Page 1 3UHIDFH 7DEOH RI &RQWHQWV ,QWURGXFWLRQ +DUGZDUH DQG &RQQHFWLRQV SIPROTEC ,QLWLDO ,QVSHFWLRQV Multi-Functional Protective 6,3527(& 'HYLFHV Relay with Bay Controller &RQILJXUDWLRQ 7SJ62 V4.0/V4.1 )XQFWLRQV Instruction Manual 2SHUDWRUV 7RROV ,QVWDOODWLRQ DQG &RPPLVVLRQLQJ 5RXWLQH &KHFNV DQG 0DLQWHQDQFH 7HFKQLFDO 'DWD $SSHQGL[ ,QGH[ C53000-G1140-C121-1...
Page 2: C53000-G1140-C121
Siemens AktiengesellschaftBuch-Nr. C53000-G1140-C121-1...
Page 3 DIN 57435 /Part 303 (corresponds to VDE 0435/Part 303). Y2k Compliance The tests made by Siemens EV S show no indications of any problems of the year 2000 compliance for the relays. Neither the performance nor the functionality of the protection relays become negatively affected through input of a date, which will before, during or after the year 2000.
Page 4 4 devices, please contact your Siemens repre- sentative. Training Courses Individual course offerings may be found in our Training Catalog, or questions can be directed to our training center. Please contact your Siemens representative. Instructions and The following indicators and standard definitions are used: Warnings...
Page 5 Preface QUALIFIED PERSONNEL Within the meaning of safety precautions of this manual and the instructions, qualified personnel are those persons who are qualified to set up, install, place into service, and operate this device, and who possess the following qualifications: Training and instruction (or other qualification) for switching, grounding, and desig- nating devices and systems.
Page 6 Liability Statement Copyright We have checked the text of this manual against the Copyright © Siemens AG 1999. All rights reserved. hardware and software described. Exclusions and devi- Dissemination or reproduction of this document, or evaluation and com- ations cannot be ruled out; we accept no liability for lack munication of its contents, is not authorized except where expressly per- of total agreement.
Page 7: Table Of Contents
Table of Contents Introduction............................1-1 Overall Operation ........................ 1-2 Applications ......................... 1-5 Characteristics........................1-7 Scope of Functions......................1-8 Hardware and Connections ......................2-1 Version of 7SJ62 for Panel Flush-Mounting / Cubicle Mounting ......... 2-2 2.1.1 Construction ........................2-2 2.1.2 Connections to Threaded Terminals ................... 2-5 2.1.3 Connections to Plug-In Terminals ..................
Page 8 Operator Control Facilities ....................4-5 4.2.1 Operating Panel On Device ....................4-5 ® 4.2.2 DIGSI 4 Tool........................4-7 Information Retrieval......................4-8 4.3.1 Annunciations ........................4-9 4.3.2 Measurements ........................4-11 4.3.3 Waveform Capture......................4-13 Control ..........................4-14 Manual Overwrite / Tagging....................4-16 General Setting Procedure ....................
Page 9 Functions............................6-1 General..........................6-3 6.1.1 Power System Data 1......................6-8 6.1.1.1 Settings ..........................6-11 6.1.1.2 Information ........................6-12 6.1.2 Setting Groups ........................6-12 6.1.2.1 Information ........................6-14 6.1.3 Power System Data 2......................6-14 6.1.3.1 Settings ..........................6-17 6.1.3.2 Information ........................6-17 Overcurrent Protection (50, 50N, 51, 51N)................
Page 10 Sensitive Ground Fault Detection (64, 50Ns, 67Ns)............6-73 6.6.1 Description of Sensitive Ground Fault Detection ............... 6-73 6.6.1.1 Voltage Element ........................ 6-73 6.6.1.2 Current Elements....................... 6-74 6.6.1.3 Determination of Direction ....................6-74 6.6.1.4 Location of Ground Connections ..................6-78 6.6.2 Programming Settings .......................
Page 11 6.12 Frequency Protection (81 O/U)..................6-120 6.12.1 Description of Frequency Protection ................6-120 6.12.2 Programming Settings ..................... 6-121 6.12.2.1 Settings for Frequency Protection ................... 6-122 6.12.2.2 Information List for Frequency Protection................ 6-123 6.13 Breaker Failure Protection (50BF)................... 6-124 6.13.1 Description of Breaker Failure Protection................ 6-124 6.13.2 Programming Settings .....................
Page 12 6.18.2 Tripping Logic of the Entire Device.................. 6-163 6.18.2.1 Description........................6-163 6.18.2.2 Programming Settings for Tripping Logic ................ 6-164 6.18.3 Fault Display on the LEDs/LCD ..................6-164 6.18.3.1 Description of “No Trip – No Flag” Option ............... 6-164 6.18.3.2 Programming Settings ..................... 6-164 6.18.4 Statistical Counters......................
Page 13 Control of Device Functions ....................7-28 7.2.1 Display and Set Date and Time..................7-28 7.2.2 Changeover of Setting Groups ..................7-32 7.2.3 Test Messages to the SCADA Interface during Test Operation ........7-35 Control of Switchgear ......................7-38 7.3.1 Display Equipment Position and Control ................7-39 7.3.2 Manual Overwriting......................
Page 14 Maintenance ........................9-4 9.3.1 Replacing the Battery ......................9-4 9.3.1.1 Battery Replacement for flush mount and surface mount devices ........9-4 Troubleshooting ........................9-7 Corrective Action/Repairs ....................9-9 9.5.1 Software Procedures ......................9-9 9.5.2 Hardware Procedures......................9-9 Return ..........................9-13 Technical Data..........................
Page 15 10.17 Breaker Control ....................... 10-35 10.18 Additional Functions ......................10-36 10.19 Dimensions........................10-40 Appendix ............................A-1 Ordering Information and Accessories ................A-2 A.1.1 Accessories .........................A-4 Elementary Diagrams ......................A-6 A.2.1 Panel Flush Mounting or Cubicle Mounting.................A-6 A.2.2 Panel Surface Mounting ......................A-8 Connection Examples......................A-11 Settings ..........................A-17 Interoperability List ......................A-28 Information List ........................
Page 16 7SJ62 Instruction Manual C53000-G1140-C121-1...
Page 17: Introduction
Introduction ® The SIPROTEC 4 7SJ62 devices are introduced in this section. An overview of the devices is presented in their application, characteristics, and scope of functions. Overall Operation Applications Characteristics Scope of Functions 7SJ62 Manual C53000-G1140-C121-1...
Page 18: Overall Operation
Introduction Overall Operation ® The SIPROTEC 4 7SJ62 is a numerical, multi-functional, protective and control de- vice equipped with a powerful microprocessor. All tasks, such as the acquisition of the measured quantities, issuing of commands to circuit breakers and other primary pow- er system equipment, are processed in a completely digital way.
Page 19 Introduction The 7SJ62 has three voltage inputs in the MI section. The inputs can either be used to measure the three phase-ground voltages, or two phase-phase voltages and 3V from, for example, open delta voltage transformers. Displacement voltage is another term used for 3V The analog input quantities from the MI stage are passed on to the input amplification (IA) stage, which provides high-resistance terminations for the analog quantities.
Page 20 Introduction A separate Service Port can be provided for remote communications via a modem, ® ® or substation computer. The SIPROTEC 4 operating program DIGSI 4 is required. All 7SJ62 data can be transferred to a central control and monitor system (RTU/SCA- DA) through the Scada Port.
Page 21: Applications
Introduction Applications ® The numerical, multi-functional SIPROTEC 4 7SJ62 is a versatile device designed for many applications. The 7SJ62 can be used as a protective, control, and monitoring device for distribution feeders and transmission lines of any voltage in networks that are grounded, low-resistance grounded, ungrounded, or of a compensated neutral point structure.
Page 22 Introduction locking conditions for switching (e.g. switching error protection) can be established with the aid of integrated, user-configurable logic functions. Messages and A series of operating messages provide information about conditions in the power sys- Measured Values; tem and the 7SJ62. Measurement quantities and values that are calculated can be Recording of Event displayed locally and communicated via the serial interfaces.
Page 23: Characteristics
Introduction Characteristics • Powerful 32-bit microprocessor system. • Complete digital processing and control of measured values, from the sampling of the analog input quantities to the initiation of outputs for, as an example, tripping or closing circuit breakers or other switchgear devices. •...
Page 24: Scope Of Functions
Introduction Scope of Functions ® The protection features of a SIPROTEC 4 7SJ62 equipped with all options are listed below pointing out highlights of each feature. The actual features of a 7SJ62 depend on the order number. • Two instantaneous (Definite-Time) overcurrent elements and an inverse-time over- Time-Overcurrent Protection current element, for both phase protection and ground protection (50-1, 50-2, 51,...
Page 25 Introduction • Two ground fault elements 67Ns-1 and 67Ns-2 that can be set as non-directional, forward sensing directional, or reverse sensing directional; • Fault direction is determined by calculating the zero sequence real power or reac- tive power, as determined by a setting; •...
Page 26 Introduction • Initiation possible through the integrated control function (control start). • Single-shot or multi-shot; Automatic Reclosing • Dead times associated with the first, second, third, and fourth shots are program- mable and can be different from one another. Dead times for the remaining shots are identical to the dead time for the fourth shot;...
Page 27 Introduction • Tracking of operating hours (time when load is supplied) of the equipment being protected; • Commissioning aids such as connection check, direction determination, and the display of test recordings. 1-11 7SJ62 Manual C53000-G1140-C121-1...
Page 28 Introduction 1-12 7SJ62 Manual C53000-G1140-C121-1...
Page 29: Hardware And Connections
Hardware and Connections An overview of the hardware of the 7SJ62 and detailed information regarding connec- tions to the device are provided in this section. The options for panel mounting and cubicle mounting are described. Device construc- tion is presented. The options for terminal connections and communication interfaces are covered.
Page 30: Version Of 7Sj62 For Panel Flush-Mounting / Cubicle Mounting
The nameplate sticker, showing important information such as power supply rating, nominal current rating, and ordering number, is located on the top of the case and the interior of the front panel. View of Front Panel SIPROTEC SIEMENS ERROR 7SJ62 MAIN MENU 01 / 05...
Page 31 Hardware and Connections Referring to the operating and display elements in Figure 2-1: 1. Display (LCD) The LCD shows processing and device information as text in various lists. Com- monly displayed information includes measured values (metering), counter values, binary information regarding the condition of circuit breakers, status of the device, protection information, general reports, and alarms.
Page 32 Hardware and Connections View of Rear Panel Figure 2-2 is a simplified view of the rear panel of the version of the device with thread- ed (screw-type) terminals and optical fiber ports for the service interface at location B. Figure 2-2 Rear View of a 7SJ62 with Screw-type Terminals (example only) 7SJ62 Manual C53000-G1140-C121-1...
Page 33: Connections To Threaded Terminals
Hardware and Connections 2.1.2 Connections to Threaded Terminals Terminal blocks for the threaded connections are designated as: Terminal blocks for voltage connections, and Terminal blocks for current connections. A simple flat-blade 6x1-mm screwdriver can be used to turn the slotted screws in ei- ther terminal block type.
Page 34 Hardware and Connections Terminal Block for There is one version of a terminal block for current connections to a 7SJ62. The ter- Current minal block is illustrated in Figure 2-5. Connections 8 Terminal Figure 2-5 Terminal Block of Threaded Terminals for Current Connections - Rear View The correlation between threaded terminals and connection numbers is the same for both the current connections and the voltage connections.
Page 35 Hardware and Connections Direct Cable Connections: solid or stranded conductor with connector sleeve; conductor with cross-section of 0.5 mm to 3.3 mm or AWG 20 to 12. Use copper wires only! Maximum Tightening Torque: 1.3 ft-lb or 16 in-lb (1.8 Nm). Connections to Ring or spade lugs may be used.
Page 36 Hardware and Connections Covering Caps Covering caps are available for terminal blocks with threaded terminals. The caps en- hance the safety of personnel by covering the terminal screws; thereby, decreasing the likelihood of inadvertent contact with the live terminals. The caps snap on to the terminal blocks, and can easily be removed with a 6x1-mm screwdriver.
Page 37: Connections To Plug-In Terminals
Hardware and Connections 2.1.3 Connections to Plug-In Terminals Plug-in terminals are only available for voltage connections. Current connections are made with threaded terminals on all 7SJ62. Terminal Blocks for There are two versions of plug-in terminal blocks. They are shown in Figure 2-8. Voltage Connections 18 Terminal...
Page 38 Hardware and Connections inside the 7SJ62. Each common group can, for example, be used for signal replication or as a common point for a signal (independent of the signals on the pin “a” terminals). Depending on the version of the terminal block, 18 or 12 common connections are available.
Page 39 Hardware and Connections Figure 2-11 2-Pin Connector and 3-Pin Connector Ordering information for the pin connectors is provided in Section A.1 of the Appendix. The design of the pin connectors is such that only correct connections can be made. For example, the design of the 2-pin connector allows connection only to pins “a” and “b”.
Page 40: Connections To Optical Communication Interfaces
Hardware and Connections 2.1.4 Connections to Optical Communication Interfaces Optical The two available versions of optical communication interfaces are shown in Figure 2- Communication 12. The ports are supplied with caps to protect the optical components against dust or Interfaces other contaminants.
Page 41: Connections To Electrical Communication Interfaces
Hardware and Connections 2.1.5 Connections to Electrical Communication Interfaces Electrical 9 pin D-subminiature female socket connectors are provided for all electrical commu- Communication nication interfaces of the 7SJ62. The connector is illustrated in Figure 2-13. The pin Interfaces assignments are described in Sub-section 8.2.1. front side rear side Figure 2-13...
Page 42: Version Of 7Sj62 For Panel Surface-Mounting
Hardware and Connections Version of 7SJ62 for Panel Surface-Mounting ® The numerical, multi-functional SIPROTEC 4 7SJ62 for panel surface-mounting is a sealed device in a 7XP20 size case (based on 19 inches) which again is installed in a housing. 2.2.1 Construction The case is inserted in a housing and secured with four screws that are located at the corners of the front panel behind the covers.
Page 43 Hardware and Connections SIPROTEC SIEMENS ERROR 7SJ62 MAIN MENU 01 / 05 Annunciation Measurement Trip MENU Pickup A Pickup B Pickup C Pickup GND Device faulty ENTER Event Log Operation. Trip Log 9 L+ L- 13 14 15 17 18 19 20 21...
Page 44: Connections To Threaded Terminals
Hardware and Connections 2.2.2 Connections to Threaded Terminals Terminal Blocks All connections including the electrical communication interfaces and the ground are made to threaded terminals on the two, double-row terminal blocks mounted on the top and bottom of the 7SJ62. The terminal blocks are shown in Figure 2-14. The ter- minals are consecutively numbered from left to right on each block.
Page 45 Hardware and Connections Laser class 1 (acc. EN 60825–1) is achieved with fiber type G50/125 µm and G62.5/125 µm. Housing for optical communication interfaces Figure 2-15 Side View of 7SJ62, Panel Surface-mounting, Optical Communication Interface For a version of the device with Profibus, the optical ports for Channel B are replaced with a D-subminiature port containing the Profibus interface.
Page 46 Hardware and Connections 2-18 7SJ62 Manual C53000-G1140-C121-1...
Page 47: Initial Inspections
Initial Inspections This section describes the first steps that should be taken upon receiving the ® SIPROTEC 4 7SJ62. Unpacking and packing is explained. Visual and electrical checks that are appropriate for initial inspection are discussed. The electrical tests include navigating through the operating menus of the device us- ing the operator control panel on the front of the device, and the operator control win- ®...
Page 48: Unpacking And Packing
Initial Inspections Unpacking and Packing The 7SJ62 is packaged at the factory to meet the requirements of IEC 60255–21. Unpacking and packing must be done with normal care, without using force, and with appropriate tools. Visually check the device immediately upon arrival for correct me- chanical condition.
Page 49: Inspections Upon Receipt
Initial Inspections Inspections Upon Receipt 3.2.1 Inspection of Features and Ratings Ordering Number Verify that the 7SJ62 has the expected features by checking the complete ordering number with the ordering number codes given in Sub-section A.1 of the Appendix. Also check that the required and expected accessories are included with the device. The ordering number of the device is on the nameplate sticker attached to the top of the case or housing.
Page 50 Initial Inspections After no more than 15 seconds, the start-up messages must vanish from the display (in which the complete ordering number, the version of firmware implemented, and the factory number are shown), and the default display must appear. Depending on the masking of the LEDs, some indicators may light up during and after power-up.
Page 51: User Interface
Initial Inspections User Interface 3.3.1 Navigating through the Operating Menus Using the Operator Control Panel Operator Control The device has a hierarchically structured operating tree, within which movements Panel and actions are made using the keys and the MENU ENTER , and keys on the front panel.
Page 52 Initial Inspections 6(783(;75$6 'DWH7LPH ²! &ORFN 6HWXS ²! 6HULDO 3RUWV ²! 'HYLFH,' ²! !0/)%9HUVLRQ ²! 0/)%9(56,21 &RQWUDVW ²! 0/)% 6-²(3 +$ %)²1U 0/)%9(56,21 )LUPZDUH %RRWV\VWHP Figure 3-2 Display of Device-specific Data (Example) Measurement To view the measured values: Viewing key.
Page 53 Initial Inspections the display will be unreadable and that no operation will be possible using the integrat- ed operator control panel. Therefore, the preset contrast value should only be changed in small steps (1 or 2 levels). key. The 0$,1 0(18 ap- When the device is ready for operation, first press the MENU pears.
Page 54: Operation Using Digsi ® 4
Initial Inspections ® 3.3.2 Operation Using DIGSI ® ® DIGSI 4 Operator DIGSI 4 has the typical PC application Windows operating environment to guide the Control Panel user. The software has a modern, intuitive, user-interface. Further details are found in ®...
Page 55 Initial Inspections Figure 3-5 Dialog Field for Data Transfer Enter the designation of the PC serial interface (COM 1,2, 3, or 4) and select in the popup list under )UDPH the transfer format, to be used in making the connection. Click on 2..
