO23 184 134 BO24 68 18 BI22 67 17 BI23 16 15 65 66 BI25 BI26 BI24 64 14 BI27 63 13 BI28 62 12 BI29 115 164 BO26 114 BO27 165 BO28 163 113 BO29 162 112 BO30 161 111 BO31 160 110 BO32 con...

Page 764: ...de Wall Earthing Terminal 51 2 52 3 54 53 4 1 Time Synchronisation IN 12 V IN SYNC COM SYNC COMMON IN 24 V Screen IN 5 V For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 System Interface or Analog Output B Sevice Interface C D Front Serial Operating Interface Protection Interface or Analog Output ...

Page 765: ... Q1 Q2 IL1 Q3 Q4 IL2 Q5 Q6 IL3 R13 R14 U4 R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 K11 K12 BO14 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 1 2 3 2 BO9 Earthing at the Rear Wall Q7 Q8 I4 System Int...

Page 766: ... R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 R1 R2 BO1 R3 BO2 R4 BO3 R9 R10 BI6 R11 R12 BI7 K15 K16 BI20 R5 R6 BO4 R7 R8 BO5 J11 J12 BO12 K10 K12 K13 K14 K11 BI16 BI18 BI19 BI17 K6 K8 K9 K5 K7 BI12 BI14 BI15 BI13 K1 K3 K4 K2 BI8 BI10 BI11 BI9 J7 J9 BO10 J8 BO11 J1 J2 BO6 J3 J4 K18 K17 BO7 BO8 BO9 Earthing at the Rear Wall Q7 Q8 I4 System Interface or Analog Output B A Time S...

Page 767: ... R13 R14 U4 R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 K11 K12 BO14 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 BO9 Earthing at the Rear Wall Q7 Q8 I4 System Interface or Analog Output B A Time Synch...

Page 768: ...4 K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 1 2 3 2 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14 BO23 P15 P16 BO24 ...

Page 769: ... R1 BO1 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 1 2 3 2 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14 BO23 P15 P16 BO24 H17 H18 BI22 G1 G2 BI23 G4 G6 G5 G3 BI25 BI26 BI24 G7 G8 BI27 G9 G10 BI28 G11 G12 BI29 H6 H7 BO26 H8 BO27 H5 BO28 H9 H10 BO29 H11 H12 BO30 H13 H14 BO31 H15 H16 ...

Page 770: ...operator panel Earthing at the Rear Wall For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 Earthing at the Rear Wall System Interface or Analog Output B A Time Synchronisation Sevice Interface C D Front Serial Operating Interface Operator Panel Protection Interface or Analog Output ...

Page 771: ...10 BI6 R11 R12 BI7 K15 K16 BI20 R5 R6 BO4 R7 R8 BO5 J11 J12 BO12 K10 K12 K13 K14 K11 BI16 BI18 BI19 BI17 K6 K8 K9 K5 K7 BI12 BI14 BI15 BI13 K1 K3 K4 K2 BI8 BI10 BI11 BI9 J7 J9 BO10 J8 BO11 J1 J2 BO6 J3 J4 K18 K17 BO7 BO8 BO9 P6 P8 P9 P5 P7 BI25 BI27 BI28 BI26 P1 P3 P4 P2 BI21 BI23 BI24 BI22 P10 P12 P13 P14 P11 BI29 BI31 BI32 BI30 P15 P16 BI33 N1 N2 BO13 N3 N4 P18 P17 BO14 BO15 BO16 N11 N12 BO19 N7...

Page 772: ...K6 K7 BO10 K8 BO11 K5 BO12 K17 K18 BI6 J1 J2 BI7 J4 J6 J5 J3 BI9 BI10 BI8 J7 J8 BI11 J9 J10 BI12 J11 J12 BI13 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R7 R8 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14 BO23 P15 P16 BO24 Earthing a...

Page 773: ...R1 BO1 R9 R10 BO7 R11 R12 BO8 K13 K14 BO15 K15 K16 BO16 K3 K4 BO9 P17 P18 BI14 N1 N2 BI15 N4 N6 N5 N3 BI17 BI18 BI16 N7 N8 BI19 N9 N10 BI20 N11 N12 BI21 P6 P7 BO18 P8 BO19 P5 BO20 P9 P10 BO21 P11 P12 BO22 P13 P14 BO23 P15 P16 BO24 H17 H18 BI22 G1 G2 BI23 G4 G6 G5 G3 BI25 BI26 BI24 G7 G8 BI27 G9 G10 BI28 G11 G12 BI29 H6 H7 BO26 H8 BO27 H5 BO28 H9 H10 BO29 H11 H12 BO30 H13 H14 BO31 H15 H16 BO32 cont...

Page 774: ...operator panel Earthing at the Rear Wall For Pin Allocations of Interfaces see Table 8 11 and 8 12 in Subsection 8 2 1 Earthing at the Rear Wall System Interface or Analog Output B A Time Synchronisation Sevice Interface C D Front Serial Operating Interface Operator Panel Protection Interface or Analog Output ...

Page 775: ...or all networks Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 15 14 13 12 30 29 28 27 7SA6 Housing Size 1 3 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 50 25 49 24 48 23 47 22 50 100 49 99 48 98 47 97 7SA6 Housing Size 1 2 Figures in Brackets Relating to Size 1 1 S2 S1 P2 P1 S2 S1 P2 P1 Flush Mounted Cubi...

Page 776: ...in this diagram Important Cable shield grounding must be done on the cable side Note Change of Address 0201 setting changes polarity of 3I0 Current Input i e terminal Q7 must be connected to that CT terminal pointing in the same direction as the starpoint of the phase current CTs towards Line side in this diagram Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6...

Page 777: ...er Important Cable shield grounding must be done on the cable side Note Change of Address 0201 setting changes polarity of 3I0 Current Input i e terminal Q7 must be connected to that CT terminal pointing in the same direction as the starpoint of the phase current CTs towards Line side in this diagram Flush Mounted Cubicle L1 L2 L3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 7SA6 Housing Size 2 3 I4 IL1 IL2 IL3 S2 S1 ...

Page 778: ...wards Line side in this diagram Important Cable shield grounding must be done on the cable side Note Change of Address 0201 setting changes polarity of 3I0 Current Input i e terminal Q7 must be connected to that CT terminal pointing in the same direction as the starpoint of the phase current CTs towards Line side in this diagram Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 I4 IL1 IL2 IL3 Q...

Page 779: ...st be done on the cable side Note Change of Address 0201 setting changes polarity of 3I0 Current Input i e terminal Q7 must be connected to that CT terminal pointing in the same direction as the starpoint of the phase current CTs towards Line side in this diagram Flush Mounted Cubicle L1 L2 L3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 7SA6 Housing Size 2 3 I4 IL1 IL2 IL3 S2 S1 P2 P1 S2 S1 P2 P1 Housing Size 1 3 Lin...

Page 780: ...Line 1 Panel Surface Mounted Flush Mounted Cubicle I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 50 25 49 24 48 23 47 97 50 100 49 99 48 98 47 22 7SA6 Panel Surface Mounted Flush Mounted Cubicle I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 50 25 49 24 48 23 47 97 50 100 49 99 48 98 47 22 7SA6 S2 S1 P2 P1 S2 S1 P2 P1 Housing Size 2 3 Line 2 L1 L2 L3 Line 1 Flush Mounted Cubicle I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6 ...

Page 781: ...otection Housing Size 1 3 Line L1 L2 L3 Transformer Panel Surface Mounted Flush Mounted Cubicle I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 15 14 13 27 30 29 28 12 7SA6 Housing Size 1 2 Figures in Brackets Relating to Size 1 1 Line L1 L2 L3 Transformer Panel Surface Mounted Flush Mounted Cubicle I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 50 25 49 24 48 23 97 47 50 100 49 99 48 98 22 47 7SA6 S2 S1 P2 P1 S1 ...

Page 782: ...e current transformers and earth current from the star point connection of an earthed power transformer for directional controlled earth fault protection Housing Size 2 3 Line L1 L2 L3 Transformer Flush Mounted Cubicle I4 IL1 IL2 IL3 Q1 Q3 Q5 Q2 Q4 Q6 Q7 Q8 7SA6 S1 S2 P1 P2 S2 S1 P2 P1 ...

Page 783: ...ousing Size 1 3 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 44 60 UL3 7SA6 R16 59 Housing Size 1 2 Figures in Brackets Relating to Size 1 1 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 20 44 19 94 44 UL3 7SA6 R16 95 45 a b A B a b A B Housing Size 2 3 Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 UL3 7SA6 R16 a b A B ...

Page 784: ...ush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 44 60 UL3 7SA6 R16 59 R13 U4 26 R14 25 Housing Size 1 2 Figures in Brackets Relating to Size 1 1 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 20 44 19 94 44 UL3 7SA6 R16 95 45 R13 U4 46 21 R14 96 46 a b A B da dn a b A B da dn Housing Size 2 3 Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 UL3 7SA6 R16 R13 U4 R1...

Page 785: ...from the busbar Housing Size 1 3 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 44 60 UL3 7SA6 R16 59 R13 U4 26 R14 25 Housing Size 1 2 Figures in Brackets Relating to Size 1 1 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 20 44 19 94 44 UL3 7SA6 R16 95 45 R13 U4 46 21 R14 96 46 a b A B A B da dn a b A B A B da dn ...

Page 786: ... 44 Voltage connections to two V connected voltage transformers with additional open delta windings da dn winding from the busbar Housing Size 2 3 Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 UL3 7SA6 R16 R13 U4 R14 a b A B A B da dn Housing Size 1 3 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 44 60 UL3 7SA6 R16 59 R13 U4 26 R14 25 a b A B A B da dn A B b a ...

Page 787: ...n winding from the busbar Housing Size 1 2 Figures in Brackets Relating to Size 1 1 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 20 44 19 94 44 UL3 7SA6 R16 95 45 R13 U4 46 21 R14 96 46 A B da dn a b A B A B b a Housing Size 2 3 Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 UL3 7SA6 R16 R13 U4 R14 A B da dn a b A B A B b a ...

Page 788: ...e connected voltage transformers and additionally to any phase to phase voltage for overvoltage protection and or synchronism check Housing Size 1 3 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 44 60 UL3 7SA6 R16 59 R13 U4 26 R14 25 any voltage a b A B A B a b ...

Page 789: ...ltage protection and or synchronism check Housing Size 2 3 Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 UL3 7SA6 R16 R13 U4 R14 any voltage a b A B A B a b Housing Size 1 2 Figures in Brackets Relating to Size 1 1 Panel Surface Mounted Flush Mounted Cubicle L1 L2 L3 R15 R17 R18 UL1 UL2 45 20 44 19 94 44 UL3 7SA6 R16 95 45 R13 U4 46 21 R14 96 46 any voltage a b A B A B a b ...

Page 790: ...hed LED 2 Relay PICKUP L2 503 Device general pick up phase L1 latched LED3 Relay PICKUP L2 504 Device general pick up phase L2 latched LED4 Relay PICKUP L3 505 Device general pick up phase L3 latched LED5 Relay PICKUP E 506 Device general pick up earth fault latched LED6 EF reverse Dis reverse 1359 3720 Device general pick up reverse fault latched LED7 2 2 no pre setting 2 Relay TRIP 1pL1 Relay TR...

Page 791: ...arks BI1 Reset LED 5 Reset of LED indications H active BI2 Manual Close 356 Manual close of circuit breaker H active no presetting 2 BI3 FAIL Feeder VT I STUB ENABLE 361 Voltage transformer secondary miniture circuit breaker H active BI4 DisTel Rec Ch1 4006 Distance protection teleprotection re ceive signal H active BI5 CB1 Ready 371 Circuit breaker 1 ready L active CB wait CB waiting for spring c...

Page 792: ... open H active 2 BI13 EarthSwit closed 2 Earth switch closed H active 2 BI16 Door open High voltage system Door open H active 2 further no presetting 2 1 only devices without power relays 2 only devices with power relays Table A 5 Further binary output presettings for all ordering variants Binary Output LCD Text Function No Remarks BO1 Relay PICKUP 0501 Device general pickup BO5 Alarm Sum Event 01...

Page 793: ...ommand for breaker pole L3 1 1 devices with single and three pole tripping 2 devices with three pole tripping only 3 devices with automatic reclosure Table A 9 Further binary output presettings 7SA6 1 B F K and 7SA6 2 C G L Binary Output LCD Text Function No Remarks BO2 Breaker open Relay TRIP 2 5112 Circuit breaker open or Relay general trip command 2 BO3 Breaker close AR CLOSE Cmd 2851 3 Circuit...

Page 794: ...L2 1 BO12 2 2 no presetting 2 Relay TRIP 1pL3 Relay TRIP 3ph 514 1 515 1 Device general trip command for breaker pole L3 1 Table A 9 Further binary output presettings 7SA6 1 B F K and 7SA6 2 C G L Binary Output LCD Text Function No Remarks 1 devices with single and three pole tripping 2 devices with three pole tripping only 3 devices with automatic reclosure ...

Page 795: ...e this indication only queued for 500 ms also indication Device Brk OPENED is reset after this time period Figure A 48 Allocation of input and output with blocks of level System Logic Interlocking With blocks of level Interlocking SFS_BEARB interlocking standard interlocking for three switchgears circuit breaker disconnector and earth switch is pre defined Due to the large functional scope of the ...

Page 796: ...he disconnector can only be closed if the circuit breaker is set to CLOS and the disconnector is set to OPEN or CLOS and the earth switch is set to OPEN or CLOS and the input indication Door open is set to OPEN The earth switch can only be closed if the circuit breaker is set to OPEN and the disconnector is set to OPEN and the earth switch is set to OPEN or CLOS and the input indication Door open ...