Page 56 Initial Inspections ® Figure 3-7 DIGSI 4 — Online Initial Window (Example) Measurement As an example the procedure for viewing the measured values is described. Viewing Double click on 0HDVXUHPHQW in the navigation window (left). Double click on the subdirectory 6HFRQGDU\ 9DOXHV in the navigation window. Click on 2SHUDWLRQDO YDOXHV VHFRQGDU\.
Page 57 Initial Inspections ® Figure 3-9 DIGSI 4 — Table of Secondary Operating Measured Values – Example Event Messages The readout of operating messages is described and serves as an additional example. Reading Double click on $QQXQFLDWLRQ in the navigation window. Click on (YHQW /RJ in the function selection.
Page 58 Initial Inspections Date and Time To enter the date and time: Setting Click on 'HYLFH in the menu bar. See Figure 3-11. Select 6HW &ORFN. ® 4 — Selection of the Option 6HW &ORFN Figure 3-11 DIGSI The dialog field 6HW FORFN GDWH LQ GHYLFH opens.
Page 59: Storage
Initial Inspections Storage If the device is to be stored, note: ® SIPROTEC 4 devices and associated assemblies should be stored in a dry and clean place, with a maximum temperature range of [–12 °F to 131 °F], or [–25 °C to +55 °C]. See Sub-section 10.1.7 under Technical Data.
Page 60 Initial Inspections 3-14 7SJ62 Manual C53000-G1140-C121-1...
Page 61: Siprotec 4 Devices
SIPROTEC 4 Devices ® This section provides an overview of the family of SIPROTEC 4 devices and the in- tegration of the devices into process control systems. Principle procedures are provid- ed for setting the devices, controlling primary equipment with the devices, and per- forming general operations with the devices.
Page 62: General
SIPROTEC 4 Devices General ® The SIPROTEC 4 family is an innovative product series of numerical protective and control devices with open communication interfaces for remote control and remote setting, ergonomically designed control panels, and highly flexible functionality. 4.1.1 Protection and Control The devices utilize numerical measuring techniques.
Page 63: Communication
SIPROTEC 4 Devices 4.1.2 Communication ® SIPROTEC 4 devices are completely suited for the requirements of modern commu- nication technology. They have interfaces that allow for integration into higher-level control centres, and user friendly operation through an on-site PC or via a modem con- nection.
Page 64: Settings
SIPROTEC 4 Devices Note: ® All SIPROTEC 4 devices also operate with the proven star coupler (e.g. 7XV5). Thus, for simple applications, the user can retrieve all information from the office or while on the road. 4.1.3 Settings ® The devices in the SIPROTEC 4 family are delivered with factory default settings.
Page 65: Operator Control Facilities
The operating panel contains either a full graphical display or a four-line display, de- ® pending on the specific device of the SIPROTEC 4 family. HMI with Four-Line Display SIPROTEC SIEMENS ERROR 7SA522 MAIN MENU 01/05 SIPROTEC SIEMENS ERROR...
Page 66 SIPROTEC 4 Devices The functions of the operating and display elements on the control panel are described below. Display Process and device information are displayed in the LCD. Commonly displayed infor- mation includes measured values, counter values, binary information regarding the condition of the device, protection information, general messages, and alarms.
Page 67: Digsi ® 4 Tool
SIPROTEC 4 Devices ® 4.2.2 DIGSI 4 Tool ® DIGSI 4 uses the familiar Windows operating environment. ® User Guide In DIGSI 4 only the settings that are available within a specific device are shown in the specific windows. If a protective feature is changed from disabled to enabled in the Device Configuration, then the settings relevant to that feature become available.
Page 68: Information Retrieval
SIPROTEC 4 Devices Information Retrieval ® A SIPROTEC 4 device has an abundance of information that can be used to obtain an overview of the present and past operating conditions of the device and the portion of the power system being protected or controlled by the device. The information is represented in separate groups: Annunciation, Measurements,...
Page 69: Annunciations
SIPROTEC 4 Devices 4.3.1 Annunciations The scope of the indication (messages) that are given under Annunciation is automat- ically determined when settings for the basis configuration of functions are applied to ® the SIPROTEC 4 device. ® The messages are divided into the following categories, and displayed using DIGSI or the HMI of the device: Event Log: Operational messages independent of network faults, e.g.
Page 70 SIPROTEC 4 Devices • Select 0DLQ 0HQX → $QQXQFLDWLRQ → e.g. (YHQW /RJ or 7ULS /RJ. 0$,1 0(18 !$QQXQFLDWLRQ ²! !0HDVXUHPHQW ²! $1181&,$7,21 !(YHQW /RJ ²! !7ULS /RJ ²! (9(17 /2* 5HVHW /(' ®...
Page 71: Measurements
SIPROTEC 4 Devices 4.3.2 Measurements The measured values that are registered are divided into the following categories for ® display in DIGSI 4 or on the HMI of the device: Primary values, based on the measured secondary values and the settings entered for the current transformers and voltage transformers.
Page 72 SIPROTEC 4 Devices ® Display on To display the measured values in the HMI of the SIPROTEC 4 device: the Device • Select 0DLQ 0HQX → 0HDVXUHPHQW → e.g. 2SHUDWLRQ SUL ² or 2SHUDWLRQ VHF ². 0$,1 0(18 !$QQXQFLDWLRQ ²! !0HDVXUHPHQW...
Page 73: Waveform Capture
SIPROTEC 4 Devices 4.3.3 Waveform Capture ® As an option, SIPROTEC 4 devices can have waveform capturing that includes Se- quence of Event Report (SER) for the elements in the device. Furthermore, the ele- ments that are shown in the SER can be selected by the user. ®...
Page 74: Control
SIPROTEC 4 Devices Control ® The multiple application possibilities for SIPROTEC 4 devices require an equally flexible concept for command editing and control. Remote If the device is integrated into a control system, then command outputs can be remote- ly controlled via the system interface using telegrams from SCADA or substation controller devices such as SICAM SC.
Page 75 SIPROTEC 4 Devices The status of a primary switch can be read out on the display using %5($.(56:,7&+ → 'LVSOD\ (Figure 4-10). %5($.(56:,7&+ !'LVSOD\ ²! ',63/$< !&RQWURO ²! !%UHDNHU 23(1 'LVF6ZLW &/26 Determining Primary Switch Status using the HMI Figure 4-10 ®...
Page 76: Manual Overwrite / Tagging
SIPROTEC 4 Devices Manual Overwrite / Tagging Manual Overwrite If the breaker/switch position is not available, the status of the switchgear can be man- ually set to the actual present position using the HMI: 0DLQ 0HQX → &RQWURO → %UHDNHU6ZLWFK → 0DQ 2YHUZULWH. The simulated breaker/switch position is used for interlocking checks, and for automatically initiated control operations.
Page 77: General Setting Procedure
SIPROTEC 4 Devices General Setting Procedure ® The SIPROTEC 4 devices are delivered with standard default settings. Changes to ® the settings are done with DIGSI ® The setting procedure for a SIPROTEC 4 device consists of: Overall Protection and Control Design: Determining the functions that are to be used (device configuration), Masking the binary inputs, outputs, LEDs, buffers, system port, etc.
Page 78 SIPROTEC 4 Devices /2$' 3$5$0(7(5 'RZQORDG DFWLYH Display of Device during Settings Transfer Figure 4-13 ® Setting Sequence When setting a SIPROTEC 4 device, adhere to the following sequence: Specify the interfaces, the device data, and the time synchronization, Determine the device configuration to be used, Design the masking of the inputs and outputs using the configuration matrix, Set the default display,...
Page 79 SIPROTEC 4 Devices Settings for Setting changes to individual protective elements can be done using the local HMI on ® Protective the SIPROTEC 4 device. Elements Other settings such as input/output masking and device configuration can be viewed from the front panel, but not changed. •...
Page 80: Device Configuration
SIPROTEC 4 Devices Device Configuration ® The individual devices within the SIPROTEC 4 family can be supplied with various protective functions. The ordering number of the device determines the available func- tions. The functions are specified more precisely through the process of enabling and disabling in the Device Configuration area of the settings.
Page 81: Configuration Of Inputs And Outputs (Configuration Matrix)
SIPROTEC 4 Devices Configuration of Inputs and Outputs (Configuration Matrix) A configuration matrix is used to determine processing of the binary inputs, outputs, LEDs, and indication buffers. ® Configuration is performed with DIGSI The configuration matrix is primarily divided into the following columns: Device functions with a selection field for the function settings;...
Page 82 SIPROTEC 4 Devices k4111.gif ® Figure 4-17 DIGSI 4, Input/Output Masking with the Configuration Matrix, Example Filter Function With the use of filters, either all information can be displayed or a selection can be done according to indications, commands, or measured values. Additionally, there is a filter setting that differentiates between information configured and not configured.
Page 83 SIPROTEC 4 Devices ® SIPROTEC 4 device information can be connected in a user-specified manner using ® the programmable logic components of the DIGSI 4 CFC. For example, the user can implement interlocking checks, create grouped messages, or derive limit value viola- tion messages.
Page 84: Programmable Logic Cfc
SIPROTEC 4 Devices Programmable Logic CFC ® ® The CFC program in DIGSI 4 can be used to create additional logic in SIPROTEC 4 devices. For example, special interlocking conditions for controlled equipment can be designed. Limit checks for measured values can be created, and corresponding control can be designed.
Page 85 SIPROTEC 4 Devices Figure 4-20 CFC Logic, example 4-25 7SJ62 Manual C53000-G1140-C121-1...
Page 86: Power System Data
SIPROTEC 4 Devices 4.10 Power System Data Power System In the window for Power System Data 1, important settings are entered that relate to Data 1 the power system and primary equipment connected to the device. The settings in- clude: Power system data such as frequency, voltage, etc.
Page 87: Setting Groups
SIPROTEC 4 Devices 4.11 Setting Groups ® A SIPROTEC 4 device has four setting groups A through D. The setting options for each group are the same; however, the applied settings can be, and are typically in- tended to be, different in each group. The active setting group can easily be changed while the device is in-service.
Page 88 SIPROTEC 4 Devices Settings Double click on a protective function shown in the smaller window of Figure 4-22 to obtain a window for entering the general settings associated with the function and the settings of the protective elements belonging to the function. ®...
Page 89: General Device Settings
SIPROTEC 4 Devices 4.12 General Device Settings The settings of the display to show information 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 below.
Page 90: Time Synchronization
SIPROTEC 4 Devices 4.13 Time Synchronization ® Time tracking in a SIPROTEC 4 device can be implemented using: DCF77 Radio Receiver (Time Signal from PTB Braunschweig), IRIG-B Radio Receiver (Time Signal from the global positioning satellite (GPS) sys- tem), Signals via the system interface from SCADA, for example, Radio clock using a system-specific synchronizer box, Minute impulses on a binary input.
Page 91: Serial Interfaces
SIPROTEC 4 Devices 4.14 Serial Interfaces ® Devices in the SIPROTEC 4 family can be equipped with up to three serial interfaces and a time. The system interface on the back panel of the device is used for connection to a SCADA, such as SICAM SC, The time control interface on the back panel of the device is used for time synchro- nization (e.g.
Page 92 SIPROTEC 4 Devices To set the framing and baud rate: • Double click on 6HULDO 3RUWV in the data window and enter the specific settings in the window that follows. ® Figure 4-28 DIGSI 4, Interface Settings Window ® Readout in the The interface settings can be checked using the SIPROTEC 4 device HMI.
Page 93: Passwords
SIPROTEC 4 Devices 4.15 Passwords ® Passwords are assigned to a SIPROTEC 4 device to protect against unintended changes to the device or unauthorized operations from the device, such as control. The following access levels are defined at the factory: Switching/tagging/manual overwrite, Non-interlocked switching, Test and diagnostics,...
Page 94 At delivery all passwords are set to 000000. 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. ®...
Page 95: Configuration
Configuration Configuration is the process of customizing the relay for the intended application. To accomplish this, the following questions must be answered: • Which functions are needed? • Which data and measured quantities need to be retrieved via which inputs? •...
Page 96: Configuration Of Functions
Configuration Configuration of Functions General The 7SJ62 relay contains a series of selectable protection functions as well as many other functions, based on the options purchased. The first step in configuring the relay is to determine which functions are required. Example for the configuration of functional scope: A protected system consists of overhead and underground feeders.
Page 97 Configuration ® Figure 5-1 Device Configuration Dialog Box in (example) DIGSI Before closing the dialog box, transfer the modified functional setting to the relay by clicking on the item ',*6, → 'HYLFH. The data is stored in the relay in a Non-Volatile Memory Buffer.
Page 98 Configuration Adr. Setting Setting Options Default Setting Explanation Grp Chge OPTION Disabled Disabled Setting group switching Enabled (A, B, C, D) OSC. FAULT REC. Disabled Disabled Waveform capture Enabled Charac. Phase Disabled Definite Time only Determines if definite-time (50) Definite Time only and inverse-time (51) elements Time Overcurrent Curve IEC are enabled, and the general...
Page 99 Configuration Adr. Setting Setting Options Default Setting Explanation 50BF Disabled Disabled Breaker failure protection Enabled 79 Auto Recl. Disabled Disabled Automatic reclosing Enabled Fault Locator Disabled Disabled Fault locator Enabled 74 Trip Ct Supv Disabled Disabled Trip circuit (e.g. breaker) monitor- with 2 Binary Inputs ing and method - using one with 1 Binary Input...
Page 100: Configuration Of Information, Meaured Values, And Commands
Configuration Configuration of Information, Meaured Values, and Commands General Upon delivery, the displays on the front panel of the relay, some of the function keys, the binary inputs, and the output contacts are configured to receive information. These configurations may be modified to meet your specific requirements. During configuration, certain information within the relay is automatically configured to certain physical interfaces (e.g., binary inputs and output contacts) or logical interfac- es (e.g., user-defined logic, CFC).
Page 101 Configuration Circuit Breaker Circuit Breaker (7SJ62) (7SJ62) Binary Input (BI 2) V– Binary Input (BI1) (breaker) V– (breaker) Binary Input (BI 3) Single Point Indication (SP) Double Point Indication (DP) Figure 5-3 Input Indications (SP & DP) Commands Commands (control actions) are output indications which are specially configured for the transmission of control signals to switching devices (circuit breakers, etc.).
Page 102 Configuration Table 5-1 Most Important Command Types Double Command with Single Minimum 3 without feedback C_D2 Outputs and Common Bus Output contacts with feedback CF_D2 &B' Double Command with Double With 4 contacts without feedback &)B' Outputs with feedback &B' Double Command with Double With 3 contacts without feedback...
Page 103 Configuration CLOSE TRIP Command Command C– Switching Device CLOSE TRIP C– COIL COIL V– BO 1 Relay Configuration: Figure 5-6 Double Command with Single Contacts plus Common Contact CLOSING TRIPPING Command Command C– Switching Device Switching CLOSE TRIP Device 2...n COIL COIL C–...
Page 104 Configuration CLOSING TRIP Command Command C–1 Switching Device CLOSE TRIP COIL COIL C–1 C–2 C–2 V– BO 1 Relay Configuration: Figure 5-8 Double Command with Double Contacts (with 4 Relays) CLOSING TRIP Command Command C– Switching Device CLOSE TRIP COIL COIL C–...
Page 105: Structure And Operation Of The Configuration Matrix
Configuration 5.2.2 Structure and Operation of the Configuration Matrix General This section deals with the structure and operation of the configuration matrix. The configuration matrix can be viewed without making any configuration changes. Infor- mation characteristics and configuration steps are described in Section 5.2.3, and configuration is demonstrated in Section 5.2.4.
Page 106 Configuration In the configuration matrix, not only the configuration is shown, but also the type of configuration. For example, information regarding an event which is configured for display on a LED may be latched or unlatched. The possible combinations of information and interfaces is dependent on the informa- ®...
Page 107 Configuration mation group. This is particularly useful if the information group is associated with a function that contains settings. If the information group belongs to a protective function for the relay, a dialog window can be accessed in which the settings of the protective function may be modified. The procedure for entering settings of a protective function is described in general in Chap- ter 4.
Page 108: Establishing Information Properties
Configuration − MV Measured Value − MVU Measured Value, User Defined − MVT Measured Value with time − LV Limit Value − LVU Limit Value, User Defined • Metered Values: − MVMV Metered Value of Measured Values − PMV Pulse Metered Value The information contains various properties depending on the information type, which are partially fixed and may be partially influenced.
Page 109 Configuration 5-12, and 5-13) is presented. For internal single point indications, the default status of the indication (on, off, or undefined) after device reset can be selected as well (Figure 5-12). Output Indication (OUT) Figure 5-11 Information Properties Example for the Information Type “Output Indication” (OUT) Internal Single Point Indication...
Page 110 Configuration Double Point Indi- In addition to the properties entered for single point indications, a “Suppress interme- cation (DP) diate position” check box is available, which may 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 “Filtering/Contact Chatter Suppression“...
Page 111 Configuration Figure 5-15 Information Properties Example for Information Type “Transformer Tap Chang- er” (TxTap) If none of the available encoding formats are selected, each individual tap changer po- sition may be set in a table. The table is accessed after the pull-down menu 7DEOH for encoding is opened, by selecting the button to the side.
Page 112 Configuration The three binary inputs used for this must have sequential numbers, such as BI 1, BI 2, and BI 3. Measured Values For the information type “Measured Values User Defined” (098), the units, the conver- User Defined (MVU) sion factor, and the number of significant digits following the decimal point may be and Limit Values specified.
Page 113 Configuration Figure 5-17 Information Properties Example for Information Type “Metered Value from Mea- sured Value” Figure 5-18 Information Properties Example for Information Type “Pulsed Metered Value” (PMV) The information included in the configuration matrix is determined by the relay type Entering Your Own and the configured functional scope.
Page 114 Configuration Figure 5-20 Entry of the Name of a User Defined Information Group Information may be entered into the new information group using the information cat- alog (Figure 5-21). The information catalog is found in the menu bar under the 9LHZ option, or via an icon in the toolbar.