Page 797: ...nterlocking A 15 X2 Interlocking A 17 X3 Interlocking A 16 X3 OUT Control Device 52 Close IE Interlocking A 14 X Interlocking A 17 X4 Interlocking A 16 X4 Interlocking A 15 X4 Interlocking A 12 Y Interlocking A 5 Y Indication Interlocking A 8 Y Interlocking A 12 Y Interlocking A 1 Y Indication Interlocking A 12 Y Interlocking A 8 Y Interlocking A 12 Y Interlocking A 10 Y Interlocking A 3 Y Indicat...

Page 798: ...Processing of Measured Values MW_BEARB IN Set points cosPhi LV IN Demand Meter cosPhi DM OUT Set points LV cosPhi OUT IN Set points IL1dmd LV IN Demand Meter IL1dmd DM IN Set points IL2dmd LV IN Demand Meter IL2dmd DM IN Set points IL3dmd LV IN Demand Meter IL3dmd DM IN Set points I1dmd LV IN Demand Meter I1dmd DM IN Set points Pdmd LV IN Demand Meter Pdmd DM IN Set points Sdmd LV IN Demand Meter ...

Page 799: ... defined Annunciations in CFC Pre defined User defined Annunciations in CFC Yes Time Sychronism Via Protocol DCF77 IRIG B Interface Binary Input Via Protocol DCF77 IRIG B Interface Binary Input Via DCF77 IRIG B Interface Binary Input Via DCF77 IRIG B Interface Binary Input Alarms with Time Stamp Yes Yes No Yes Yes Commissioning Tools Alarm and Measured Value Transmission Blocking Yes Yes No No Yes...

Page 800: ...Appendix A 76 7SA6 Manual C53000 G1176 C156 2 ...

Page 801: ...ix B This appendix is primarily a reference for the experienced user Tables with all settings and all information available in a 7SA6 equipped with all options are provided B 1 Settings B 2 B 2 List of Information B 23 B 3 Measured Values B 59 ...

Page 802: ...son POTT over Protec tion Interface Disabled Disabled Teleprotection for Distance prot 121 122 DTT Direct Trip Disabled Enabled Disabled DTT Direct Transfer Trip 122 124 SOTF Overcurr Disabled Enabled Disabled Instantaneous HighSpeed SOTF Overcurrent 124 125 Weak Infeed Disabled Enabled Disabled Weak Infeed Trip and or Echo 125 126 Back Up O C Disabled Time Overcurrent Curve IEC Time Overcurrent C...

Page 803: ...bled Trip Circuit Supervision 140 142 Ther OVERLOAD Disabled Enabled Disabled Thermal overload protection 142 145 P INTERFACE 1 Enabled Disabled Enabled Protection Interface 1 Port D 145 147 NUMBER OF RELAY 2 relays 3 relays 2 relays Number of relays 147 150 AnalogOutput B1 Disabled IL2 UL23 P Q Fault location d Fault location d km Fault location d miles Trip current Imax primary Disabled Analog O...

Page 804: ...rs RE RL and XE XL Zero seq comp factor K0 and angle K0 Zero seq comp factors RE RL and XE XL Setting format for zero seq comp for mat 239 T CB close Power System Data 1 0 01 0 60 sec 0 06 sec Closing operating time of CB 240A TMin TRIP CMD Power System Data 1 0 02 30 00 sec 0 10 sec Minimum TRIP Command Duration 241A TMax CLOSE CMD Power System Data 1 0 01 30 00 sec 0 10 sec Maximum Close Command...

Page 805: ...ctor XE XL for Z1B Z5 1120 K0 Z1 Power System Data 2 0 000 4 000 1 000 Zero seq comp factor K0 for zone Z1 1121 Angle K0 Z1 Power System Data 2 135 00 135 00 0 00 Zero seq comp angle for zone Z1 1122 K0 Z1 Power System Data 2 0 000 4 000 1 000 Zero seq comp factor K0 higher zones Z1 1123 AngleI K0 Z1 Power System Data 2 135 00 135 00 0 00 Zero seq comp angle higher zones Z1 1126 RM RL ParalLine Po...

Page 806: ...0 1PHAS Distance protec tion general set tings 0 00 0 50 sec 0 04 sec Delay 1ph faults comp isol star point 1207A 3I0 Iphmax Distance protec tion general set tings 0 05 0 30 0 10 3I0 pickup stabilisation 3I0 Iph max 1215 Paral Line Comp Distance protec tion general set tings NO YES YES Mutual coupling parall line compensa tion 1220 PHASE PREF 2phe Distance protec tion general set tings L3 L1 acycl...

Page 807: ...ive Forward Operating mode Z2 1312 R Z2 Ø Ø Distance zones quadrilateral 0 050 250 000 Ohm 2 500 Ohm R Z2 Resistance for ph ph faults 1313 X Z2 Distance zones quadrilateral 0 050 250 000 Ohm 5 000 Ohm X Z2 Reactance 1314 RE Z2 Ø E Distance zones quadrilateral 0 050 250 000 Ohm 5 000 Ohm RE Z2 Resistance for ph e faults 1315 T2 1phase Distance protec tion general set tings Distance zones quadrilate...

Page 808: ...tance zones quadrilateral 0 050 250 000 Ohm 12 000 Ohm RE Z5 Resistance for ph e faults 1345 T5 DELAY Distance protec tion general set tings Distance zones quadrilateral 0 00 30 00 sec 0 90 sec T5 delay 1346 X Z5 Distance zones quadrilateral 0 050 250 000 Ohm 4 000 Ohm X Z5 Reactance for Reverse direc tion 1351 Op mode Z1B Distance zones quadrilateral Forward Reverse Non Directional Inactive Forwa...

Page 809: ...tance protec tion general set tings 0 10 8 00 A 0 50 A Iphi Pickup minimum current at phi 1617 Uph e Iphi Distance protec tion general set tings 20 70 V 48 V Undervoltage ph e at Iphi 1618 Uph ph Iphi Distance protec tion general set tings 40 130 V 80 V Undervoltage ph ph at Iphi 1619A EFFECT ϕ Distance protec tion general set tings forward and reverse Forward forward and reverse Effective directi...

Page 810: ...ak Infeed Trip and or Echo 2 70 V 25 V Undervoltage ph e 2601 Operating Mode Backup overcurrent ON Only Active with Loss of VT sec circuit OFF Only Active with Loss of VT sec circuit Operating mode 2610 Iph Backup overcurrent 0 10 25 00 A 2 00 A Iph Pickup 2611 T Iph Backup overcurrent 0 00 30 00 sec 0 30 sec T Iph Time delay 2612 3I0 PICKUP Backup overcurrent 0 05 25 00 A 0 50 A 3I0 Pickup 2613 T...