Page 115: Performing Configuration
Configuration ton to open the context menu, and select 'HOHWH *URXS. A confirmation window will appear (Figure 5-22). Figure 5-22 Configuration Window Before Deleting a User Defined Group Click <HV if you actually want to delete the group. Note : When deleting a group, all information definitions within this group will be deleted.
Page 116 Configuration Note : A single logical indication should not be configured to two binary inputs, since an OR- link of both signals is not ensured. The operating program allows only one link, and deletes the first link when a second is established. Use CFC to perform an “25” in- stead.( In addition, a single point indication cannot be configured to a binary input and to CFC as a source at the same time.
Page 117 Configuration side of the matrix. Upon release, a new row appears in the matrix. If the mouse is po- sitioned at the intersection of this row with column F, and the right mouse button is pressed, a context menu opens (Figure 5-24) in which the function key may be set as a source by clicking the proper choice Figure 5-24 Selecting a Function Key...
Page 118 Configuration Example: Double Command with 2 Contacts (acc. Table 5-1) Figure 5-25 Window Information Catalog (Example: Different Command Types) If a command with multiple outputs is configured, all binary outputs required in the ma- trix for the configuration are automatically defined. If one of these outputs is deconfig- ured, all other binary outputs associated with the command will be automatically de- configured.
Page 119 Configuration Figure 5-26 Dialog Box - Object Properties for a Command with Feedback (Example: Double Command with Single Trip Outputs and Double Close Outputs, CF_D12) The conditional checks that should be conducted before execution of a switching com- mand can also be defined: •...
Page 120 Configuration Configuring a LED Single point indications (SP), output indications (OUT), and internal single point indi- Display as a Desti- cations (IntSP) may be configured to LEDs. When this is done, the user may select nation whether the indications are to be latched (/) or unlatched (8). Up to ten (10) indications may be configured to a LED display.
Page 121 Configuration Overview of SCADA Interfaces Table 5-3 Information Type ↓ \SCADA Interface → Profibus Protective Measurement Value Protective Measurement Value with Time (MVT) Protective Measurement Value, User Defined (MVU) Pulsed Metered Value (PMV) Metered Value from Measurement Value (MVMV) Configuring CFC Single point, double point, and output indications, as well as limit and measured val- as a Destination ues, may be configured to CFC as the destination.
Page 122 Configuration Any new user defined information is also shown in the display once loaded into the ® relay from DIGSI When selecting the 0$6.,1* ,2 menu, either binary inputs, LEDs, or binary out- puts may be selected. Selection of binary inputs is illustrated in Figure 5-27. 0$6.,1* ,2 ...
Page 123: Transferring Metering Values
Configuration Preset Configuration for LED Display Table 5-4 Descriptive Text Brief Text Message # Comments LED 5 Pickup G Non-Directional G Pickup by Ground Element Directional G Fault ΣI LED 6 Measurement Monitoring Message Failure Fault I Symmetry Fault V Symmetry Fault I Rotation Fault V Rotation...
Page 124 Configuration entered in the selection window, as shown in Figure 5-30. The selection window may be found from the open configuration matrix by clicking 2SWLRQV in the menu bar and then selecting &KDWWHU %ORFNLQJ. ® Figure 5-30 DIGSI 4: Setting the Chatter Blocking Feature Defining the Moni- The operating mode of the chatter blocking feature is determined by five settings: toring Criteria...
Page 125 Configuration ually for each binary input. See “Filtering / Contact Chatter Suppression” in Sub-sec- tion 5.2.3. Note: Chatter blocking cannot be activated for any of the standard protective indications. The following should be noted: • If there is contact chatter at a binary input and the input is blocked, the correspond- ing indication will be displayed with “CCF”...
Page 126: Creating User Defined Functions With Cfc
Configuration Creating User Defined Functions with CFC General The 7SJ62 relay is capable of implementing user defined logic functions (PLC) which may be processed by the relay. The CFC feature (Continuous Function Chart) is need- ed to process user defined protective functions and logic conditions (e.g. interlocking conditions for switching devices) or to process measured values.
Page 127 Configuration Within the Run Sequence menu, select (GLW, and then 3UHGHFHVVRU IRU ,Q VWDOODWLRQ, to ensure that the function modules selected from the library will be im- plemented into the desired task level (Figure 5-32). Figure 5-32 Assignment of Function Modules to the Selected Task Level The proper assignment is important for several reasons.
Page 128 Configuration Table 5-5 Selection Guide for Function Modules and Task Levels Task Level Function Modules Description MW_BEARB PLC1_BEARB PLC_BEARB SFS_BEARB Meter processing Slow PLC Fast PLC Interlocking RS_FF RS-Flipflop – SR_FF SR-Flipflop – TIMER Timer – – UPPER_SETPOINT Upper limit –...
Page 129 Configuration Example of an OR Lattice: Module Menu Figure 5-34 Under the 2EMHFW 3URSHUWLHV menu, the user may edit the name of the module, insert a comment, or edit run-time properties and connection parameters. Connecting modules with each other, and linking them with system input and output signals, is performed by selection of the desired modules input or output and subse- quently pressing the right mouse button, and selecting the menu option ,QVHUW &RQ QHFWLRQ WR 2SHUDQG (see Figure 5-35).
Page 130 Configuration Consistency check In addition to the sample configuration chart 1, shown in Figure 5-36, other configura- tion sheets may exist. The contents of any particular configuration sheet is compiled ® by DIGSI 4 into a program and processed by the protective device. For CFC charts developed by the user, syntactic correctness can be verified by clicking the menu command &KDUW, and then &KHFN &RQVLVWHQF\.
Page 131 Configuration ® Figure 5-37 Warning message from DIGSI 4 when 100 % of allowed memory is used After acknowledgement of the warning, the register sheet Compile under Option → 5HSRUWV can be accessed. By scrolling, an area can be reached in which statements are given regarding the memory usage, as a percentage of the portion reserved for CFC.
Page 132 Configuration • A lower limit setpoint value (IL<) is linked with the setpoint inputs of each of three limit sensor functions. • The 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 “² DODUP”.
Page 133 Configuration Function Key 4 CB is CLOSED CB is OPEN GS is CLOSED & Disconnector GS is OPEN Close IS is CLOSED IS is OPEN Door is CLOSED Figure 5-40 Interlocking an Disconnect Switch as an Example of a User Defined Interlock Protective Function Example 3 (PLC1): By using slow PLC processing, an additional, event-driven logic condition may be con-...
Page 134: Establishing A Default Display
Configuration Establishing a Default Display Under normal conditions, a preset image is shown as the default display. It shows op- erating information and/or measured values of the protected equipment. Depending on the relay type, a number of predefined basic displays are available. Using the keys, one of the displayed images may be selected (see example in the fol- lowing figure), causing it to appear as the default display under normal conditions.
Page 135: Serial Ports
(see Figure 5-43). On the other hand, for those settings that must be entered by the user, the option ,QGHSHQGHQW RI GHYLFH should be selected. The settings RQ 1 and RQ 2 are intended for Siemens use only. Please do not modify these settings.
Page 136 Configuration ® Figure 5-44 DIGSI 4, Settings for the PC Port on device ® For the IEC communication, each SIPROTEC device must have a unique IEC ad- dress assigned to it. There is a total of 254 IEC addresses available. Select an address from the pull-down menu $GGUHVV.
Page 137 Configuration ® ® Profibus FMS For a Profibus FMS connection between a SIPROTEC device and the SICAM ® Connection or DIGSI 4, a minimum transfer rate of 500 kBaud is recommended for disturbance- 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 5-45).
Page 138: Date And Time Stamping
Configuration Date and Time Stamping Integrated date and time stamping allows for the exact evaluation of sequence of events (e.g. operations or error messages, or limit violations). The following clock set- tings are available: • Internal RTC clock (Real Time Clock), •...
Page 139 Configuration ® Figure 5-48 Dialog Window for Time Synchronization and Format in DIGSI Here the user may select the time standard for internal time stamping by selecting from the following modes: Table 5-8 Operating Modes for Time Tracking Operating Mode Explanations ,QWHUQDO Internal synchronization using RTC (pre-set)
Page 140 Configuration With IRIG B, the year must be set manually, because this standard does not include a year value. Note : If a year number less than “91” is selected by mistake, the year “91” will be set upon first synchronization. For synchronization using pulses via a binary input, the present device time will ad- vance to 00 seconds of the next minute for values greater than 30 seconds when the positive slope of the pulse arrives.
Page 141 Functions ® This chapter describes the numerous functions available on the SIPROTEC 7SJ62 relay. The setting options for each function are defined, including instructions for re- porting setting values and formulas where required. General Overcurrent Protection (50, 50N, 51, 51N) 6-18 Directional Overcurrent Protection (67, 67N) 6-40...
Page 142 Functions ® Regionalization The SIPROTEC 7SJ62 devices are offered in regional versions. The prepared func- tions are adapted to the technical requirements of the regions. The user should pur- chase only the functional scope that is needed. Table 6-1 Regionalization Function Region DE Region Worldwide...
Page 143: Functions
Functions General A few seconds after the device is powered up, the default display will appear showing measured values by the 7SJ62 protective relay. The settings associated with the various device functions may be modified using the ® controls on the front panel of the device or by using the operator interface in DIGSI in conjunction with a personal computer.
Page 144 Functions Settings are selected using the keys. When the ENTER key is pressed, the user is prompted for a password. The user should enter Password No. 5 and then press the ENTER key. The current value of the setting appears in a text box, with a blink- ing text insertion cursor.
Page 145 Functions If a setting modification is not confirmed with the ENTER key, the original value reappears after one minute, and a message window appears after three minutes notifying the user that the setting modification period has expired. When the ENTER key is pressed, a further message window appears, notifying the user that the setting modifications were discarded.
Page 146 Functions ® Figure 6-5 Navigating Using DIGSI 4 — Example A dialog box associated with the selected function is displayed (e.g., if 3RZHU 6\VWHP 'DWD function is selected, the dialog box shown in Figure 6-6 will appear). If a func- tion contains many settings, the dialog box may include multiple windows.
Page 147 Functions or numerical format. When the mouse cursor is positioned over a numerical field in the 9DOXH column, the allowable range is shown. To modify a setting, the user must click on the setting value which is displayed in the 9DOXH column.
Page 148: Power System Data 1
Functions Each entry may be confirmed by clicking $SSO\. Valid values are accepted automat- Confirmation ically when another field is selected. The final acceptance of a modified setting takes place once setting modification mode is exited (see below “Exiting the Setting Modification Mode”). The dialog box may be closed by clicking 2..
Page 149 Functions At addresses 9QRP 35,0$5< and 9QRP 6(&21'$5<, information is en- VT’s and CT’s Nominal Values tered regarding the rated primary nominal voltage and rated secondary nominal volt- ages (L-L) of the connected voltage transformers. At addresses &7 35,0$5< and &7 6(&21'$5<, information is entered regarding the primary and second- ary ampere ratings of the current transformers.
Page 150 Functions 300 5 ⁄ Address 0207 ---------------- - 0.600 500 5 ⁄ Address corresponds to the factor by which the sensitive ground current (I must be adjusted relative to the phase current. • In models with sensitive ground current detection where an independent current transformer is used to supply I (Appendix Section A3, Figures A-9 and A-10), ad- dress is set equal to the ratio of the neutral current transformer ratio to the...
Page 151: Settings
Functions Address 97 &RQQHFWLRQ specifies how the voltage transformers are connect- Voltage Connection ed. When the voltage transformers are connected in a wye configuration, address is set at 9DQ, 9EF, 9FQ. When the voltage transformers are connected as shown in Figure A-12 of Appendix Section A.3, address should be set at 9DE, 9EF, 9*QG.
Page 152: Information
Functions Addr. Setting Setting Options Default Setting Comment VT Connection Van, Vbn, Vcn Van, Vbn, Vcn Transformer connection Vab, Vbc, VGnd Rated Frequency 50 Hz 60 Hz Nominal frequency 60 Hz Distance Unit Kilometers Miles Distance units for fault location Miles ) depending of the ordering code, please refer to Table 6-1 6.1.1.2...
Page 153 Functions ® Figure 6-9 Copying a Setting Group in DIGSI The next step is to highlight the name of setting group in the list into which the setting values should be copied. The user should go to the menu bar, click on (GLW and select 3DVWH.
Page 154: Power System Data 2
Functions After copying setting groups, it is only necessary to modify those setting values that are to be set differently. Restoring Factory The factory settings may be restored for a modified setting group. To restore factory Settings settings to a setting group, the name of the setting group whose settings are to be re- stored should be highlighted.
Page 155 Functions At addresses 9 35,0$5< 23 and , 35,0$5< 23, the nominal volt- Definition of nomi- nal rated values age (phase-to-phase) and current (phase) of the protected equipment is entered (e.g., motors). These values do not effect pickup settings. They are generally used to show values in reference to full scale.
Page 156 Functions The reactance value is entered as a secondary value at address in ohms per mile if address is set to Miles, or at address in ohms per kilometer if ad- dress is set to Kilometers (see Subsection 6.1.1 under “Units of Length”). If the setting of address is modified after entry of a reactance value at address or , the reactance value must be modified and reentered accordingly.
Page 157: Settings
Functions • Because the thermal cure of the overload protection is “frozen” (held constant) dur- ing motor start-up, the setting must be high enough to allow operation of the over- load protection at higher load current levels. 6.1.3.1 Settings In the list below, the setting ranges and default setting values are for a device with a nominal current rating I = 5 A.
Page 158: Overcurrent Protection (50, 50N, 51, 51N)
Functions Overcurrent Protection (50, 50N, 51, 51N) General Time-overcurrent protection is the main protective function of the 7SJ62 relay. It may be enabled or disabled for phase or ground faults, and may be configured with various time-overcurrent characteristic curves. There are four definite time (Instantaneous elements with optional timers) and two in- verse time-overcurrent elements in the device.
Page 159 Functions The dropout value of the definite time, time-overcurrent elements is roughly equal to 95 % of the pickup value for currents greater than or equal to 30 % of the nominal cur- rent of the device. Figure 6-12 shows the logic diagram for the 50-1 and 50N-1 protection. Pickup and delay settings for the 50-1, 50-2, 50N-1, and 50N-2 elements may be in- dividually programmed.
Page 160 Functions ! "ÃH6IV6GÃ8GPT@Ã Dhp‡v‰r $ Ãv†‡ $ Ãv†‡ “1“ $!Ãv†‡ & Ã Manual Close φ 50-2 PU F# 1800 50-2 picked up & !"Ã$!Ã F# 1805 50-2 Trip & F# 1804 50-2 Time Out Phase Measurement On/Off 7y‚px 79 50-2 F# 1721 >BLOCK 50-2 Int.
Page 161 Functions ! "ÃH6IV6GÃ8GPT@ Dhp‡v‰r $ Ãv†‡ $!Ãv†‡ “1“ $ Ãv†‡ Inrush Recognition (see Figure 6-31) & Manual Close F# 7551 φ 50-1 PU & 50-1Inrush PU F# 1810 & 50-1 picked up & F# 1815 !$Ã$ & 50-1 TRIP F# 1814 50-1 TimeOut Phase Measurement On/Off...
Page 162: Inverse Time-Overcurrent Protection (51, 51N)
Functions 6.2.1.2 Inverse Time-Overcurrent Protection (51, 51N) Inverse time-overcurrent protection, the 51 and 51N relay elements may contain IEC characteristic curves or ANSI characteristic curves depending on the model ordered. A user-specified curve may also be applied to the inverse-overcurrent relay elements. The curves and associated formulas are given in Technical Specifications (Figures 10- 1 to 10-3 in Section 10.3).
Page 163 Functions relay element then approximates the curve using linear interpolation. When utilizing user specified time-current curves, the reset curve may user specified as well. This is advantageous when the inverse time, time-overcurrent protection must be coordinated with conventional electromechanical overcurrent relays located toward the source.
Page 164 Functions ! "ÃH6IV6GÃ8GPT@ Dhp‡v‰r $!Ãv†‡ $ Ãv†‡ “1“ $ Ãv†‡ Inrush Recognition (see Figure 6-31) & Manual Close F# 7553 φ 51 A & 51 InRush PU F# 1820 & 51 picked up & F# 1825 !(Ã$ ÃU9 & 51 TRIP F# 1824 51 TimeOut Phase Measurement...
Page 165: Reverse Interlocking Bus Protection
Functions 6.2.1.3 Reverse Interlocking Bus Protection Application Exam- The pickup of a time-overcurrent relay element may be blocked via binary inputs. At the users option, the binary inputs can be set up to block tripping when DC voltage is applied or when DC voltage is removed. Reverse interlocking allows for faster protec- tion by eliminating the need for time-current coordination.
Page 166: Programming Time-Overcurrent Settings
Functions Normal Load Flow 50-1 50-2 50-1 50-1 ´$!Ã7y‚px´ 50-1 50-2 TRIP TRIP TRIP TRIP 50-1 50-2 Fault Location B: Source-side Trip Time = T = Source side 50-2 Delay 50-2 Fault Location A: Load-side Trip Time = t Source-side Backup Trip Time = T =Source-side 50-1 Delay 50-1 Figure 6-14...
Page 167 Functions pickup and delay such that operation of the 50-2 element will coordinate with other protective equipment in the system. Below is an example of how a 50-2 relay element might be set to protect a power transformer in a radial distribution system against high magnitude internal faults: Example: Transformer used to supply distribution bus with the following data: Base Transformer Rating 16 MVA...
Page 168 Functions bus feeder breakers. The 50-1 element or 51 element will serve as redundant protec- tion for the bus. The pickup values of both the 50-2 unit and the 50-1 or 51 unit are set equal to each other. The time delay associated with the 50-1 or 51 element is then time-coordinated with the individual bus feeder devices.
Page 169 Functions The pickup of the 51 element is set at address 3,&.83. As is the case for the 50-1 relay element, the pickup value of the 51 relay element should be set above the maximum anticipated load current. Pickup due to overload should never occur since the 51 relay element is designed only for fault protection.
Page 170 Functions When reclosing occurs, it is desirable to have high speed protection against temporary faults. With address set to ZLWK DFWLYH, the 50-2 elements may be set for high speed tripping. If the fault still exists after the first reclose, the 50-2 elements can be blocked and the 50-1 and/or 51 elements will provide time delay tripping.
Page 171 Functions ® Figure 6-17 Visualization of a User Specified Characteristic Curve in DIGSI If address was set to 8VHU 'HILQHG 3LFNXS &XUYH or 8VHU 'HILQHG 3LFNXS DQG 5HVHW &XUYH during configuration of the user-specified curve option, a maximum of 20 value pairs (current and time) may be entered at address 1 to represent the time-current characteristic curve associated with the 51 element.
Page 172: Settings For Phase Overcurrent Protection
Functions The time and current value pairs are entered at address to recreate the drop- down curve. The following must be observed: Reset Curve Characteristic Curve Largest Current Point Smallest Current Point Largest Current Point Smallest Current Point 0.05 0.9 1 1.1 Figure 6-18 Use of a User-Specified Curve...
Page 173 Functions Addr. Setting Title Setting Options Default Setting Comments Configuration 1202 50-2 PICKUP 0.50 ~ 175.00 A 10.00 A Pickup setting of the 50-2 X X X X X element 1203 50-2 DELAY 0.00 ~ 60.00 sec 0.00 sec Delay setting of the 50-2 X X X X X element 1204 50-1 PICKUP...
Page 174: Information List For Phase Overcurrent Protection
Functions 6.2.2.3 Information List for Phase Overcurrent Protection LCD-Text Comment 1761 50(N)/51(N) PU 50(N)/51(N) O/C GENERAL PICKUP 1791 50(N)/51(N) GENERAL TRIP (N)/51(N)TRIP LCD-Text Comment 1751 50/51 PH OFF 50/51 O/C switched OFF 1752 50/51 PH BLK 50/51 O/C is BLOCKED 1753 50/51 PH ACT 50/51 O/C is ACTIVE...
Page 175 Functions with phase protection. Because of this, relay coordination for ground faults is indepen- dent of relay coordination for phase faults, and more sensitive settings can often be applied to ground protection. The pickup and delay of the 50N-2 relay element are set at addresses 1 50N-2 Relay Ele- 3,&.83 and 1 '(/$<...
Page 176 Functions The pickup of the 51N element is set at address 1 3,&.83. As is the case for the 50N-1 relay element, the pickup value of the 51N relay element should be set below the minimum anticipated ground fault current in the relay’s zone of protection. The corresponding time dial is set at address 1 7,0( ',$/ and should be based on system coordination requirements.
Page 177: Settings For Ground Overcurrent Protection
Functions 6.2.2.5 Settings for Ground Overcurrent Protection In the list below, the setting ranges and default setting values for the pickup currents are for a device with a nominal current rating I = 5 A. For a nominal current rating I = 1 A, divide the Setting Options values and Default Setting values by 5.
Page 178: Information List For Ground Overcurrent Protection
Functions Addr. LCD-Text Setting Options Default Setting Comments Configuration 1313 MANUALCLO 50N-2 50N-2 Selection of high speed tripping X X X X X SEMODE Instantaneously Instantaneously element when manual closing 50N-1 feature is used Instantaneously Instantaneously Inactive 1314 50N-2 active Always Always Criteria for operation of 50N-2...
Page 179 Functions LCD-Text Comment 1856 51N BLOCKED 51N BLOCKED 1714 >BLK 50N/51N >BLOCK 50N/51N 1724 >BLOCK 50N-2 >BLOCK 50N-2 1725 >BLOCK 50N-1 >BLOCK 50N-1 1726 >BLOCK 51N >BLOCK 51N 6-39 7SJ62 Manual C53000-G1140-C121-1...
Page 180: Directional Overcurrent Protection (67, 67N)
Functions Directional Overcurrent Protection (67, 67N) General The 7SJ62 features directional overcurrent protection. Therefore, this device can be applied to systems where proper protection depends on knowing both the magnitude of the fault current and the direction of energy flow to the fault location. Directional overcurrent protection requires that the device be connected to both current trans- formers and voltage transformers.
Page 181 Functions Direction of Lastfluß- Load Flow richtung Time-Overcurrent Protection Überstromzeitschutz Directional Overcurrent Protection gerichteter Überstromzeitschutz Figure 6-19 Overcurrent Protection for Parallel Transformers Time-Overcurrent Protection Überstromzeitschutz Directional Overcurrent Protection gerichteter Überstromzeitschutz Figure 6-20 Transmission Lines with Sources at Each End All directional overcurrent elements, inverse and definite time, enabled in the device may be blocked via an external signal to the binary inputs of the device.
Page 182: Description Of Directional Overcurrent Protection
Functions Tripping by the 67-1, 67-TOC, 67N-1, and 67N-TOC elements may beblocked for in- rush conditions by utilizing the inrush restraint feature (see Section 6.5). 6.3.1 Description of Directional Overcurrent Protection 6.3.1.1 Definite Time, Directional Overcurrent Protection The 67-2 and 67N-2 directional overcurrent elements, phase and ground currents are compared separately with the pickup values of the 67-2 and 67N-2 relay elements.
Page 183 Functions $ "ÃH6IV6G8GPT@HP9@ Dhp‡v‰r %&UP8Ãv†‡ %& Ãv†‡ “1“ %&!Ãv†‡ & Manual Close φ 67-2 PU F# 2642 67-2 picked up & $"Ã%&!Ã F# 2649 67-2 TRIP & F# 2647 67-2 TimeOut Phase Measurement On/Off 79 67-2 Block F# 2615 >BLOCK 67-2 Int.
Page 184: Inverse Time, Directional Overcurrent Protection (67-Toc, 67N-Toc)
Functions $ "ÃH6IV6G8GPT@HP9@ Dhp‡v‰r %&!Ãv†‡ %&UP8Ãv†‡ “1“ %& Ãv†‡ & Inrush Recognition (see Figure 6-31) Manual Close F# 7559 φ 67-1 PU 67-1InRush PU & F# 2660 67-1 picked up & & $$Ã%& F# 2665 & 67-1 TRIP F# 2664 Direction Determination 67-1 TimeOut F# 2628...
Page 185: Determination Of Direction
Functions pickup, the time delay of the trip signal is calculated using an integrated measurement process. The calculated time delay is dependent on the actual fault current flowing and the selected time-current characteristic curve. Once the time delay elapses, a trip sig- nal is issued.
Page 186 Functions ground, phase-to-phase, and double phase-to-ground faults, sufficient voltage magni- tude is available at the relay location to determine direction for all possible fault loca- tions. For three-phase faults, stored voltage values are used to determine direction un- less sufficient voltage magnitudes exists at the relay location. The stored voltage val- ues correspond to the voltage magnitudes and angles during the last two cycles where sufficient voltage magnitude was available to determine direction.
Page 187 Functions a) Phase to Ground Fault (a-g) b) Phase to Phase Fault (a-c) Figure 6-23 Voltages Used for Direction Determination Table 6-2 shows the assignment of voltage and current values for the determination of fault di- rection for various types of short-circuit faults. Table 6-2 Voltage and Current Values for the Determination of Fault Direction GROUND...
Page 188: Reverse Interlocking For Looped Lines
Functions views an impedance which lies on the same of the directional limit line as the shaded area, the fault is assumed to be in the forward direction. For a phase-to-phase fault, the actual directional limit line will deviate from the theo- retical when the fault location is different than the relay location because the polarizing voltage angle varies with fault location (see Figure 6-23b).
Page 189: Programming Directional Overcurrent Settings
Functions a fault in the reverse direction, the directional overcurrent element that detects faults in the reverse direction will block the high-speed operation of the non-directional over- current element at the opposite end of the line. The relay at the opposite end of the line is generally located at a different substation, thus blocking is accomplished via the pilot wires.
Page 190 Functions panying addresses appear in the overview of setting groups only when the functions are configured as present (Section 5.1). The functions may be enabled by selecting a time characteristic(i.e. Definite, ANSI, or User-Defined) during configuration. The functions associated with directional overcurrent protection were established dur- ing configuration of protective functions (Section 5.1) at address 72&.
Page 191 Functions The pickup of the 67-TOC element is set at address 72& 3,&.83. As is the case for the 67-1 relay element, the pickup value of the 67-TOC relay element should be set above the maximum anticipated load current. Pickup due to overload should never occur since the 67-TOC relay element is designed only for fault protection.
Page 192 Functions At address DFWLYH, it can be specified whether or not the 67-2 elements Interaction with Automatic should be supervised by the status of internal or external automatic reclosing device. If address is set to :LWK $FWLYH, the 67-2 elements will not operate unless Reclosing automatic reclosing is enabled.
Page 193 Functions 1.00 to simplify the calculation of these ratios. Once the curve is entered, the settings at addresses and may be modified if necessary. Upon delivery of the device, all time values are set at ∞, preventing pickup of the de- vice from initiating a trip signal.
Page 194: Settings For Directional Phase Overcurrent Protection
Functions 6.3.2.2 Settings for Directional Phase Overcurrent Protection In the list below, the setting ranges and default setting values for the pickup currents are for a device with a nominal current rating I = 5 A. For a nominal current rating I = 1 A, divide the Setting Options values and default setting values by 5.
Page 195 Functions Addr. LCD-Text Setting Options Default Setting Comments Configuration 1515 Normal Load Inductive (135°) Inductive (135°) Angle of the directional limit line X X X X X (Torque angle of Resistive (90°) dir. Fct) Capacitive (45°) 1516 67 Direction Forward Forward Directional orientation of the 67 X X X X X...
Page 196: Information List For Directional Phase Overcurrent Protection
Functions 6.3.2.3 Information List for Directional Phase Overcurrent Protection LCD-Text Comment 2691 67/67N picked up 67/67N picked up 2696 67/67N TRIP 67/67N TRIP 2651 67/67-TOC OFF 67/67-TOC switched OFF 2652 67 BLOCKED 67/67-TOC is BLOCKED 2653 67 ACTIVE 67/67-TOC is ACTIVE 2642 67-2 picked up 67-2 picked up...
Page 197: Programming Settings For Directional Overcurrent Ground Protection
Functions 6.3.2.4 Programming Settings for Directional Overcurrent Ground Protection General The functions associated with time-overcurrent protection were established during configuration of protective functions (Section 5.1) at address 1172&. If address was set to 'HILQLWH 7LPH 2QO\, then only the settings for the defi- nite-time elements are available.
Page 198 Functions The time multiplication factor may also be set to ∞. The 67N-TOC element will then pickup and generate a message, but will never trip. If the 67N-TOC element is not re- quired at all, address should be set to 'HILQLWH 7LPH 2QO\ during protective function configuration (see Section 5.1).
Page 199: Settings For Directional Ground Overcurrent Protection
Functions If address 1172& was set to 8VHU 'HILQHG 3LFNXS &XUYH or 8VHU User Specified 'HILQHG 3LFNXS DQG 5HVHW &XUYH during configuration of the user-specified Curves curve option, a maximum of 20 value pairs (current and time) may be entered at ad- dress 0RI 38 7' to represent the time-current characteristic curve associated with the 67N-TOC element.
Page 200: Information List For Directional Ground Overcurrent Protection
Functions Addr. LCD-Text Setting options Default Setting Comments Configuration 1609 67N–TOC T– DIAL 0.50 ~ 15.00 5.00 sec Time dial setting, ANSI 1610 67N–TOC RESET immediate Disk emulation Characteristics of 67N- disk emulation TOC dropout 1611 67N-TOC IEC Normal Inverse Normal Inverse Characteristic curve (IEC) Very Inverse...
Page 201 Functions LCD-Text Comment 2679 67N-2 TRIP 67-2 TRIP 2681 67N-1 picked up 67N-1 picked up 2683 67N-1 TRIP 67N-1 TRIP 2684 67N-TOCPickedup 67N-TOC picked up 2686 67N-TOC TRIP 67N-TOC TRIP 2695 67N picked up 67N/67N-TOC picked up 2648 67N-2 Time Out 67N-2 Time Out 2682 67N-1 Time Out...
Page 202: Dynamic Cold Load Pick-Up Function (50C, 50Nc, 51Nc, 67C, 67Nc)
Functions Dynamic Cold Load Pick-Up Function (50c, 50Nc, 51Nc, 67c, 67Nc) General With the dynamic cold load pick-up feature, it is possible to dynamically increase the pickup values of the directional and non-directional overcurrent relay elements when dynamic cold load pickup conditions are anticipated (i.e. after a long period of zero voltage).
Page 203 Functions If a relay element picks up while the dynamic settings are enabled, elapse of the $F WLYH 7LPH or 6WRS 7LPH will not restore the normal pickup settings until drop out of the relay element occurs based on the dynamic settings. If the dynamic cold load pick-up function is blocked via a binary input, all triggered tim- ers will be immediately reset and all normal settings will be restored.
Page 204: Programming Settings
Functions F# 1730 F# 1995 CLP BLOCKED > BLOCK CLP F# 1996 & Ã8PG9GP69ÃQD8FVQ CLP running F# 1994 CLP OFF “1“ 52a Configured & 52b Configured Measurement/Logic F# 4601 >52-a &"Ã87ÃPƒrÃUv€r Circuit- F# 4602 Breaker & Closed >52-b &!ÃT‡h…‡Ã8‚qv‡v‚ 7…rhxr…Ã8‚‡hp‡ I‚Ã8ˆ……r‡...
Page 205: Settings For Dynamic Cold Load Adjustments
Functions Non-Directional The dynamic pickup values and time delays associated with non-directional overcur- Elements rent phase protection are set at address block 18. The dynamic pickup and delay settings for the 50-2 element are set at addresses F 3,&.83 and F '(/$< respectively; the dynamic pickup and delay settings for the 50-1 element are set at addresses F 3,&.83 and F '(/$<...
Page 206 Functions Addr. Setting Setting Options Default Setting Comment Configuration 1701 COLD LOAD Dyn. Cold Load Setting Adj. On/Off X X X X X PICKUP 1702 Start Condition No Current No Current Dyn. Cold Load Setting Adj. Arming X X X X X Breaker Contact Condition 1703...
Page 207 Functions Addr. Setting Setting Options Default Addr. Normal Setting Configuration Setting 1905 51Nc PICKUP 0.50 ~ 20.00 A 5.00 A 1307 51N PICKUP X X X X 1906 51Nc T-DIAL 0.05 ~ 3.20 sec. 0.50 sec. 1308 51N TIME DIAL, IEC 1907 51Nc T-DIAL 0.5 ~ 15.00...
Page 208: Information List For Dynamic Cold Load Setting Adjustments
Functions 6.4.2.2 Information List for Dynamic Cold Load Setting Adjustments LCD-Text Comment 1994 CLP OFF Cold-Load-Pickup switched off 1995 CLP BLOCKED Cold-Load-Pickup is blocked 1996 CLP running Cold-Load-Pickup is running 1997 Dyn set. ACTIVE Dynamic settings are active 1730 >BLOCK CLP >Block Cold-Load-Pickup 1731 >BLK CLP stpTim...
Page 209: Inrush Restraint
Functions Inrush Restraint General When the 7SJ62 relay is installed to protect a power transformer, large magnetizing inrush currents will flow when the transformer is energized. These inrush currents may be several times the nominal transformer current, and, depending on the transformer size and design, may last from several milliseconds to several seconds.
Page 210 Functions es. This is referred to as cross-blocking and can be enabled at address . Inrush currents flowing in the ground path will not cross-block tripping by the phase elements. The cross-blocking function may also be limited to a particular time interval, which can be set at address .
Page 211: Programming Settings
Functions The maximum current , 0D[ where inrush restraint can operate is set at address ,f energizing the protected equipment results in a current that exceeds the , 0D[ Vetting value, inrush restraint based on detection of second harmonic currents will no longer occur.
Page 212: Information List For Inrush Restraint (Stabilization)
Functions 6.5.2.2 Information List for Inrush Restraint (Stabilization) LCD-Text Comment 1840 PhA InrushBlk Phase A trip blocked by inrush detection 1841 PhB InrushBlk Phase B trip blocked by inrush detection 1842 PhC InrushBlk Phase C trip blocked by inrush detection 1843 INRUSH X-BLK Cross blk: Ph Cross blocked PhY...
Page 213: Sensitive Ground Fault Detection (64, 50Ns, 67Ns)
Functions Sensitive Ground Fault Detection (64, 50Ns, 67Ns) General Sensitive ground fault detection may be used in isolated or compensated systems to detect ground faults. In solidly or low-resistance grounded systems, sensitive ground fault detection is used to detect high impedance ground faults. Sensitive ground fault detection may be used for alarming and annunciation, or may be allowed to initiate tripping.
Page 214: Current Elements
Functions the voltage magnitudes of the other two phases are simultaneously above the setting value entered at address 93+ 0$;. 6.6.1.2 Current Elements The current elements associated with sensitive ground fault detection typically operate for low magnitudes of zero sequence current. They are typically applied in systems where ground fault currents are limited by neutral resistors.
Page 215 Functions be in the opposite direction (reverse direction). This method it typically used to deter- mine the direction of ground connections in an ungrounded system. Curves Figure 6-32 illustrates the directional characteristic of the sensitive ground fault detec- tion function using a complex vector diagram in which the displacement voltage V the reference magnitude.
Page 216 Functions Implementation In- In an ungrounded system, the reactive component of the current should be used to structions determine the direction. In a grounded system, the real component of the current should be used to determine the direction. Therefore, in an ungrounded system, ad- dress should be set for 6,1 3+, measurement whereas in a grounded system, address should be set for &26 3+, measurement.
Page 217 Functions " &ÃWQCÃH6Y " %ÃWQCÃHDI " "ÃQVÃ8SDU@SD6 WtqÃ6I9ÃDI† V< V> WtqÃPSÃDI† „1“ V< F# 1272 Sens.Gnd Ph A PU & V> F# 1273 V< Sens.Gnd Ph B PU & V> F# 1274 Sens.Gnd Ph C PU & V< F# 1271 V>...