Page 811: ...ec Trip time delay after SOTF 2801 DMD Interval Demand Measure ment Setup 15 Min per 1 Sub 15 Min per 3 Subs 15 Min per 15 Subs 30 Min per 1 Sub 60 Min per 1 Sub 60 Min per 1 Sub Demand Calculation Intervals 2802 DMD Sync Time Demand Measure ment Setup On the Hour 15 Min after Hour 30 Min after Hour 45 Min after Hour On the Hour Demand Synchronization Time 2811 MinMax cycRESET Min Max Measure ment...

Page 812: ... Uph e min of faulted phase 3004 Uph e max Sensitive Earth Flt comp isol starp 10 100 V 75 V Uph e max of healthy phases 3005 3I0 Sensitive Earth Flt comp isol starp 0 003 1 000 A 0 050 A 3I0 Release directional element 3006 T Sens E F Sensitive Earth Flt comp isol starp 0 00 320 00 sec 1 00 sec Time delay for sens E F detection 3007 T 3U0 Sensitive Earth Flt comp isol starp 0 00 320 00 sec 0 00 s...

Page 813: ...rating mode 3121 3I0 Earth fault overcur rent 0 20 25 00 A 2 00 A 3I0 Pickup 3122 T 3I0 Earth fault overcur rent 0 00 30 00 sec 0 60 sec T 3I0 Time Delay 3123 3I0 Telep BI Earth fault overcur rent NO YES NO Instantaneous trip via Teleprot BI 3124 3I0 SOTF Trip Earth fault overcur rent NO YES NO Instantaneous trip after SwitchOnTo Fault 3125 3I0 InrushBlk Earth fault overcur rent NO YES NO Inrush B...

Page 814: ...Inverse ANSI Curve 3153 LOG Curve Earth fault overcur rent Logarithmic inverse Logarithmic inverse LOGARITHMIC Curve 3154 3I0p Startpoint Earth fault overcur rent 1 0 4 0 1 1 Start point of inverse characteristic 3160 POLARIZATION Earth fault overcur rent with U0 and IY dual polar ized with IY transformer star point current with U2 and I2 negative sequence with U0 and IY dual polar ized Polarizati...

Page 815: ...t flt 3401 AUTO RECLOSE Automatic Reclo sure OFF ON ON Auto Reclose function 3402 CB 1 TRIP Automatic Reclo sure YES NO NO CB ready interrogation at 1st trip 3403 T RECLAIM Automatic Reclo sure 0 50 300 00 sec 3 00 sec Reclaim time after successful AR cycle 3404 T BLOCK MC Automatic Reclo sure 0 50 300 00 sec 0 1 00 sec AR blocking duration after manual close 3406 EV FLT RECOG Automatic Reclo sure...

Page 816: ...0 01 1800 00 sec 1 20 sec Dead time after 2phase faults 3455 1 AR Tdead 3Flt Automatic Reclo sure 0 01 1800 00 sec 0 50 sec Dead time after 3phase faults 3456 1 AR Tdead1Trip Automatic Reclo sure 0 01 1800 00 sec 1 20 sec Dead time after 1pole trip 3457 1 AR Tdead3Trip Automatic Reclo sure 0 01 1800 00 sec 0 50 sec Dead time after 3pole trip 3458 1 AR Tdead EV Automatic Reclo sure 0 01 1800 00 sec...

Page 817: ...re 0 01 300 00 sec 0 20 sec Action time 3486 4 AR Tdead 1Flt Automatic Reclo sure 0 01 1800 00 sec 1 20 sec Dead time after 1phase faults 3487 4 AR Tdead 2Flt Automatic Reclo sure 0 01 1800 00 sec 1 20 sec Dead time after 2phase faults 3488 4 AR Tdead 3Flt Automatic Reclo sure 0 01 1800 00 sec 0 50 sec Dead time after 3phase faults 3489 4 AR Tdead1Trip Automatic Reclo sure 0 01 1800 00 sec sec Dea...

Page 818: ...Maximum frequency difference 3533 MC maxAngleDiff Synchronism and Voltage Check 2 60 10 Maximum angle difference 3535A MC SYNCHR Synchronism and Voltage Check YES NO YES Live bus live line and Sync before MC 3536 MC Usyn Uline Synchronism and Voltage Check YES NO NO Live bus dead line check before Man Cl 3537 MC Usyn Uline Synchronism and Voltage Check YES NO NO Dead bus live line check before Man...

Page 819: ...49A U2 RESET Voltage Protection 0 50 0 98 0 98 U2 Reset ratio 3751 Uph e Voltage Protection OFF Alarm Only ON OFF Operating mode Uph e undervoltage prot 3752 Uph e Voltage Protection 1 0 100 0 V 0 30 0 V Uph e Pickup 3753 T Uph e Voltage Protection 0 00 30 00 sec 2 00 sec T Uph e Time Delay 3754 Uph e Voltage Protection 1 0 100 0 V 0 10 0 V Uph e Pickup 3755 T Uph e Voltage Protection 0 00 30 00 s...

Page 820: ...OFF End fault stage is 3922 T EndFault Breaker Failure 0 00 30 00 sec 2 00 sec Trip delay of end fault stage 3931 PoleDiscrepancy Breaker Failure ON OFF OFF Pole Discrepancy supervision 3932 T PoleDiscrep Breaker Failure 0 00 30 00 sec 2 00 sec Trip delay with pole discrepancy 4001 FCT TripSuperv Trip Circuit Supervi sion ON OFF OFF TRIP Circuit Supervision is 4002 No of BI Trip Circuit Supervi si...

Page 821: ...gOutputs 10 100000 A 20000 A 20 mA B2 correspond to 5013 20 mA B2 AnalogOutputs 1 0 1000 0 km 50 0 km 20 mA B2 correspond to 5014 20 mA B2 AnalogOutputs 1 0 1000 0 Miles 50 0 Miles 20 mA B2 correspond to 5016 MIN VALUE B2 AnalogOutputs 0 0 5 0 mA 4 0 mA Output value B2 valid from 5017 NEG VALUE B2 AnalogOutputs 1 00 22 50 mA 19 84 mA Output value B2 for negative values 5018 OVERFLOW B2 AnalogOutpu...

Page 822: ...lue IN 1 A For a secondary nominal current value IN 5 A the current values are to be multiplied by 5 For setting primary values the transformation ratio of the transformer also must be taken into consideration Settings specified with an A can only be changed with DIGSI 4 under Additional Settings 5039 Tmax OUTPUT D2 AnalogOutputs 0 10 180 00 sec 5 00 sec Maximum output time D2 Addr Setting Title F...

Page 823: ...On Off Marked in Oscill Record LED Binary Input Function Key Binary Output Chatter Blocking Type Information No Data Unit ASDU General Interrogation 3 Synchronize Internal Real Time Clock Time Synch Device SP LED BI BO 4 Trigger Waveform Capture Trig Wave Cap Oscillographic Fault Records SP ON M LED BI BO 5 Reset LED Reset LED Device SP LED BI BO 7 Setting Group Select Bit 0 Set Group Bit0 Change ...