Page 218: Location Of Ground Connections
Functions Generation of a tripping message, for both current and voltage elements, is dependent on the direction selection for each element. If the element is set to QRQGLUHFWLRQ DO, then exceeding the current element pickup setting causes a corresponding mes- sage, independent of the condition of the V element.
Page 219: Programming Settings
In the rare event that this protective relay is utilized in a compensated system, the reader should contact Siemens Power T&D for more infor- mation regarding application of the 7SJ62 relay in a compensated system.
Page 220 Functions ement is a condition for initiation of directional determination. Depending on the setting at 97 &RQQHFWLRQ, only the applicable limit value at address or is accessible. That is, if two phase-to-phase voltages and the displacement voltage V are supplied to the device, the measured displacement voltage is used directly for is programmed at address , where ground fault recognition.
Page 221 Functions − Address = FRV ϕ: the real component of the zero sequence current with re- Ã spect to the displacement voltage (the component of 3I in phase with V or 3V ) is evaluated by the setting at address (see Figure 6-32); −...
Page 222 Functions General The following is valid for determination of direction during ground faults: The minimum current for directional determination entered at address must be set as high as possible so as not to be a false limit of the device during the flow of asymmetrical cur- rents in the system.
Page 223: Settings For Sensitive Ground Fault Detection
Functions T/Tp Anregekennlinie: Pickup Curve Smallest Current Point kleinster Kennlinienpunkt Largest Current Point größter Kennlinienpunkt 1 1.1 I/Ip Figure 6-39 Use of a User Defined Curve 6.6.2.1 Settings for Sensitive Ground Fault Detection The current-based setting ranges and Default Setting values are independent of the nominal current rating of the device.
Page 224 Functions Addr. LCD-Text Setting options Default Setting Comment Configu- ration 3106 VPH MIN 10 ~ 100 V 40 V Voltage of faulty phase Vph min 3107 VPH MAX 10 ~ 100 V 75 V Voltage of phase Unfaulted Vph max 3109 1.8 ~ 130.0 V 40.0 V...
Page 225: Information List For Sensitive Ground Fault Detection
Functions 6.6.2.2 Information List for Sensitive Ground Fault Detection LCD-Text Comment 1211 50Ns/67Ns OFF 50Ns/67Ns is OFF 1212 50Ns/67Ns ACT 50Ns/67Ns is ACTIVE 1215 64 Pickup 64 displacement voltage pick up 1217 64 TRIP 64 displacement voltage element TRIP 1221 50Ns-2 Pickup 50Ns-2 Pickup 1223...
Page 226: Negative Sequence Protection (46)
Functions Negative Sequence Protection (46) General Negative sequence protection detects unbalanced loads on the system. In addition, it may be used to detect interruptions, faults, and polarity problems with current trans- formers. It is particularly useful in detecting phase-to-ground, phase-to-phase, and double phase-to-ground faults with magnitudes lower than the maximum load current.
Page 227: Inverse Time Element (46-Toc)
Functions Tripping Area Auslösebereich > 46-1 >> 46-2 > >> 46-1 46-2 Figure 6-40 Definite Time Characteristic for Negative Sequence Protection 6.7.1.3 Inverse Time Element (46-TOC) The inverse time element is designated 46-TOC and can operate with IEC or ANSI characteristic tripping curves depending on the model ordered.
Page 228 Functions Schieflast- Warnstufe I 2> Negative Sequence Warning Level 46-1 I2> Auslösebereich Tripping Area thermische Thermal Protection Auslösestufe Schieflast- Severe Imbalance Auslösestufe I 2>> Protecion 46-2 I2>> 46-1 46-2 >> > 1,1 x I Figure 6-41 Inverse Time Characteristic for Negative Sequence Protection F# 5166 46-TOC picked up #&Ã#%Ã6ITDÃ8VSW@...
Page 229: Programming Settings
Functions Logic Figure 6-42 shows the logic diagram for negative sequence protection. The protection may be blocked via a binary input. When the negative sequence protection criteria are no longer satisfied (i.e. all phase currents drop below 10 % of the nominal relay current or at least one phase current is greater than four (4) times the nominal device current, the tripping time delay is imme- diately reset.
Page 230 Functions interpreted as a phase-to-phase fault, the time delay of this element should be coor- dinated with fault protection relays. The magnitude of the negative sequence current with respect to the phase current when one phase is out of service is given as follows: ------ - I ⋅...
Page 231: Settings For Negative Sequence (Phase Balance) Current Protection
Functions If the pickup setting (PU) of the device on the high side is set to 0.1 A, then a phase- to-ground fault current of I = (1/0.33) * CTR * PU * V 3 * 100 * 0.1 A * 110 kV / 20 kV = 165 A and a phase-to-phase fault current of I = (1/0.58) * CTR * PU * V 1.732 * 100 * 0.1 A * 110 kV / 20 kV = 95 A...
Page 232 Functions = 1 A, divide the Setting Options values and Default Setting values by 5. Consider the current transformer ratios when setting the device with primary values. Addr. LCD-Text Setting Options Default Setting Comments Configu- ration 4001 FCT 46 Negative sequence current X X X protection 4002 46-1 PICKUP...
Page 233: Information List For Negative Sequence Current Protection
Functions 6.7.2.2 Information List for Negative Sequence Current Protection LCD-Text Comment 5151 46 OFF 46 switched OFF 5152 46 BLOCKED 46 is BLOCKED 5153 46 ACTIVE 46 is ACTIVE 5159 46-2 picked up 46-2 picked up 5165 46-1 picked up 46-1 picked up 5166 46-TOC pickedup...
Page 234: Motor Starting Protection (48)
Functions Motor Starting Protection (48) 6.8.1 Description of Motor Starting Protection General When the 7SJ62 relay is used to protect a motor, the starting time monitoring feature supplements the overload protection described in Section 6.9 by protecting the motor against the potential damage that might result from frequent starting or extended start- ing durations.
Page 235 Functions TRIP Amax MOT ANL MOT START Figure 6-43 Inverse Time Characteristic Tripping Curve for Motor Starting Current Therefore, if the starting current I actually measured is smaller (or larger) than the entered at address 67$5783 &855(17, the actual nominal starting current I tripping time t is lengthened (or shortened) accordingly.
Page 236: Programming Settings
Functions Fault Cond. F# 6823 φ START-SUP PU Pickup A # !ÃTU6SUVQÃ8VSS@IU # "ÃTU6SUVQÃUDH@ F# 6821 START-SUP TRIP # #ÃGP8FÃSPUPSÃUDH@ F# 6822 Rotor locked & φ Hrh†ˆ…r€r‡Ã hqÃU…vƒƒvtÃG‚tvp F# 6805 >Rotor locked F# 6801 F# 6812 START-SUP BLK >BLK START-SUP # ÃA8UÃ#'%% „1“...
Page 237: Settings For Motor Starting Time Monitoring
Functions The setting at address , 02725 67$57 must lie above the maximum load cur- rent and below the minimum start-up current. If no other influencing factors are present (peak loads), the value set at address may be a median value: 135 A ⋅...
Page 238: Information List For Motor Starting Time Monitoring
Functions 6.8.2.2 Information List for Motor Starting Time Monitoring LCD-Text Comment 6811 START-SUP OFF Startup supervision OFF 6812 START-SUP BLK Startup supervision is BLOCKED 6813 START-SUP ACT Startup supervision is ACTIVE 6821 START-SUP TRIP Startup supervision TRIP 6822 Rotor locked Rotor locked 6823 START-SUP pu...
Page 239: Thermal Overload Protection (49)
Functions Thermal Overload Protection (49) 6.9.1 Description of Thermal Overload Protection General The thermal overload protection feature of the 7SJ62 is designed to prevent overloads from damaging the protected equipment. The device is capable of projecting excessive operating temperatures for the protect- ed equipment in accordance with a single-body thermal model, based on the following differential equation: dΘ...
Page 240 Functions the motor currents drop below a programmable minimum current setting (refer to “Cur- rent Flow Monitoring” in Subsection 6.1.1). For externally-cooled motors, cables, and transformers, the Nτ )$&725 = . Blocking The thermal overload protection feature may be blocked via a binary input. When blocking occurs, the thermal image is simultaneously reset.
Page 241: Programming Settings
Functions #!!Ã#(ÃFA68UPS #!$ÃDÃ6G6SH #!"ÃUDH@Ã8PITU6IU F# 1515 49 O/L I Alarm I > dΘ #!#Ã#(Ã Ã6G6SH Θ -- - Θ ⋅ ⋅ ------- - -- - I τ τ F# 1516 Θ 49 O/L Θ Alarm φ > Θ = const. Θ...
Page 242 Functions The short time delays associated with fault protection elements do not allow sufficient time for the orderly curtailment of load by operating personnel. In addition, fault pro- tection elements set to trip for overload will not allow short-duration, non-damaging overloads –...
Page 243 Functions Time Constant τ The thermal overload protection element tracks excessive temperature progression, employing a thermal differential equation whose solution is an exponential function. The 7,0( &2167$17 τ (set at address ) is used in the calculation to determine the operating temperature. This is expressed as a maximum allowable operating tem- perature.
Page 244: Settings For Thermal Overload Protection
Functions culated operating temperature falls below the warning level, thus allowing the protect- ed equipment to be placed back into service. The thermal warning level is given in % of the tripping temperature level (maximum allowable operating temperature). A current warning level is also available (, $/$50 ). The setting at address corresponds to secondary amperes, of course, and should be set equal to, or slightly less than, permissible continuous current (k * I .
Page 245: Information List For Thermal Overload Protection
Functions 6.9.2.2 Information List for Thermal Overload Protection LCD-Text Comment 1511 49 O / L OFF 49 Overload Protection is OFF 1512 49 O/L BLOCK 49 Overload Protection is BLOCKED 1513 49 O/L ACTIVE 49 Overload Protection is ACTIVE 1515 49 O/L I Alarm 49 Overload Current Alarm (I alarm) 49 O/L Θ...
Page 246: Start Inhibit For Motors (66/68)
Functions 6.10 Start Inhibit for Motors (66/68) General The rotor temperature of a motor generally remains well below its maximum allowable temperature during normal operation and even during severe loading conditions. How- ever, during motor starting, the rotor can heat up quickly. If multiple starting attempts are made in a short duration of time, the rotor could suffer thermal damage.
Page 247 Functions one start becomes possible without exceeding the excessive rotor temperature limit, the blocking signal is terminated. Therefore the restarting temperature related to trip temperature is expressed as: Θ – Restart cold ------------------- - -------------------- - Θ Trip cold Restarting Times When giving the maximum allowable cold and warm starting attempts , the motor man- ufacturer assumes the motor is not restarted immediately after motor shutdown.
Page 248: Programming Settings
Functions #"!ÃDT‡h…‡DHPU‚€ #""ÃUÃTU6SUÃH6Y #"'Ãx‡A68UPS #"$ÃDÃHPUPSÃIPHDI6G τ kτ x #"%ÃH6YX6SHÃTU6SUT #"&ÃÆ8PG9²ÆX6SH #"#ÃUÃ@„ˆhy ! !Ã7x…8yÃDÃHDI Θ (t) Calculator Θ I > T EquaL = 0 & Θ (t) > Θ REST. & F# 4827 66 TRIP & F# 4823 >66 emer.start F# 4822 F# 4825 >BLOCK 66 66 BLOCKED...
Page 249: Settings For Start Inhibit Of Motors
Functions the difference between the number of allowable cold and warm starts is entered at ad- dress &2/'² :$50. For motors without separate ventilation, the reduced cooling at motor stop can be ac- counted for by entering the Nτ²)$&725 at address . As soon as the current no longer exceeds the current flow monitoring setting entered at address , the time constant is increased by the kτ...
Page 250: Information List For Start Inhibit Of Motors
Functions Addr. LCD-Text Setting Options Default Comments Setting 4305 I MOTOR NOMINAL 6.0 A 5.0 A Rated Motor Current 4306 MAX.WARM STARTS 1 Maximum Number of Warm Starts 4307 #COLD–#WARM Number of Cold Starts – Warm Starts 4308 Kτ-FACTOR Kt-Factor at Stop 6.10.2.2 Information List for Start Inhibit of Motors LCD-Text Comments...
Page 251: Voltage Protection (27, 59)
Functions 6.11 Voltage Protection (27, 59) 6.11.1 Description of Voltage Protection 6.11.1.1 Measurement Principle VT Connection The voltages supplied to the device may correspond to the three phase-to-ground volt- ages, or two phase-to-phase voltages and the displacement voltage, depending on how the voltage transformers are connected.
Page 252: Undervoltage Protection (27)
Functions nal. The 59 element is a definite time element in that the time delay is not a function of the voltage magnitude. Figure 6-48 shows the logic diagram of the overvoltage protection element. $#Ã$( Ã9@G6` $!Ã$( ÃQD8FVQ F# 6570 59-1 TRIP &...
Page 253 Functions Srpy‚†vt !& Anrege- !& Ã Anregung U…vƒƒvtÃ Tvthy Qvpxˆƒ Befehl Ã 9…‚ƒÃPˆ‡ rückfall Tvthy U< Befehl WÃ‡ U< U(t) W 9…‚ƒÃPˆ‡ÃTr‡‡vt Rückfallschwelle !& Ã9P U< Rf QvpxˆƒÃTr‡‡vt Anregeschwelle !& ÃQV U< U€vÃp‚€ TU < T AUSKOM !& Ã9ryh’ Qvpxˆƒ Anregung 9…‚ƒÃPˆ‡...
Page 254 Functions Tripping Closing 27-1 27-1 Anrege- Anregung Signal Pickup Signal Befehl Befehl rückfall Drop Out U< U< V(t) U(t) Drop Out Setting Rückfallschwelle 27-1 DO U< Rf U< AK Pickup Setting Anregeschwelle 27-1 PU U< I(t) Current Flow Monitoring Setting Addr.
Page 255: Programming Settings
Functions $ !Ã8VSS@IUÃTVQ@SW „1“ ! !Ã7x…8y‚†rqÃDÃHDI I> 20 ms F# 6505 $ %Ã!& Ã9@G6` >27 I SUPRVSN $ !Ã!& ÃQV F# 6539 27-1 TRIP & & V< F# 6534 27-1 PU CS & F# 6506 F# 6533 >BLOCK 27-1 27-1 picked up &...
Page 256: Overvoltage Protection
Functions 6.11.2.1 Overvoltage Protection Overvoltage protection can be turned 21, 2)), or set to $ODUP RQO\ at address )&7 . When address is set to 21, tripping by the overvoltage element is al- lowed. Pickup Values There are not clear cut procedures on how to set the pickup value of the overvoltage element.
Page 257: Undervoltage Protection
Functions 6.11.2.4 Undervoltage Protection Undervoltage protection can be turned 21, 2)), or set to $ODUP RQO\ at address )&7 . When undervoltage protection is turned 21, tripping by the undervolt- age elements is allowed. Pickup Values There are not clear cut procedures for setting the pickup values of the undervoltage relay elements.
Page 258: Settings For Undervoltage Protection
Functions Note: When switching off the &855(17 683(59,6,21 setting under Address , the device immediately picks up if voltage is not present and the undervoltage protec- tion is switched on. The device cannot be programmed if in pickup. Apply 3 phase volt- age to continue with programming! The 50 element “%NU&ORVHG , 0,1”...
Page 259: Information List For Undervoltage Protection
Functions 6.11.2.6 Information List for Undervoltage Protection LCD-Text Explanation 6530 27 OFF 27 Undervoltage protection switched OFF 6531 27 BLOCKED 27 Undervoltage protection is BLOCKED 6532 27 ACTIVE 27 Undervoltage protection is ACTIVE 6533 27–1 picked up 27–1 Undervoltage picked up 6534 27–1 PU CS 27–1 Undervoltage PICKUP w/curr.
Page 260: Frequency Protection (81 O/U)
Functions 6.12 Frequency Protection (81 O/U) 6.12.1 Description of Frequency Protection General The frequency protection function detects abnormally high and low frequencies in the system. If the frequency lies outside the allowable range, appropriate actions are ini- tiated, such as load shedding or separating a generator from the system. A decrease in system frequency occurs when the system experiences an increase in the real power demand, or when a malfunction occurs with a generator governor or automatic generation control (AGC) system.
Page 261: Programming Settings
Functions $#"Ã' ÃQD8FVQ >BLOCK 81-1 81-1 picked up F# 5206... F# 5232... $#$Ã' Ã9@G6` & $#!ÃW€v f > 81-1 TRIP V > Vmin f < F# 5236... Hrh†ˆ…r€r‡G‚tvp F#. 5214 81 Under V Blk $# ÃA8UÃ' ÃPV F#. 5211 „1“...
Page 262: Settings For Frequency Protection
Functions The time delays (Definite Time) entered at addresses , , and , Delays allow the device to prioritize or order corrective actions based on the degree to which the actual system frequency departs (upward or downward) from the nominal system frequency.
Page 263: Information List For Frequency Protection
Functions 6.12.2.2 Information List for Frequency Protection LCD-Text Comments 5211 81 OFF 81 Frequency protection switched OFF 5212 81 BLOCKED 81 Frequency protection is BLOCKED 5213 81 ACTIVE 81 Frequency protection is ACTIVE 5214 81 Under V Blk 81 Frequency protection Undervoltage Block 5232 81–1 picked up 81–1 Frequency element picked up...
Page 264: Breaker Failure Protection (50Bf)
Functions 6.13 Breaker Failure Protection (50BF) 6.13.1 Description of Breaker Failure Protection General The breaker failure protection function monitors the reaction of a circuit breaker to a trip signal. If after a programmable time delay, the circuit breaker has not opened, a breaker failure trip signal issued, and all adjacent circuit breakers that represent sourc- es to the fault can be tripped (see Figure 6-53).
Page 265 Functions breaker successfully cleared the fault current, therefore, the device can be pro- grammed such that only the current flow criterion is used to determine breaker status. The current criterion is met if at least one of the three phase currents exceeds the cur- rent flow monitoring setting entered at address (see Subsection 6.1.1).