Page 824: ...O 135 183 1 GI 164 Failure general Voltage Supervision Fail U Superv Measurement Supervision OUT LED BO 128 33 1 GI 165 Failure Voltage summation Phase Earth Fail Σ U Ph E Measurement Supervision OUT ON OFF LED BO 135 184 1 GI 167 Failure Voltage Balance Fail U balance Measurement Supervision OUT ON OFF LED BO 135 186 1 GI 168 Failure Voltage absent Fail U absent Measurement Supervision OUT ON OFF...

Page 825: ... 1 GI 203 Waveform data deleted Wave deleted Oscillographic Fault Records OUT_Ev ON LED BO 135 203 1 273 Set Point Phase L1 dmd SP IL1 dmd Set Points Mea sured Values OUT on off LED BO 135 230 1 GI 274 Set Point Phase L2 dmd SP IL2 dmd Set Points Mea sured Values OUT on off LED BO 135 234 1 GI 275 Set Point Phase L3 dmd SP IL3 dmd Set Points Mea sured Values OUT on off LED BO 135 235 1 GI 276 Set ...

Page 826: ... trip permitted from ext AR 1p Trip Perm Power System Data 2 SP ON OFF LED BI BO 382 External AR programmed for 1phase only Only 1ph AR Power System Data 2 SP ON OFF LED BI BO 383 Enable all AR Zones Stages Enable ARzones Power System Data 2 SP ON OFF ON OFF LED BI BO 385 Lockout SET Lockout SET Power System Data 2 SP ON OFF LED BI BO 150 35 1 GI 386 Lockout RESET Lockout RESET Power System Data 2...

Page 827: ...ICKUP Phase L3 Relay PIKKUP L3 Power System Data 2 OUT M LED BO 128 66 2 GI 506 Relay PICKUP Earth Relay PICKUP E Power System Data 2 OUT M LED BO 128 67 2 GI 507 Relay TRIP command Phase L1 Relay TRIP L1 Power System Data 2 OUT M LED BO 128 69 2 508 Relay TRIP command Phase L2 Relay TRIP L2 Power System Data 2 OUT M LED BO 128 70 2 509 Relay TRIP command Phase L3 Relay TRIP L3 Power System Data 2...

Page 828: ...6 205 924 Wp Forward Wp Energy MVMV 133 51 205 925 Wq Forward Wq Energy MVMV 133 52 205 928 Wp Reverse Wp Energy MVMV 133 53 205 929 Wq Reverse Wq Energy MVMV 133 54 205 1000 Number of breaker TRIP commands TRIPs Statistics OUT 1001 Number of breaker TRIP commands L1 TripNo L1 Statistics OUT 1002 Number of breaker TRIP commands L2 TripNo L2 Statistics OUT 1003 Number of breaker TRIP commands L3 Tr...

Page 829: ...n 1 BCD d 1 Fault Locator OUT LED BO 1144 BCD Fault location 2 BCD d 2 Fault Locator OUT LED BO 1145 BCD Fault location 4 BCD d 4 Fault Locator OUT LED BO 1146 BCD Fault location 8 BCD d 8 Fault Locator OUT LED BO 1147 BCD Fault location 10 BCD d 10 Fault Locator OUT LED BO 1148 BCD Fault location 20 BCD d 20 Fault Locator OUT LED BO 1149 BCD Fault location 40 BCD d 40 Fault Locator OUT LED BO 115...

Page 830: ...ensitive Earth Flt comp isol starp OUT ON LED BO 128 51 1 GI 1277 Sensitve E F detection Reverse SensEF Reverse Sensitive Earth Flt comp isol starp OUT ON LED BO 128 52 1 GI 1278 Sensitve E F detection Undef Direction SensEF undefDir Sensitive Earth Flt comp isol starp OUT ON LED BO 151 178 1 GI 1281 Sensitve E F detection TRIP command SensEF TRIP Sensitive Earth Flt comp isol starp OUT ON ON LED ...

Page 831: ...ction for Earth fault over curr SP ON OFF ON LED BI BO 166 24 1 GI 1331 Earth fault protection is switched OFF E F Prot OFF Earth fault over current OUT ON OFF LED BO 166 31 1 GI 1332 Earth fault protection is BLOCKED E F BLOCK Earth fault over current OUT ON OFF ON OFF LED BO 166 32 1 GI 1333 Earth fault protection is ACTIVE E F ACTIVE Earth fault over current OUT LED BO 166 33 1 GI 1345 Earth fa...

Page 832: ... for Earth fault over curr OUT ON OFF LED BO 166 88 1 GI 1389 E F Telep Blocking carrier STOP signal EF Tele BL STOP Teleprotection for Earth fault over curr OUT on LED BO 166 89 2 1390 E F Tele Blocking Send signal with jump EF Tele BL Jump Teleprotection for Earth fault over curr OUT LED BO 166 90 2 1391 EF Tele Carrier RECEPTION L1 Device1 EF Rec L1 Dev1 Teleprotection for Earth fault over curr...

Page 833: ...ure prot ON OFF via BI Bkr FailON offBI Breaker Failure IntSP ON OFF LED BO 1451 Breaker failure is switched OFF BkrFail OFF Breaker Failure OUT ON OFF LED BO 166 151 1 GI 1452 Breaker failure is BLOCKED BkrFail BLOCK Breaker Failure OUT ON OFF ON OFF LED BO 166 152 1 GI 1453 Breaker failure is ACTIVE BkrFail ACTIVE Breaker Failure OUT LED BO 166 153 1 GI 1461 Breaker failure protection started BF...

Page 834: ...O L TRIP Thermal Overload OUT ON M LED BO 167 21 1 2054 Emergency mode Emer mode Backup overcur rent OUT ON OFF ON OFF LED BO 128 37 1 GI 2701 AR Switch on auto reclose function AR on Automatic Reclo sure SP LED BI BO 40 1 1 2702 AR Switch off auto reclose function AR off Automatic Reclo sure SP LED BI BO 40 2 1 2703 AR Block auto reclose function AR block Automatic Reclo sure SP ON OFF LED BI BO ...

Page 835: ...up L2 for AR start Pickup L2 AR Automatic Reclo sure SP ON LED BI BO 40 43 2 GI 2749 AR External pickup L3 for AR start Pickup L3 AR Automatic Reclo sure SP ON LED BI BO 40 44 2 GI 2750 AR External pickup 1phase for AR start Pickup 1ph AR Automatic Reclo sure SP ON LED BI BO 40 45 2 GI 2751 AR External pickup 2phase for AR start Pickup 2ph AR Automatic Reclo sure SP ON LED BI BO 40 46 2 GI 2752 AR...