Page 266 Functions &#Ã8uxÃ7SFÃ8PIU68U „1“ 52 Configuration Error & 52 Configured 52-a & 52 Configured 52-b & & AÆ #% & 52-a AÆ #%! & 52-b & & Internal Source AÆ #$% 50 BF int Pickup &$ÃUSDQUv€r… & AÆ #' From Internal 50 BF int TRIP Protection Functions &...
Page 267: Programming Settings
Functions 6.13.2 Programming Settings The breaker failure protection function is only effective and available if address General %5($.(5 )$,/85( is set to (QDEOHG. If the breaker failure function is not required, then address should be set to 'LVDEOHG. Address &KN %5.
Page 268: Settings For Breaker Failure Protection
Functions 6.13.2.1 Settings for Breaker Failure Protection Addr. LCD-Text Setting Options Default Setting Comments 7001 FCT 50BF 50BF Breaker failure protection 7004 Chk BRK CONTACT Evaluation of breaker auxiliary con- tacts (52/a or 52/b) via binary inputs 7005 TRIP–Timer 0.06 60.00 sec 0.25 sec Timer to indicate failure...
Page 269: Automatic Reclosing System (79M)
Functions 6.14 Automatic Reclosing System (79M) 6.14.1 Description of Automatic Reclosing System General From experience, the majority of faults associated with overhead distribution feeders are temporary in nature. Therefore, to maximize service availability, it is desirable to employ a system that will close the circuit breaker shortly after it is tripped. This is ac- complished in the 7SJ62 relay via the automatic reclosing system.
Page 270 Functions Trip Command closed Breaker Status open 52-a 9@69UDH@Ã Ã 9@69UDH@Ã!Ã Dead Time 8hpryÃv‡uÃhÃrÃ 8hpryÃv‡uÃhÃrÃ U…vƒÃ8‚€€hq U…vƒÃ8‚€€hq Reclose Command Reset Time (Blocking Time) Reclosing Unsuccessful Figure 6-57 Timing Diagram showing Two Unsuccessful Reclosing Shots (no additional reclosing of the circuit breaker) Initiation Initiation of the automatic reclosing function can be caused by internal protective func- tions or externally using a binary input.
Page 271 Functions sequence elements, the program is started. Like the ground fault reclosing pro- gram, this program can be started via a binary input as well. Determination of which program will be executed is based solely on which elements pick up prior to the first reclosing attempt. Once a program is started, it will be used to control reclosing until the last allowable reclosing signal is initiated.
Page 272 Functions After the final circuit breaker trip, the automatic reclosing system is dynamically blocked (see below). Blocking Time The blocking time (reset time) is started each time a reclosing attempt is initiated. If the reclosing attempt is successful, then the automatic reclosing system will reset once the blocking time has elapsed.
Page 273 Functions input with Function No: “! 7 :$,7” and specific setting of delayed AR command at address 0$;,QKLELW7,0() has elapsed. − Manual closing was detected (externally). − Through an binary input (FNo. “!%/2&. ”) configured with functions of dynamic blocking.
Page 274 Functions If the circuit breaker is not ready for operation when the dead time elapses, the dead time can be extended (see setting of dress ). If during this extended dead time period the circuit breaker mechanism indicates, via the binary input, that it is ready for another operation, a reclose command is initiated.
Page 275: Programming Settings
Functions in an inadvertent trip by the 50-2 element protecting the bus. Because zone sequenc- ing is switched on at the bus relay, the bus relay counts the number of faults, and after the first fault, blocks the 50-2 element from tripping. Therefore, for a permanent fault on Feeder #3, the 50-2 element at the bus would have been blocked after the reclosing attempt, and the 50-1 element at Feeder #3 would have tripped the circuit breaker in 0.4 seconds.
Page 276 Functions be set for only a few seconds. In areas with frequent thunderstorms, a shorter blocking time may be necessary to avoid feeder lockout due to sequential lightning strikes. A longer blocking time should be chosen if there is no possibility to monitor the circuit breaker ready status (see below) during multiple reclosing.
Page 277: Settings For Automatic Reclosing
Functions Blocking of auto re- The auto reclose function can be blocked, if control commands are issued. The control close via internal information must be routed via CFC (interlocking task-level) using the control CMD_Information block (see Figure 6-59). “IN: Control Device “OUT: >BLOCK 79”...
Page 278 Functions Addr. LCD-Text Setting Options Default Setting Comments Ordering Code 7SJ62**– 7103 BLK MAN. CLOSE NO Block automatic reclosing dur- ing manual closing of breaker (01 - BI) 7105 TIME RESTRAINT 0.50 320.00 sec. 3.00 sec. Reset time of automatic reclos- 7108 SAFETY 79 ready 0.01...
Page 279 Functions Addr. LCD-Text Setting Options Default Setting Comments Ordering Code 7SJ62**– 7103 BLK MAN. CLOSE NO Block automatic reclosing dur- ing manual closing of breaker (01 - BI) 7105 TIME RESTRAINT 0.50 320.00 sec. 3.00 sec. Reset time of automatic reclos- 7108 SAFETY 79 ready 0.01...
Page 280 Functions Addr. LCD-Text Setting Options Default Setting Comments Ordering Code 7SJ62**– 7155 67–TOC/67N– No influence No influence 67–TOC and 67N–TOC supervi- Starts 79 sion of automatic reclosing Stops 79 7156 sens Ground Flt No influence No influence Sensitive ground fault detection Starts 79 supervision of automatic reclos- Stops 79...
Page 281 Functions Addr. LCD-Text Setting Options Default Setting Comments Ordering Code 7SJ62**– 7180 3.Cy: 67(N)–1 Not Blocked Not Blocked Automatic reclosing control of Blocked Via 79 67–1 and 67N–1 during third shot 7181 3.Cy: 67(N)–2 Not Blocked Not Blocked Automatic reclosing control of Blocked Via 79 67–2 and 67N–2 during third shot...
Page 282: Information List For Automatic Reclosing
Functions 6.14.2.2 Information List for Automatic Reclosing LCD-Text Explanation Ordering Code 7SJ62**– 2781 79 OFF 79 Auto recloser is switched OFF 2782 79 ON 79 Auto recloser is switched ON 2784 CB is NOT ready Circuit breaker is NOT ready 2785 79 Dyn Block 79 –...
Page 283: Fault Location
Functions 6.15 Fault Location Measurement of the distance to a short-circuit fault is an important feature of the 7SJ62 relay allowing faster determination of the fault location. Fault location is only possible if the device is connected to both current and voltage transformers. 6.15.1 Description of Fault Location Initiation Fault location is initiated if the directional or non-directional overcurrent relay elements...
Page 284 Functions Table 6-3 Selection of Paths to be Reported for Wye-Connected Voltage Transformers Pickup Possible Paths Evaluated Paths Notes A–G, A–B, C–A A–G or If only one phase is A–G and least L–L picked up, then only the appropriate phase-to- ground path is displayed.
Page 285: Setting The Functional Parameters
Functions Table 6-4 Selection of Paths to be Reported for Open-Delta Connected Voltage Transform- Pickup Possible Paths Evaluated Paths Notes Least φ − φ A–B, C–A φ φ The least path is dis- Least φ − φ A–B, B–C played. Least φ...
Page 286: Settings For Fault Locator
Functions Line Constants To calculate the fault distance in miles or kilometers, the device needs the per distance reactance of the line in Ω/mile or Ω/kilometer, expressed as a secondary quantity. These values were entered during setting of the general protection data under ad- dress or (see Subsection 6.1.3).
Page 287: Phase Rotation
Functions 6.16 Phase Rotation 6.16.1 Description of Phase Rotation General Various functions of the 7SJ62 only function correctly if the phase rotation of the volt- ages and currents is known. Among these functions are negative sequence protec- tion, undervoltage protection (based only on positive sequence voltages), directional overcurrent protection, and measurement quantity monitors.
Page 288: Monitoring Functions
Functions 6.17 Monitoring Functions The device is equipped with extensive monitoring capabilities - both for hardware and software. In addition, the measured values are also constantly monitored for plausibil- ity, therefore, the current transformer and voltage transformer circuits are largely inte- grated into the monitoring.
Page 289: Software Monitoring
Functions current measured from a separate current transformer. If all four currents inputs are connected, their digitized sum must be zero. Faults in the current circuit are recognized if ⋅i ) | > Σ , 7+5(6+2/'⋅ I + Σ , )$&725 ⋅ I (= address &7 1&7 3K) takes into account a possible difference The factor k in the neutral current transformer ratio.
Page 290: Monitoring Of External Current Transformer Circuits
Functions 6.17.1.3 Monitoring of External Current Transformer Circuits Interruptions or short circuits in the secondary circuits of the current transformers or voltage transformers, as well as faults in the connections (important for start-up!), are detected and reported by the device. The measured quantities are periodically checked in the background for this purpose, as long as no system fault is present.
Page 291: Programming Settings For Measured Values Monitoring
Functions Increase: 76GA68UPSÃW 76G6I8@ÃW²GDHDU Figure 6-63 Voltage Symmetry Monitoring Current and Volt- To detect swapped phase connections in the voltage and current input circuits, the age Rotation phase sequence of the phase-to-phase measured voltages and the phase currents are checked by the monitoring. Direction measurement with normal voltages, path selection for fault location, and negative sequence detection all assume a phase sequence of “abc”.
Page 292: Settings For Measured Values Monitoring
Functions Address %$/$1&( 9²/,0,7 determines the limit voltage (Phase-to-Phase), above which the voltage symmetry monitor is effective (see also Figure 6-63). Address %$/ )$&725 9 is the associated symmetry factor; that is, the slope of the symmetry characteristic curve (Figure 6-63). Address %$/$1&( , /,0,7 determines the limit current, above which the cur- rent symmetry monitor is effective (see also Figure 6-62).
Page 293: Information
Functions 6.17.2.2 Information LCD-Text Comments Failure Σ I 0162 Failure: Current Summation 0163 Fail I balance Failure: Current Balance 0167 Fail V balance Failure: Voltage Balance 0171 Fail Ph. Seq. Failure: Phase Sequence 0175 Fail Ph. Seq. I Failure: Phase Sequence Current 0176 Fail Ph.
Page 294: Programming Settings For Fuse-Failure-Monitor
Functions 6.17.4 Programming Settings for Fuse-Failure-Monitor Note: The settings for the fuse failure monitor (address )86( )$,/ 9R) are to be selected so that reliable activation occurs if a phase voltage fails, but not such that false activation occurs during ground faults in a grounded network. The value entered at address should be based on the settings entered in 36<67(0 '$7$ re- garding the voltage transformer connections.
Page 295 Functions A condition for the use of trip circuit monitoring is that the control voltage for the circuit breaker is greater than the sum of the minimum voltage drops of both binary inputs > 2 ⋅ V ). Since at least 17 V are needed for each binary input, the monitor can BImin only be used with a system control voltage of over 35 V.
Page 296 Functions The conditions of the two binary inputs are checked periodically. A check takes place about every 600 ms. If three consecutive conditional checks detect an abnormality (af- ter 1.8 s), an annunciation is reported (see Figure 6-65). This is used to avoid the an- nunciation for brief transition periods.
Page 297: Programming Settings For Trip Circuit Monitor
Functions checked 500 times before an annunciation is sent. A condition check takes place about every 600 ms, so trip circuit monitoring is only activated during an actual mal- function of the trip circuit (after 300 s). After the malfunction in the trip circuit is cleared, the failure annunciation is reset automatically.
Page 298 Functions tion is delayed by a fixed amount of time. For two binary inputs, the delay is about 2 seconds, and for one binary input, the delay is about 300 ms. This ensures that, for the longest possible duration of a trip signal, a false malfunction message will not be generated.
Page 299: Setting For Trip Circuit Monitor
Functions Example: ® 1.8 mA (from SIPROTEC 7SJ62) BI (HIGH) ® 19 V for delivery setting for nominal voltage 24/48/60 V (from SIPROTEC 7SJ62) BI min ® 88 V or delivery setting for nominal voltage 110/125/220/250 V) (from SIPROTEC 7SJ62) 110 V (from system / release circuit) 500 Ω...
Page 300: Malfunction Responses Of The Monitoring Functions
Functions 6.17.7 Malfunction Responses of the Monitoring Functions Depending on the type of malfunction discovered, an annunciation is sent, a restart of the processor system is initiated, or the device is taken out of service. after three un- successful restart attempts. The live status contact operates to indicate the device is malfunctioning.
Page 301 Functions Summary of the Device Malfunction Responses Table 6-6 Monitoring Possible Cause Malfunction Re- Message Output sponse „)DLOXUH Σ,“ CT Error) Message as masked Current Summation (FNo. 162 „)DLO , EDODQFH“ Current Symmetry CT Error Message as masked (FNo. 163 „)DLO 9 EDODQFH“...
Page 302: Protection Function Logic
Functions 6.18 Protection Function Logic The function logic is the heart of the device. It coordinates the sequence of both the protective and auxiliary functions, processes functional decisions, and processes data received from the system. In particular, the function logic is responsible for the follow- ing: •...
Page 303: Tripping Logic Of The Entire Device
Functions Please note, the overload protection does not have a pickup comparable to the other protective functions. The general relay pickup time is first started with the trip signal, and an abnormal occurrence is opened. The dropout of the thermal image of the over- load protection ends the fault message and, thereby, the running time from general re- lay pickup to general device dropout.
Page 304: Programming Settings For Tripping Logic
Functions 6.18.2.2 Programming Settings for Tripping Logic The setting of the minimum trip signal duration at address 7PLQ 75,3 &0' was Trip Signal Dura- tion already discussed in Subsection 6.1.1. This time is valid for all protective functions that can initiate trip signals, as well as for trip signals that are initiated using the device function controller.
Page 305: Statistical Counters
Functions 6.18.4 Statistical Counters 6.18.4.1 Description Number of Trips The number of trips initiated by the 7SJ62 is counted, as long as the position of the circuit breaker is monitored via breaker auxiliary contacts and binary inputs. Fault Current Furthermore, the fault current in each pole of the circuit breaker is determined for each trip signal.
Page 306 Functions LCD-Text Explanation 0071 Settings Check Settings Check 0072 Level-2 change Level-2 Change 0068 Clock SyncError Clock Synchronization Error 0069 DayLightSavTime Daylight Savings Time (clock) 0183 Error Board 1 Error Board 1 0184 Error Board 2 Error Board 2 0185 Error Board 3 Error Board 3 0186...
Page 307: Auxiliary Functions
Functions 6.19 Auxiliary Functions The auxiliary functions of the 7SJ62 relay include: Message Processing Measurements Waveform Capture 6.19.1 Message Processing After the occurrence of a system fault, data regarding the response of the protective relay and the measured quantities should be saved for future analysis. For this reason message processing is done in three ways: •...
Page 308: Measurements
Functions In the idle condition, as long as no system fault is present, the display field can display selected operating information (overview of operating measurement values). In the case of a system fault, information about the system fault appears instead (spontaneous messages).
Page 309 Functions The displacement voltage is either measured directly or calculated from the phase-to- ground voltages: = 3V with: gnTRA = (V = Transformation adjustment for ground gnTRA input voltage (setting ) The ground current I is either measured directly or calculated from the conductor cur- rents: = 3⋅I / (I...
Page 310: Waveform Capture
Functions − The long-term averages of the three phase currents I ; the positive sequence com- ponents I for the three phase currents; and the real power P, reactive power Q, and apparent power S; in primary values. The period of time for averaging is selectable. −...
Page 311: Programming Settings
Functions , and I , and V , 3V (voltages depending on the connection) are scanned at intervals of 1.04 ms for 60 Hz (1.25 ms for 50 Hz) and stored in a revolving buffer (16 samples per cycle). For a fault, the data are stored for an adjustable period of time, but not more than 5 seconds.
Page 312 Functions Furthermore, it is possible to monitor the power factor, and connected 20 mA values (if any). The settings are entered under 0($685(0(17 in the sub-menu 6(7 32,17609 by overwriting the existing values. Waveform capture of faults is executed only when Address 0104 26& )$8/7 5(& Waveform Capture is set for (QDEOHG Other settings pertaining to waveform capture are found under the 26&)$8/7 5(& sub-menu of the 6(77,1*6 menu.
Page 313: Settings For Auxiliary Functions
Functions 6.19.4.1 Settings for Auxiliary Functions Demand and Min/ Max Measurement Setup Addr. LCD-Text Setting Options Default Setting Comments 8301 DMD Interval 15 Min., 1 Sub 60 Min., 1 Sub Interval for Averaging 15 Min., 3 Subs 15 Min., 15 Subs 30 Min., 1 Sub 60 Min., 1 Sub 8302...
Page 314: Information List For Auxiliary Functions
Functions 6.19.4.2 Information List for Auxiliary Functions LCD-Text Explanation 0395 >I MinMax Reset >I MIN/MAX Buffer Reset 0396 >I1 MiMaReset >I1 MIN/MAX Buffer Reset 0397 >V MiMaReset >V MIN/MAX Buffer Reset 0398 >VphphMiMaRes >Vphph MIN/MAX Buffer Reset 0399 >V1 MiMa Reset >V1 MIN/MAX Buffer Reset 0400 >P MiMa Reset...
Page 315: Breaker Control
Functions 6.20 Breaker Control General In addition to the protective functions described thus far, a Control command process ® is integrated in the SIPROTEC 7SJ62 to coordinate the operation of circuit breakers and other equipment in the power system. Control commands can originate from four command sources: −...
Page 316 Functions − Commands (e.g. operation of circuit breakers, etc.) − Step Commands (e.g. raising and lowering transformer LTCs) − Set-point Commands with configurable time settings (Petersen coils) Internal / pseudo These commands do not directly operate binary outputs. They serve to initiate internal Commands functions, simulate changes of state, or to acknowledge changes of state.
Page 317: Steps In The Command Sequence
Functions 6.20.2 Steps in the Command Sequence Safety mechanisms in the command sequence ensure that a command can only be released after a thorough check of preset criteria has been successfully concluded. Standard Interlocking checks are provided for each individual control command. Ad- ditionally, user-defined interlocking conditions can be programmed separately for each command.