Page 836: ... LED BO 40 155 2 GI 2845 AR 2nd cycle running AR 2ndCyc run Automatic Reclo sure OUT ON LED BO 40 157 2 GI 2846 AR 3rd cycle running AR 3rdCyc run Automatic Reclo sure OUT ON LED BO 40 158 2 GI 2847 AR 4th or higher cycle running AR 4thCyc run Automatic Reclo sure OUT ON LED BO 40 159 2 GI 2848 AR cycle is running in ADT mode AR ADT run Automatic Reclo sure OUT ON LED BO 40 130 2 GI 2851 AR Close ...

Page 837: ...e Check SP LED BI BO 2903 BLOCK synchro check function BLOCK Sync Synchronism and Voltage Check SP LED BI BO 2905 Start synchro check for Manual Close Sync Start MC Synchronism and Voltage Check SP on off LED BI BO 2906 Start synchro check for AR Sync Start AR Synchronism and Voltage Check SP on off LED BI BO 2907 Sync Prog Live bus live line Sync Sync synch Synchronism and Voltage Check SP LED BI...

Page 838: ...tage Check OUT LED BO 41 51 1 GI 2961 Close command from synchro check Sync CloseCmd Synchronism and Voltage Check OUT LED BO 41 61 1 GI 2970 Sync Bus frequency fn 3Hz Sync f bus Synchronism and Voltage Check OUT ON OFF ON OFF LED BO 2971 Sync Bus frequency fn 3Hz Sync f bus Synchronism and Voltage Check OUT ON OFF ON OFF LED BO 2972 Sync Line frequency fn 3Hz Sync f line Synchronism and Voltage C...

Page 839: ...ON OFF LED BO 93 142 1 GI 3464 Communication topology is complete Topol complete Protection Inter face Port D E OUT ON OFF LED BO 3487 Equal IDs in constellation Equal IDs Protection Inter face Port D E OUT ON OFF LED BO 3541 Remote Trip 1 signal input Remote Trip1 Remote Signals SP on off LED BI BO 3542 Remote Trip 2 signal input Remote Trip2 Remote Signals SP on off LED BI BO 3543 Remote Trip 3 ...

Page 840: ...gnals 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 Signal 20 input Rem Signal20 Remote Signals SP on off LED BI BO 3569 Remote Signal 21 input Rem Signal21 Remote Signals SP on off LED ...

Page 841: ...3588 Remote signal 16 received Rem Sig16recv Remote Signals OUT on off LED BO 93 173 1 GI 3589 Remote signal 17 received Rem Sig17recv Remote Signals OUT on off LED BO 93 174 1 GI 3590 Remote signal 18 received Rem Sig18recv Remote Signals OUT on off LED BO 93 175 1 GI 3591 Remote signal 19 received Rem Sig19recv Remote Signals OUT on off LED BO 93 176 1 GI 3592 Remote signal 20 received Rem Sig20...

Page 842: ...ance PICKUP L1 Dis Pickup L1 Distance protec tion general set tings OUT M LED BO 28 72 2 GI 3673 Distance PICKUP L2 Dis Pickup L2 Distance protec tion general set tings OUT M LED BO 28 73 2 GI 3674 Distance PICKUP L3 Dis Pickup L3 Distance protec tion general set tings OUT M LED BO 28 74 2 GI 3675 Distance PICKUP Earth Dis Pickup E Distance protec tion general set tings OUT M LED BO 28 75 2 GI 368...

Page 843: ...tance protec tion general set tings OUT M LED BO 3696 Dist Phi phase L2 Pickup Dis Pickup ϕ L2 Distance protec tion general set tings OUT M LED BO 3697 Dist Phi phase L3 Pickup Dis Pickup ϕ L3 Distance protec tion general set tings OUT M LED BO 3701 Distance Loop L1E selected forward Dis Loop L1 E f Distance protec tion general set tings OUT ON OFF LED BO 3702 Distance Loop L2E selected forward Di...

Page 844: ...ngs OUT ON OFF LED BO 3716 Distance Loop L12 selected non direct Dis Loop L12 Distance protec tion general set tings OUT ON OFF LED BO 3717 Distance Loop L23 selected non direct Dis Loop L23 Distance protec tion general set tings OUT ON OFF LED BO 3718 Distance Loop L31 selected non direct Dis Loop L31 Distance protec tion general set tings OUT ON OFF LED BO 3719 Distance Pickup FORWARD Dis forwar...

Page 845: ... Z3 Distance protec tion general set tings OUT LED BO 3759 Distance Pickup Z4 Dis Pickup Z4 Distance protec tion general set tings OUT LED BO 3760 Distance Pickup Z5 Dis Pickup Z5 Distance protec tion general set tings OUT LED BO 3771 DistanceTime Out T1 Dis Time Out T1 Distance protec tion general set tings OUT LED BO 128 78 2 3774 DistanceTime Out T2 Dis Time Out T2 Distance protec tion general ...

Page 846: ...ce TRIP single phase Z2 Dis TripZ2 1p Distance protec tion general set tings OUT LED BO 28 216 2 3817 Distance TRIP 3phase in Z2 Dis TripZ2 3p Distance protec tion general set tings OUT LED BO 28 217 2 3818 Distance TRIP 3phase in Z3 Dis TripZ3 T3 Distance protec tion general set tings OUT LED BO 28 218 2 3819 Dist Trip by fault detection forward Dis Trip FD Distance protec tion general set tings ...

Page 847: ...ot SP on off on LED BI BO 29 10 1 GI 4030 Dis Tele Unblocking UNBLOCK Chan nel 1 Dis T UB ub 1 Teleprotection for Distance prot SP on off on LED BI BO 29 30 1 GI 4031 Dis Tele Unblocking BLOCK Channel 1 Dis T UB bl 1 Teleprotection for Distance prot SP on off on LED BI BO 29 31 1 GI 4032 Dis Tele Unblocking UNBLOCK Ch 1 L1 Dis T UB ub1L1 Teleprotection for Distance prot SP on off on LED BI BO 29 3...

Page 848: ...L2 Dis T BL STOPL2 Teleprotection for Distance prot OUT LED BO 4084 DisTel Blocking carrier STOP signal L3 Dis T BL STOPL3 Teleprotection for Distance prot OUT LED BO 4085 Dis Tele Carrier RECEPTION L1 Device1 Dis T RecL1Dev1 Teleprotection for Distance prot OUT on off on LED BO 4086 Dis Tele Carrier RECEPTION L2 Device1 Dis T RecL2Dev1 Teleprotection for Distance prot OUT on off on LED BO 4087 Di...

Page 849: ...nd or Echo OUT ON LED BO 4241 Weak Infeed General TRIP command WeakInfeed TRIP Weak Infeed Trip and or Echo OUT LED BO 25 41 2 4242 Weak Infeed TRIP command Only L1 Weak TRIP 1p L1 Weak Infeed Trip and or Echo OUT ON LED BO 25 42 2 4243 Weak Infeed TRIP command Only L2 Weak TRIP 1p L2 Weak Infeed Trip and or Echo OUT ON LED BO 25 43 2 4244 Weak Infeed TRIP command Only L3 Weak TRIP 1p L3 Weak Infe...