Page 318: Interlocking
Functions 6.20.3 Interlocking ® DIGSI Dialogue Box for Object Properties – for Setting the Interlock- Figure 6-71 ing Conditions. The interlocking checks are divided into: • System Interlocking (checked by a central control system such as SCADA or sub- station controller), to be implemented with Version 4.2 •...
Page 319: Interlocked/Non-Interlocked Switching
Functions 6.20.3.1 Interlocked/Non-Interlocked Switching The command checks that can be selected for the 7SJ62 relay are also referred to as “standard interlocking”. These checks can be activated (interlocked) or deactivated (non interlocked). Deactivated interlock switching means the configured interlocking conditions are not checked in the relay.
Page 320 Functions mote DIGSI connection or via the SCADA interface is only allowed if switching au- thority is set to REMOTE. An overview for processing the interlocking conditions in the relay is shown by Figure 6-72. Switching Authority Switching Mode Device with Source of Command = On/Off LOCAL...
Page 321 Functions − DIGSI ® − REMOTE (commands are issued from SCADA) The switching authority condition /2&$/ allows commands from the user interface of the relay, but not remote or DIGSI commands. The selection between local and remote is made using the local user interface. A pass- word is required, to make this selection.
Page 322 Functions − Local commands (SC = LOCAL) − interlocked, or − non-interlocked switching. For devices without key-switches, the switching mode can be changed between “in- terlocked” and “non-interlocked” using the front PC port, after password entry. − Remote or DIGSI ®...
Page 323: Operators Tools
Operators Tools ® This chapter describes interaction possibilities with the SIPROTEC 7SJ62 device during operation. The information that can be obtained and the procedure for retriev- ing the data are discussed. Methods of influencing the device functions during opera- tion and controlling the system using the device are covered. Detailed knowledge about the device functions is not required at this point;...
Page 324: Retrieval Of Information
Operators Tools Retrieval of Information General The device provides information that can be obtained locally or remotely: • Messages, • Operating measurement and metered values, • Waveform data in oscillographic records. This information is individually discussed below. Methods for viewing, retrieving, ac- knowledging, and storing this information on a PC are also explained.
Page 325 Operators Tools Binary Outputs Indications can be configured to binary outputs for external indication (e.g. annuncia- tor, sequence-of-events recorder, RTU, etc ), and operate exactly like LEDs. See also Chapter 5 for details. Front Panel Display To retrieve messages using the front panel display on a device that is ready for oper- ation: First press the 0(18 key .
Page 326: Event Log (Operating Messages)
Operators Tools ® 4 2QOLQH directory is opened with a double-click, the operating func- If the DIGSI tions for the device appear in the navigation window (Figure 7-2). By double clicking on $QQXQFLDWLRQ, the tree structure expands and shows the individual message groups.
Page 327 Operators Tools key. The 0$,1 0(18 appears. From the With a device ready for operation, first press the MENU Device Front The first menu item ($QQXQFLDWLRQ) is marked. key to enter the $1181&,$7,21 menu (see Figure 7-1). Press the Here, select the menu item (YHQW /RJ (already marked). The (9(17 /2* table ap- pears.
Page 328: Trip Log (Fault Messages)
Operators Tools ® Figure 7-5 DIGSI 4 Event Log Window — Example 7.1.1.3 Trip Log (Fault Messages) Spontaneous The spontaneous messages that can be viewed on the device front serve to display messages the most important data about a fault. The messages appear automatically in the dis- play, after a general pickup of the device, in the sequence shown in Figure 7-6.
Page 329 Operators Tools key, select the sub-menu item 7ULS /RJ and move to the Trip Log sub- Using the key. The 75,3 /2* selection appears. menu using the In this sub-menu, the indications for the last 8 network faults can be selected, again using the keys.
Page 330: Ground Fault Messages (Ground Fault Messages Associated With The Sensitive Ground Fault Function)
Operators Tools ® Figure 7-8 DIGSI 4 Selection of Trip Log with Faults Listed in the Data Window ® Figure 7-9 DIGSI 4 Example of Indications for a Fault, Trip Log Window 7.1.1.4 Ground Fault Messages (Ground Fault messages associated with the sensitive ground fault function) For devices with sensitive ground fault detection, special ground fault records are available.
Page 331 Operators Tools In this sub-menu, messages from the last 3 ground faults can be selected, again using key and moving on with the key. See the example in Figure 7-10. If no messages are present for a fault record, then access is denied and the message “/LVW (PSW\”...
Page 332: Saving And Erasing The Messages
Operators Tools ® Figure 7-12 DIGSI 4 Example of Indications for a Ground Fault, Ground Fault Log 7.1.1.5 Saving and Erasing the Messages Normally, erasing the messages is not necessary because the oldest messages are automatically erased when new events are entered, if the memory is full at the time. However, erasure of the stored messages may be useful, for instance, after revision or commissioning, so that in the future the memory only contains information about ac- tual events.
Page 333: General Interrogation
Operators Tools Press the associated number key to se- 6(75(6(7 lect the messages to be erased. !(YHQW /RJ !7ULS /RJ 3: 3DUDPHWHU &KDQJH" Enter Password No. 5 (for setting change) ENTER and confirm with ENTER Confirm “<(6” with the key and com- ENTER $UH \RX VXUH"...
Page 334: Statistics
Operators Tools Double click 6SRQWDQHRXV $QQXQFLDWLRQ in the data window. The date and time appear in the data window. By double clicking on them, the Spontaneous Annunciation window opens, as shown in the following figure. Each entering message appears im- mediately, without requiring that an update be initiated.
Page 335: Resetting And Setting The Statistics
Operators Tools key. The 0$,1 0(18 appears. From the With a device ready for operation, first press the MENU The first menu item $QQXQFLDWLRQ is marked. Device Front key to enter the $1181&,$7,21 sub-menu (see Figure 7-1). Press the key to select the item 6WDWLVWLF, and switch to the list of statistics values Use the key.
Page 336: Setting Limit Values For The Statistics Counters
Operators Tools 67$7,67,& RI 75,3V 2S+RXUV !KRXU ENTER ENTER 2SHU +UV 2S+RXUV 2147483648 Figure 7-17 Setting Statistics Values from the Device Front In the 6WDWLVWLF window, mark the value that is to be set. With the right mouse but- From PC with ®...
Page 337: Measured And Metered Values
Operators Tools Move to the item 6HW 3RLQWV 6WDWLVWLF under 6WDWLVWLF in the $QQXQFL From PC with ® DWLRQ. By double clicking, the associated contents are displayed in another window, DIGSI as shown in Figure 7-20. Overwriting the default value sets a new limit value. Entry of password No.
Page 338: Measured Values
Operators Tools Tabelle 7-1 Convertion formula between secondary values and primary/percentage values Measured Second Primary Value SEC. &7 35,0$5< prim. ⋅ ------------------------------------------ - I ---------------------------------------------- - &7 6(&21'$5< , 35,0$5< 23 SEC. N SEC. &7 35,0$5< N prim. ⁄ ⋅ ⋅...
Page 339 Operators Tools • I : positive and negative sequence components of the currents, primary in A and kA, secondary in A and in % of the device nominal current. • Va, Vb, Vc: phase-to-ground voltages, primary in kV, secondary in V and in % of /√3, assuming that the phase-to-ground voltages are connected.
Page 340 Operators Tools 3. 2SHUDWLRQ VHF Operating measured values, secondary. The values of the measurement quantities that are present directly at the terminals of the device are issued. 4. ,1V VHFRQGDU\ Ground fault measured values, secondary. The real portion, I , and reactive portion, I , of the ground connection current.
Page 341 Operators Tools Use the key to select the measured value group that has the values desired, and switch to the display of this group with the key. Figure 7-22 shows an example for the display of operating measured values. 0($685(0(17 !2SHUDWLRQ SUL...
Page 342 Operators Tools 3. 3HUFHQW Measured values, as a percentage of the nominal quanti- ties. The nominal quantities are determined by the version of the device and possibly the nominal value settings (addresses 9 35,0$5< 23, , 35,0$5< 23, refer sub- section 6.1.3).
Page 343: Energy, Metered Values
Operators Tools ® Measured Values Window in Figure 7-24 DIGSI ® Example of Measured Values shown in Figure 7-25 DIGSI 7.1.3.2 Energy, Metered Values Retrieving of In a 7SJ62 device with the maximum configuration, counters are available that sum the real and reactive energy (:S, :T) separately, according to reporting and recording Metered Values of the real energy and capacitive and inductive reactive energy, in the direction of the protected object.
Page 344: Setting Limit Values
Operators Tools Moving up and down in the table of energy measurements is done using the key can be used to return to the 0($685(0(17 level. Press the keys. The MENU key to return to the 0$,1 0(18. The metered value groups can be found under 0HDVXUHPHQW (Figure 7-2) with a From PC with ®...
Page 345 Operators Tools 0($685(0(17 !6HW 3RLQWV09 6(7 32,176 09 !5HVHW ! ,$ GPG! Etc. Enter Password No. 5 (individual settings) 3: 6HWWLQJV" ENTER and confirm with ENTER ENTER $UH <RX 6XUH" ENTER !<(6 12 (VFDSH Figure 7-26 Setting Limit Values at the Front Panel —...
Page 346: Resetting Metered Values And Min/Max Values
Operators Tools ® Figure 7-27 Set Limit Values in DIGSI 7.1.3.4 Resetting Metered Values and Min/Max Values Metered values and minimum/maximum values can be reset. key. The 0$,1 0(18 appears. From the With a device ready for operation, first press the MENU Device Front key to select the menu item 0HDVXUHPHQW, and switch to the list of mea-...
Page 347: Waveform Capture
Operators Tools To set values to zero, right click on the group in the navigation to open a context menu. Click on 5HVHW. Note : By selecting the 5HVHW command, all values are reset to zero without further inquiry. This procedure cannot be undone. 7.1.4 Waveform Capture Waveform data is stored in the device and can be graphically represented on a PC...
Page 348 Operators Tools The quantities can be represented in these views: • Time signals • Vector diagrams • Locus diagrams • Harmonics Selection takes place using the menu bar (9LHZ), or in the symbol bar above the rep- resented switching fields. Figure 7-30 shows all four views simultaneously. The waveform data read into the PC memory are first shown in full on the monitor.
Page 349: Saving Of Waveform Capture
Operators Tools 7.1.4.2 Saving of Waveform Capture Storage of Oscillographic records that are received are not automatically saved in the PC. The Oscillographic Data data can, however, be saved in files. ® For more details, see the DIGSI 4 Operating Handbook, Order No. E50417–H1176– C097, Section 9.4.
Page 350: Control Of Device Functions
Operators Tools Control of Device Functions The user can change individual functions and messages in a 7SJ62 while the device is in-service. Some examples are given above, including erasing saved information (Sub-section 7.1.1.5) and setting/resetting counters and limits (Sub-sections 7.1.2.2 and 7.1.3.4).
Page 351 Operators Tools sentations. The possible representations and the associated causes are listed in Table 7-3. Table 7-3 Representations of Date and Time: Display (Example) Year Time Malfunc- Time Invalid tion Date Time HHHH " Year = 1990 irrelevant " " " 1990<Year<2090...
Page 352 Operators Tools In the other operating modes, manual adjustments are only accepted if the synchroni- zation is momentarily lost. The messages “time malfunction ON” and “time malfunction OFF” are given when manually changing the year in the IRIG B mode. Without healthy or external time synchronisation the free running date and time can also be relatively adjusted (+/–...
Page 353 Operators Tools From PC with To manually enter the date and time into the device: ® DIGSI Click on 'HYLFH in the menu bar as shown in Figure 7-33. Select the command 6HW &ORFN. Selecting The Command 6HW &ORFN in DIGSI ®...
Page 354: Changeover Of Setting Groups
Operators Tools ® Figure 7-35 Setting Window in DIGSI Double click on 7LPH 6\QFKURQL]DWLRQ in the data window. This give access to change: − Source of time synchronisation − Time delay alarm − Time format − Time correction. ® Figure 7-36 Window for Time Synchronization and Time Format Settings in DIGSI 7.2.2 Changeover of Setting Groups...
Page 355 Operators Tools can also be remotely controlled via binary inputs or the SCADA interface. User-de- fined logic capabilities offer even more possibilities. Password No. 5 (password for individual settings) is required to change setting groups. The first setting group is called group A. The others are groups B, C, and D. If setting group changing is to be used, then settings for the groups to be employed must be entered (see Section 6) and the changeover facility must be (QDEOHG under Address 0103 *US &KJH 237,21.
Page 356 Operators Tools Control of the setting groups can always be regained by changeover to one of the Groups A through D. key can be used to return to the 6(77,1*6 sub-menu; the MENU key can be pressed to returns to the 0$,1 0(18. ®...
Page 357: Test Messages To The Scada Interface During Test Operation
Operators Tools ® Figure 7-39 Setting Group Changeover Window in DIGSI The active setting group is displayed. To switch to another setting group, click on the field 9DOXH and select the desired option from the drop-down list. Before closing the window, transfer the change to the device.
Page 358 Operators Tools key, highlight the menu item 7HVW'LDJQRVH, and then press the Using the key to enter sub-menu. 7(67',$*126( will appear at the top of the menu. At this point, highlight the menu item 7HVW (QDEOH using the key, and then press key to enter sub-menu.
Page 359 Operators Tools ® Figure 7-42 Example: Transfer Block Activated in DIGSI Click on %ORFN 'DWD 7UDQVPLVVLRQ to activate or deactivate the transfer block. After entry of Password No. 4 for test and diagnostics, and confirmation with 2., the setting change is complete. Activation is indicated with a check mark in front of the command.
Page 360: Control Of Switchgear
Operators Tools Control of Switchgear ® A SIPROTEC 4 device 7SJ62 contains control functions that allow for opening and closing of power system switching devices (i.e. circuit breakers). Local control is pos- sible utilizing different elements of the 7SJ62. Breaker control from a remote location ®...
Page 361: Display Equipment Position And Control
Operators Tools 7.3.1 Display Equipment Position and Control key. The 0$,1 0(18 appears. From the With a device ready for operation, first press the MENU Device Front key, select the menu item &RQWURO, and go to editing the control func- Using the key.
Page 362 Operators Tools Enter Password No. 1 (for interlocked switching) and acknowledge with the ENTER key. Note: if the switching mode is 121²,17(5/2&.(' 7HVW (Sub-section 7.3.7), all switching operations are only possible with Password No. 2 (for non-interlocked switching). A new window appears. Depending on the operating and command type of the select- ed switching device, various options are offered.
Page 363 Operators Tools ® The switching authority is first transferred to DIGSI 4 at the moment the control win- dow shown in Figure 7-48 is opened. The configuration matrix discussed in Section 5.2 determines the control devices that have information displayed in this field. ®...
Page 364: Manual Overwriting
Operators Tools 7.3.2 Manual Overwriting When using the Control with Feedback feature, the device checks the feedback in- dications (i.e. 52-a and 52-b) before and after a control command is issued. If for some reason, the physical connection from a circuit breaker auxiliary contact to the binary inputs of the device is broken, inadvertently shorted, or disconnected, commands may be blocked.
Page 365: Set Status
Operators Tools 0$1 2 !23(1 !%UH &/26 !23(1 !'LVF &/26 Figure 7-50 Selection Window for Manual Overwriting of a Switch Position, Front Panel A safety inquiry appears: “$UH \RX VXUH"” Provided manual overwriting is allowed, a response of “<(6” results in an appropriate message on the display. Acknowledge the message by pressing the key again.
Page 366 Operators Tools Note: Input ignored only works for physical inputs! Do not set the block for indications cre- ated by CFC. key. The 0$,1 0(18 appears. From the With a device ready for operation, first press the MENU Device Front key, select the menu item &RQWURO and go to editing the control func- Using the key.
Page 367: Interlocking
Operators Tools From PC Us- For safety reasons, Status changes are only possible locally using the keypad on the ® ® ing DIGSI front panel of the device. Status changes are not possible in DIGSI 7.3.4 Interlocking Operating equipment such as circuit breakers, circuit switchers and ground switches can be subject to interlocking conditions.
Page 368: Tagging
Operators Tools ble clicking on 0DVNLQJ ,2, the matrix is opened. Mark the switching device (in the line for the operating message of the switching device). Using the right mouse key, the properties of the switching device can now be called up. The conditions for ,QWHU ORFN 6ZLWFKLQJ, among other items, are recognizable in the dialog box that opens.
Page 369: Switching Authority
Operators Tools 7.3.6 Switching Authority Switching authority determines the command sources that are permitted for control. key. The 0$,1 0(18 appears. From the With a device ready for operation, first press the MENU Device Front key, select the menu item &RQWURO and move to editing the control func- Using the key.
Page 370: Control Messages
Operators Tools DANGER! Only highly qualified personnel who have an exact knowledge of the power sys- tem conditions shall perform non-interlocked switching. Inappropriate switch- ing operations can lead to death, serious personnel injury and property dam- age. key. The 0$,1 0(18 appears. From the With a device ready for operation, first press the MENU...
Page 371 Operators Tools ated causes are listed in Table 7-4, together with other messages for the control of de- vice functions. Table 7-4 Possible Control Messages Message Text Message Cause 6\VWHP (UURU Interruption by system error 0DQ2YHUZULWH 2. Return routing carried out 0DQ2YHUZULWH )DLO Return routing cannot be carried out &RQWURO $ERUW 2.
Page 372: Other Commands
Operators Tools Table 7-4 Possible Control Messages Message Text Message Cause &KHFNLQJ ,QWHUORFN Command is sent to the central unit to check system interlocking 6HWWLQJV DUH 2. Parameter change was correctly accepted 7LPH /LPLW ([SLUHG Parameter change was interrupted because time expired 7HUPLQDWHG3LFNXS Parameter change interrupted because a fault became active dur- ing parameterization...