Page 850: ...2 DTT Trip L2 DTT Direct Trans fer Trip SP ON OFF LED BI BO 4414 Direct Transfer Trip INPUT Phase L3 DTT Trip L3 DTT Direct Trans fer Trip SP ON OFF LED BI BO 4417 Direct Transfer Trip INPUT 3ph L123 DTT Trip L123 DTT Direct Trans fer Trip SP ON OFF LED BI BO 4421 Direct Transfer Trip is switched OFF DTT OFF DTT Direct Trans fer Trip OUT ON OFF LED BO 51 21 1 GI 4422 Direct Transfer Trip is BLOCKE...

Page 851: ... OFF LED BI BO 64 6 1 GI 7110 Backup OverCurrent InstantaneousTrip O C InstTRIP Backup overcur rent SP ON OFF ON OFF LED BI BO 64 10 1 GI 7130 BLOCK I STUB BLOCK I STUB Backup overcur rent SP ON OFF LED BI BO 64 30 1 GI 7131 Enable I STUB Bus function I STUB ENABLE Backup overcur rent SP ON OFF ON OFF LED BI BO 64 31 1 GI 7151 Backup O C is switched OFF O C OFF Backup overcur rent OUT ON OFF LED B...

Page 852: ...C Pickup L123 Backup overcur rent OUT ON LED BO 64 84 2 7185 Backup O C Pickup L123E O C PickupL123E Backup overcur rent OUT ON LED BO 64 85 2 7191 Backup O C Pickup I O C PICKUP I Backup overcur rent OUT ON LED BO 64 91 2 GI 7192 Backup O C Pickup I O C PICKUP I Backup overcur rent OUT ON LED BO 64 92 2 GI 7193 Backup O C Pickup Ip O C PICKUP Ip Backup overcur rent OUT ON LED BO 64 93 2 GI 7201 O...

Page 853: ...sting OUT_Ev ON 7350 CB TEST was succesful CB TST OK Testing OUT_Ev ON 10201 BLOCK Uph e Overvolt phase earth Uph e BLK Voltage Protection SP LED BI BO 10202 BLOCK Uph ph Overvolt phase phase Uph ph BLK Voltage Protection SP LED BI BO 10203 BLOCK 3U0 Overvolt zero sequence 3U0 BLK Voltage Protection SP LED BI BO 10204 BLOCK U1 Overvolt positive seq U1 BLK Voltage Protection SP LED BI BO 10205 BLOC...

Page 854: ... 1 GI 10230 U1 Undervolt is BLOCKED U1 BLK Voltage Protection OUT ON OFF ON OFF LED BO 73 30 1 GI 10231 Over Under Voltage protection is ACTIVE U ACTIVE Voltage Protection OUT ON OFF LED BO 73 31 1 GI 10240 Uph e Pickup Uph e Pickup Voltage Protection OUT ON OFF LED BO 73 40 2 GI 10241 Uph e Pickup Uph e Pickup Voltage Protection OUT ON OFF LED BO 73 41 2 GI 10242 Uph e Pickup L1 Uph e PU L1 Volta...

Page 855: ...2 GI 10290 U2 Pickup U2 Pickup Voltage Protection OUT ON OFF LED BO 73 90 2 GI 10291 U2 Pickup U2 Pickup Voltage Protection OUT ON OFF LED BO 73 91 2 GI 10292 U2 TimeOut U2 TimeOut Voltage Protection OUT LED BO 10293 U2 TimeOut U2 TimeOut Voltage Protection OUT LED BO 10294 U2 TRIP command U2 TRIP Voltage Protection OUT ON LED BO 73 94 2 GI 10300 U1 Pickup U1 Pickup Voltage Protection OUT ON OFF L...

Page 856: ...et door open Door open Process Data SP on off LED BI BO CB 101 1 1 GI CB waiting for Spring charged CB wait Process Data SP on off LED BI BO CB 101 2 1 GI Error Control Voltage ErrCntrlU Process Data SP on off LED BI BO CB 240 182 1 GI Error Meter Err Meter Process Data SP on off LED BI BO CB 240 184 1 GI Error Motor Voltage Err Mot U Process Data SP on off LED BI BO CB 240 181 1 GI SF6 Loss SF6 L...

Page 857: ...rror Systeminterface SysIntErr Protocol IntSP on off LED BO Fan ON OFF Fan ON OFF Control Device CF_D2 on off BO 240 175 1 GI Fan ON OFF Fan ON OFF Control Device DP on off BI CB 240 175 1 GI Fault Recording Start FltRecSta Oscillographic Fault Records IntSP ON OFF LED BO Feeder EARTHED FdrEARTHED Device IntSP LED BO Group A Group A Change Group IntSP ON OFF LED BO 128 23 1 GI Group B Group B Chan...

Page 858: ...ol Device CF_D2 on off BO 240 163 1 GI Q9 Open Close Q9 Op Cl Control Device DP on off BI CB 240 163 1 GI Stop data transmission DataStop Device IntSP ON OFF LED BO 128 20 1 GI Test mode Test mode Device IntSP ON OFF LED BO 128 21 1 GI Unlock data transmission via BI UnlockDT Control Device IntSP F No Description Function Type of Informa tion Log Buffers Configurable in Matrix IEC 60870 5 103 Even...

Page 859: ...sequence I1 Measurement CFC CD DD 620 I2 negative sequence I2 Measurement CFC CD DD 621 U L1 E UL1E Measurement 128 148 comp 9 4 CFC CD DD 134 124 priv 9 4 622 U L2 E UL2E Measurement 128 148 comp 9 5 CFC CD DD 134 124 priv 9 5 623 U L3 E UL3E Measurement 128 148 comp 9 6 CFC CD DD 134 124 priv 9 6 624 U L12 UL12 Measurement 134 124 priv 9 10 CFC CD DD 625 U L23 UL23 Measurement 134 124 priv 9 11 ...

Page 860: ...hase L1 Θ ΘtripL1 Measurement CFC CD DD 803 Temperature rise for phase L2 Θ ΘtripL2 Measurement CFC CD DD 804 Temperature rise for phase L3 Θ ΘtripL3 Measurement CFC CD DD 833 I1 positive sequence Demand I1dmd Demand Mea surement Setup CFC CD DD 834 Active Power Demand Pdmd Demand Mea surement Setup CFC CD DD 835 Reactive Power Demand Qdmd Demand Mea surement Setup CFC CD DD 836 Apparent Power Dem...

Page 861: ...um IL2Max Min Max Mea surement Setup CFC CD DD 855 I L3 Minimum IL3Min Min Max Mea surement Setup CFC CD DD 856 I L3 Maximum IL3Max Min Max Mea surement Setup CFC CD DD 857 Positive Sequence Minimum I1 Min Min Max Mea surement Setup CFC CD DD 858 Positive Sequence Maximum I1 Max Min Max Mea surement Setup CFC CD DD 859 U L1E Minimum UL1EMin Min Max Mea surement Setup CFC CD DD 860 U L1E Maximum UL...

Page 862: ...nd IL1dmd Demand Mea surement Setup CFC CD DD 964 I L2 demand IL2dmd Demand Mea surement Setup CFC CD DD 965 I L3 demand IL3dmd Demand Mea surement Setup CFC CD DD 966 R L1E R L1E Measurement CFC CD DD 967 R L2E R L2E Measurement CFC CD DD 970 R L3E R L3E Measurement CFC CD DD 971 R L12 R L12 Measurement CFC CD DD 972 R L23 R L23 Measurement CFC CD DD 973 R L31 R L31 Measurement CFC CD DD 974 X L1...

Page 863: ... Forw Demand Mea surement Setup CFC CD DD 1053 Active Power Demand Reverse Pdmd Rev Demand Mea surement Setup CFC CD DD 1054 Reactive Power Demand Forward Qdmd Forw Demand Mea surement Setup CFC CD DD 1055 Reactive Power Demand Reverse Qdmd Rev Demand Mea surement Setup CFC CD DD 7751 Prot Int 1 Delay time PI1 DT Statistics CFC DD 7753 Prot Int 1 Availability per minute PI1A m Statistics CFC DD 77...

Page 864: ...lay 2 CFC DD 14021 Angle IL1 ϕIL1 Measurements from relay 2 CFC DD 14022 IL2 primary IL2 Measurements from relay 2 CFC DD 14023 Angle IL2 ϕIL2 Measurements from relay 2 CFC DD 14024 IL3 primary IL3 Measurements from relay 2 CFC DD 14025 Angle IL3 ϕIL3 Measurements from relay 2 CFC DD 14030 UL1E primary UL1E Measurements from relay 2 CFC DD 14031 Angle UL1E ϕUL1E Measurements from relay 2 CFC DD 14...

Page 865: ... relay 3 CFC DD 14055 Angle UL3E ϕUL3E Measurements from relay 3 CFC DD Lower setting limit for Power Factor PF Set Points Mea sured Values CFC Upper setting limit for I1dmd I1dmd Set Points Mea sured Values CFC Upper setting limit for IL1dmd IL1dmd Set Points Mea sured Values CFC Upper setting limit for IL2dmd IL2dmd Set Points Mea sured Values CFC Upper setting limit for IL3dmd IL3dmd Set Points...

Page 866: ...Appendix B 66 7SA6 Manual C53000 G1176 C156 2 ...

Page 867: ...6 259 Breaker Tripping Alarm Suppression 6 300 Broken Conductor 6 277 Buffer Battery 6 274 C Calculation of the Impedances Applying the Function Parameter Settings 6 49 Method of Operation 6 42 Certifications 10 12 CFC 4 15 4 23 CFC as destination 5 34 CFC as source 5 30 Changeover of Setting Groups 7 34 Changeover of setting groups 8 10 Changing the Time 7 30 Characteristics 10 19 Characteristics...

Page 868: ... 6 63 Copying Setting Groups 6 14 Correction of measured values for load current on double end fed lines 6 244 Correction of measured values on Parallel Lines 6 243 Corrective Action Repairs 9 12 Creating User Defined Functions with CFC 5 39 Current flow monitoring 6 249 Current Inputs 10 2 Current Symmetry 6 276 Current Transformer Connection 6 9 Current Transformer Saturation 6 22 Current Voltag...

Page 869: ...ion 6 31 Earth Impedance Residual Compensation 6 18 with Magnitude and Angle K0 Factor 6 19 with Scalar Factor RE RL and XE XL 6 18 Earth Impedance Matching 10 15 Echo Function 6 112 6 116 6 149 6 153 Electrical Communication Interfaces 2 20 2 34 Electrical Check 3 3 Electrical Communication Interfaces 2 48 Electrical Tests 10 9 EMC tests 10 9 10 10 Emergency Operation 10 17 End fault protection 6...

Page 870: ...ndicators LEDs and Binary Outputs Output Relays 6 306 Information 5 18 to a Control Centre 6 307 Information properties 5 19 Information via Integrated Display LCD or a Personal Computer 6 306 Initial Inspections 3 1 Initialize device 9 9 Inrush Stabilization 6 126 6 134 10 21 Inspection of Features and Ratings 3 3 Inspections upon Receipt 3 3 Installation 8 2 Installation and Commissioning 8 1 In...

Page 871: ...rating interface 1 6 Operating modes of the automatic reclosure circuit 6 191 Operating Panel with Four Line Display 4 5 Operating Polygons 6 55 Operating Serial Interface 4 6 Operating Software DIGSI 4 A 11 Operation Using DIGSI 4 3 6 Operation Using the Operator Control Panel 3 4 Operations 4 4 Optical Communication Interfaces 2 30 Optical Fibres 8 43 Optical interfaces ST connectors 2 18 2 45 O...

Page 872: ...g 8 4 Rated Frequency 6 10 Rating of the Protected Plant 6 17 Read and Set Date and Time 7 28 Reading out Metered Values 7 21 Read out of Information Fault Records 7 26 Messages 7 2 Switching Statistics 7 13 Read out of Measured Values 7 15 Real Time Clock and Buffer Battery 10 46 Rear Service Modem Interface 10 6 Reassembling the Device 9 14 Reassembly of Device 8 40 Reclose Block 6 191 Reduced d...

Page 873: ...g 6 287 Synchronism check conditions before automatic reclosure 6 222 before manual closing 6 222 Synchronization and Voltage Check 1 11 System SCADA Interface 8 41 10 7 system interface 1 7 System Starpoint 6 10 T Tagging 4 16 7 55 Technical Data 10 1 Teleprotection Methods 6 139 with Distance Protection 8 69 with Earth Fault Protection 6 133 Teleprotection Methods 6 89 Teleprotection Schemes wit...

Page 874: ...anel Housing Size 1 2 2 7 of Front Panel with Four Line Display Housing Size 1 2 2 5 2 6 2 25 of Front Panel with Four Line Display Housing Size 1 3 2 3 2 23 of Front Panel with Four Line Display Housing Size1 1 2 26 of Front Panel with Graphic Display Housing Size 1 1 2 29 of Front Panel with Graphic Display Housing Size 1 2 2 27 of Rear Panel Housing Size 1 1 2 10 of Rear Panel Housing Size 1 2 ...

Page 875: ...Dear reader printing errors can never be entirely eliminated therefore should you come across any when reading this manual kindly enter them in this form together with any comments or suggestions for improvement that you may have From Name Company Dept Address Phone no Fax no Corrections Suggestions ...

Page 876: ...bidden with out express authority Offenders are liable to the payment of damages All rights are reserved in the event of the grant of a patent or the registration of a utility model or design Order no C53000 G1176 C156 2 Available from LZF Fürth Bislohe Printed in Germany Imprimé en Allemagne AG 07 02 0 1 FO 876 En Siemens Aktiengesellschaft ...

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