Page 373: Installation And Commissioning
Installation and Commissioning This section is primarily for personnel who are experienced in installing, testing, and commissioning protective and control systems, and are familiar with applicable safety rules, safety regulations, and the operation of a power system. Installation of the 7SJ62 is described in this section. Connections for the device are discussed.
Page 374: Installation And Connections
8.1.1 Installation Panel Flush Remove the four covers on the corners of the front cover. Four elongated holes in Mounting the mounting angle strips become accessible. Elongated Holes SIPROTEC SIEMENS ERROR 7SJ62 H6DIÃH@IVÃÃÃÃÃÃÃÃÃÃÃÃ $ Annunciation Metering TRIP MENU ″ PICKUP A...
Page 375 Rack Mounting Two mounting brackets are necessary to install the 7SJ62 in a rack. The order number for the brackets is given in the Appendix, Sub-section A.1.3. Mounting Bracket SIPROTEC SIEMENS ERROR 7SJ62 MAIN MENU 01/05 Annunciation Metering...
Page 376: Connections
Installation and Commissioning Remove the four covers on the corners of the front cover of the device. Four elon- gated holes in the mounting angle strips become accessible. Fasten the device to the mounting brackets with four screws. Replace the four covers. Tighten the mounting brackets to the rack using 8 screws.
Page 377 Installation and Commissioning The maximum continuous voltage rating of a 7SJ62 is 170 V. For the first case above (phase-ground voltage connections), phase-phase voltages of up to [√3 · 170V] = 294 V can be continuously processed, applied. For the second case, the steady state phase-phase voltages connected to the device must be 170 V or less.
Page 378: Hardware Modifications
Installation and Commissioning Selector Switch for Setting Group changeover V– &Ã Binary input set for: 3Tr‡ÃB…‚ˆƒÃ7v‡Ã “ ”, High 7SJ62 V– 'Ã Binary input set for: 3Tr‡ÃB…‚ˆƒÃ7v‡Ã ” ”, High Figure 8-3 Connection Diagram (Example) for Setting Group Changeover with Binary In- puts Trip Circuit One or two binary inputs can be used for monitoring a circuit breaker trip coil.
Page 379 Installation and Commissioning All these jumpers (X61 to X64 and X60) must be in the same position: 1 A or 5 A. If the highly sensitive current input is used, jumper X64 is omitted. If nominal current ratings are changed, then the new ratings must be altered under Ad- dress &7 6(&21'$5<...
Page 380 Installation and Commissioning − #1 Phillips screwdriver, − 4.5 mm socket or nut driver. Unfasten the screw-posts of the D-subminiature connector on the back panel at loca- tion “A”. This activity does not apply if the device is for surface mounting. If the device has more communication interfaces at locations “B”...
Page 381 Installation and Commissioning Processor Printed Circuit Board CPU Input/Output Printed Circuit Board I/O Slot 5 Slot 19 BI1 to BI4 to Binary Inputs (BI) BI11 Figure 8-4 Front View After Removing the Front Cover (Simplified and Reduced) 7SJ62 Manual C53000-G1140-C121-1...
Page 382 Installation and Commissioning On the CPU board, check the provided nominal voltage of the integrated power supply according to Table 8-2 and the selected pickup voltages of the binary inputs BI1 through BI3 according to Table 8-3. – Figure 8-5 Jumpers On The CPU Board For The Power Supply And Binary Inputs BI1 To BI3 (Simplified) 8-10...
Page 383 Installation and Commissioning Table 8-2 Jumper Settings for the Nominal Voltage of the Integrated Power Supply on the CPU Board Jumper Nominal Voltage 60/110/125 VDC 110/125/220/250 VDC 24/48 VDC 115 VAC 230 VAC Jumpers X51 1-2 and 3-4 through X54 are not used Can be interchanged Not changeable...
Page 384 Installation and Commissioning On the I/O board, check the supplied nominal current ratings of the current transform- ers (5 jumpers) and the selected pickup voltages for the binary inputs BI4 through BI11 according to Table 8-4. Figure 8-6 Jumpers on the I/O Board for the Current Transformers and the Binary Inputs BI4 to BI11 (simplified) The X3 and X4 jumpers for configuring the terminating resistors of a serial interface are on a card that is located on the CPU board.
Page 385 Installation and Commissioning Table 8-5 Configuration of Jumpers for RS 232 or RS 485 on the Interface Card (Circuit Board Number C53207-A322-B80, Figure 8-7) Jumper RS 232 1–2 1–2 1–2 1–2 1–2 1–2 2–3 RS 485 2–3 2–3 2–3 2–3 2–3 2–3 2–3...
Page 386 Installation and Commissioning The Profibus–Interface has two Jumpers X3 and X4, as shown in Figure 8-9. Jumpers X3 and X4 are set at the factory so that the terminating resistors are switched-out. Both jumpers must always be set for the same position. C53207-A322- 2 3 4 B100...
Page 387: Checking Connections
Installation and Commissioning Checking Connections 8.2.1 Data Connections Table 8-7 shows the pin-assignments for the various serial interfaces of the device. Table 8-8 refers to the time synchronization interface. PC Interface at When the recommended communication cable is used, correct connection between ®...
Page 388: Substation Connections
Installation and Commissioning RS 485 The RS 485 interface is capable of half-duplex mode with the signals A/A’ and B/B’ Termination with a common relative potential C/C’ (DGND). Verify that only the last device on the bus has the terminating resistors connected, and that the other devices on the bus do not.
Page 389 Installation and Commissioning Caution! Operating the device on a battery charger without a connected battery can lead to un- usually high voltages and consequently, the destruction of the device. For limit values see Sub-section 10.2.1 under Technical Data. If an undervoltage element (27) is enabled and 21 and the current supervision of the 27 element is 2)), then the 27 element will immediately trip when voltage is removed from the device.
Page 390 Installation and Commissioning Connect an ammeter in the supply circuit of the power supply. A range of about 1 A for the meter is appropriate. Close the protective switches to apply voltage to the power supply. The measured steady state current should be insignificant. Transient movement of the ammeter merely indicates the charging current of capacitors.
Page 391: Commissioning
Installation and Commissioning Commissioning Warning! When operating an electrical device, certain parts of the device inevitably have dan- gerous voltages. Severe personal injury or property damage can result if the device is not handled properly. Only qualified people shall work on and around this device after becoming thoroughly familiar with all warnings and safety notices in this instruction manual as well as with the applicable safety steps, safety regulations, and precautionary measures.
Page 392: Directional Testing With Load Current
Installation and Commissioning a problem, the relevant condition can be viewed in the Event Log. If current summation errors occur, then check the matching factors. See Sub-section 6.17.2.1. Messages from the symmetry monitoring could occur because there actually are asymmetrical conditions in the network. If these asymmetrical conditions are normal service conditions, the corresponding monitoring functions should be made less sen- sitive.
Page 393: Polarity Testing For Ground Fault Protection
Installation and Commissioning direction of the normal network current flow or the load current flow for this test. For all three phases, the corresponding power flow directional messages must be reported properly. If all directions are incorrect, then there is conflict between the polarity of the current transformers and the polarity set under Address &7 6WDUSRLQW, in 36\VWHP 'DWD.
Page 394 Installation and Commissioning sured values. Messages from the measured-values supervision should be ignored during this testing. DANGER! Primary measurements must only be carried out on disconnected and grounded equipment of the power system. Danger to life exists even on disconnected equipment because of capacitive coupling from other energized equipment of the power system! DANGER!
Page 395: Testing The Reverse Interlocking Scheme (If Applicable)
Installation and Commissioning 7SJ62 Line Figure 8-12 Polarity Testing for I , Example with Current Transformers Configured in a Hol- mgreen-Connection (VTs Wye-Connected) Check the directional data. The messages in the annunciation must contain at least the message “JURXQG FRQQHFWLRQ IRUZDUG” and a pickup message (“1V!21”). See also Sub-section 6.6.1.3.
Page 396 Installation and Commissioning tion in a radial distribution system with three feeders. The tripping of both elements is blocked when Binary Input 1 is energized. The input mask is [!%/2&. + or !%/2&. 1 +]. The elements have slight time delays to provide coordination with the blocking protective relays.
Page 397: Testing The Breaker Failure Scheme (If Applicable)
Installation and Commissioning 8.3.5 Testing the Breaker Failure Scheme (if applicable) Precise timing tests of the breaker failure scheme within the device are better suited for a lab environment, but on-site functional tests are practical. Current injection from a test set directly into the 7SJ62 is recommended for these functional tests. The device must be isolated from the current transformers.
Page 398: Test Mode And Blocking Data Transmission
Installation and Commissioning 8.3.7 Test Mode and Blocking Data Transmission ® If the SIPROTEC 4 device is connected to a central or main computer system via the SCADA interface, then the information that is transmitted can be influenced. If 7HVW PRGH is set 21, then a message sent by the device to the main system has an additional test bit.
Page 399 Installation and Commissioning The possible intended condition of a hardware component is indicated with clear text under the 6FKHGXOH column, which is next to the 6WDWXV column. The intended con- dition offered for a component is always the opposite of the present state. The right-most column indicates the operating equipment, commands, or messages that are configured (masked) to the hardware components.
Page 400: Trip/Close Tests For Primary Equipment
Installation and Commissioning − for each component, if a command to change the condition is successfully per- formed, − for all hardware components if the 8SGDWH field is clicked, − for all hardware components with cyclical updating if the $XWRPDWLF 8SGDWH VHF field is marked.
Page 401: Triggering Oscillographic Recordings
Installation and Commissioning 8.3.10 Triggering Oscillographic Recordings At the end of commissioning, an investigation of a closing operation of a circuit breaker or primary switching device, under load conditions, should be done to assure the sta- bility of the protection during the closing process. Oscillographic event recordings ob- tain the maximum information about the behavior of the 7SJ62.
Page 402: Generate Indications
Installation and Commissioning 8.3.11 Generate Indications A test of the SCADA interface to verify that messages are being correctly transmitted ® and received can be done with DIGSI 4. With the program Online, click on Test, and then double-click on Test System Port in the right window. The dialog box Generate indications appears, as shown in Figure 8-15.
Page 403 Installation and Commissioning The first time a button is clicked in the Action column to send a message, Password No. 6 (for hardware test menus) is requested. After correct input of the password, mes- sages can be individually transmitted. To send a message, click on the Action button of the corresponding line.
Page 404: Final Preparation Of The Device
Installation and Commissioning Final Preparation of the Device Verify all terminal screws are tight and secure. Do not overtighten. Ensure that all pin connectors are properly inserted. Verify the wires to the terminals are tightly connect- ed. Make sure the communication cables are firmly connected; however, do not over- tighten the screws.
Page 405: Routine Checks And Maintenance
Routine Checks and Maintenance General comments about the maintenance activities to ensure the high reliability of the 7SJ62 are given in this section. Simple routine checks and a procedure for replacing the battery are discussed. Troubleshooting advice is provided. A procedure for replac- ing the power supply fuse is described.
Page 406: General
Routine Checks and Maintenance General ® Siemens numerical protective and control SIPROTEC 4 devices require no special maintenance. All measurement and signal processing circuits are fully solid state. All input modules are also fully solid state. The output relays are hermetically sealed or provided with protective covers.
Page 407: Routine Checks
Routine Checks and Maintenance Routine Checks Routine checks of the characteristic curves or pickup values of the protective elements are not necessary because they form part of the continuously supervised firmware programs. The normally scheduled interval for substation maintenance can be used for carrying out operational testing of the protective and control equipment.
Page 408: Maintenance
Routine Checks and Maintenance Maintenance 9.3.1 Replacing the Battery The battery is used to retain the annunciation memory and waveform data in the event of an interruption of the power supply. The battery also maintains the internal system clock with calendar after a loss of the power supply. The battery is checked by the processor at regular intervals.
Page 409 Routine Checks and Maintenance 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 part before handling the internal components. Warning! Hazardous voltages can exist in the device, even after disconnecting the power supply or withdrawing the boards! Capacitors can be charged.
Page 410 Routine Checks and Maintenance Observing the polarity and firmly insert the new battery into the snap-on connector shown in Figure 9-1. Connect the ribbon-cable between the CPU (¯) board and the front panel. Be espe- cially careful not to bend any of the connector pins! Do not use any force! Be sure that the plug connectors latch.
Page 411: Troubleshooting
PC after commissioning (refer to Section 8.4). The device is then in-service. Further Assistance If these steps do not resolve the problem, please call your local Siemens representa- tive or customer hotline. Our customer hotline needs the following information to assist you:...
Page 412 Routine Checks and Maintenance − the complete MLFB (order number) of the device − the serial number of the device (BF...) − the firmware version − the bootsystem version ® This information is found in the device file which can be retrieved using DIGSI 4 as shown in Figure 9-4.
Page 413: Corrective Action/Repairs
Routine Checks and Maintenance Corrective Action/Repairs 9.5.1 Software Procedures A restart of the processor system, as described in Section 9.2, can be done as an at- tempt to solve a problem. Setting changes can be made to solve simple problems, such as sporadic alarms from elements of the measured-value-supervision.
Page 414 Routine Checks and Maintenance Remove the corner covers on the front panel and loosen the screws that are holding the front panel to the device case. Carefully pull off the front panel. The component is connected to the CPU board with a short ribbon-cable.
Page 415 Routine Checks and Maintenance B20 B24 B21 B22 B23 B25 B26 B27 T 2.0/250 G Figure 9-5 Power Supply Fuse on the Processor Printed Circuit Board CPU Install a new fuse in the holder. Carefully install the CPU board in the case. The position for the board is shown in Fig- ure 9-1.
Page 416 Routine Checks and Maintenance Attach all Align all D-subminiature plugs to the matching D-subminiature sockets. Screw in the fiber optic cables where applicable. 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.
Page 417: Return
Routine Checks and Maintenance Return Siemens strongly recommends that no further repairs on defective devices, boards, or components be done. Special electronic components are used for which proce- dures for preventing electrostatic discharges must be followed. Most importantly, spe- cial production techniques are necessary to avoid damaging the wave-soldered multi- layer board, the sensitive components, and the protective varnish.
Page 418 Routine Checks and Maintenance 9-14 7SJ62 Manual C53000-G1140-C121-1...
Page 419: Technical Data
Technical Data ® This chapter provides the technical data of the SIPROTEC 4 7SJ62 device and the individual functions of the device, including the limiting values that under no circum- stances may be exceeded. The electrical and functional data are followed by the me- chanical data, with dimensional drawings of 7SJ62 devices equipped with all options.
Page 420: General Device Data
Technical Data 10.1 General Device Data 10.1.1 Analog Inputs and Outputs Nominal Frequency 50 Hz or 60 Hz (adjustable) Current Inputs Nominal Current 1 A or 5 A ≤ 1.6 A Ground Current, SensitiveI Burden per Phase and Ground Path –...
Page 421: Binary Inputs And Outputs
Technical Data Alternative Voltage Voltage Supply via Integrated Converter Nominal Power Supply Alternating Voltage 115 V 230 V Permissible Voltage Ranges 92 to 132 V 184 to 265 V Power Consumption, Quiescent approx. 3 VA approx. 3 VA Power Consumption, Energized approx.
Page 422: Communications Interfaces
Technical Data Switching Voltage 250 V Permissible Current 1 A continuous ) UL–listed with the following nominal value: 120 V ac Pilot duty, B300 240 V ac Pilot duty, B300 240 V ac 5 A General Purpose 24 V dc 5 A General Purpose 48 V dc 0.8 A General Purpose...
Page 423 Technical Data – Laser Class 1 Under EN 60825–1/ –2 using glass fiber 50/125 µm or using glass fiber 62.5/125 µm max. 8 dB, with glass fiber 62.5/125 µm – Optical Link Signal Attenuation – Channel Distance max. 1.5 km (0.95 miles) –...
Page 424: Electrical Tests
Technical Data For Panel Surface- Mounted Case on the case bottom – Transmission Speed up to 1.5 M Baud recommended: > 500 k Baud λ = 820 nm – Optical Wavelength – Laser class 1 Under EN 60825–1/ –2 using glass fiber 50/125 µm or using glass fiber 62.5/125 µm max.
Page 425 Technical Data – High Voltage Test (routine test) 500 V (rms) AC Only Isolated Communications and Time Synchronization Interfaces 5 kV (peak): 1.2/50 µs: 0.5 Ws: 3 positive – Impulse Voltage Test (type test) All Circuits Except Communications and 3 negative surges in intervals of 5 s and Time Synchronization Interfaces, Class III EMC Tests for Im-...
Page 426: Mechanical Stress Tests
Technical Data – Damped Oscillations 2.5 kV (Peak Value), polarity alternating similar to IEC 60694–4–12, 100 kHz, 1 MHz, 10 MHz and 50 MHz, = 200 Ω IEC 61000–4–12 EMC Tests For Standard: EN 50081–1 (Generic Standard) Noise Emission – Radio Noise Voltage to Lines, 150 kHz to 30 MHz (type test) Only Power Supply Voltage...
Page 427: Climatic Stress Tests
56 days of the year up to 93% relative humidity. CONDENSATION MUST BE AVOIDED Siemens recommends that all devices be installed such that they are not exposed to direct sunlight, nor subject to large fluctuations in temperature that may cause conden- sation to occur.
Page 428: Construction
Technical Data • Do not withdraw or insert individual modules while the protective device is ener- gized. When handling the modules or the device outside of the case, standards for components sensitive to electrostatic discharge (ESD) must be observed. The mod- ules and device are not endangered when inserted into the case.
Page 429: Definite-Time Overcurrent Protection (50 And 50N Elements)
Technical Data 10.2 Definite-Time Overcurrent Protection (50 and 50N Elements) Pickup and Time Pickup Current 50–1 (phases) 0.50 A to 175.00 A )(increments 0.05 A) or ∞ (ineffective, no pickup) Delay Ranges/ Resolutions Pickup Current 50N–1 (ground)0.25 A to 175.00 A )(increments 0.05 A) or ∞...
Page 430: Inverse-Time Overcurrent Protection (51 And 51N Elements)
Technical Data 10.3 Inverse-Time Overcurrent Protection (51 and 51N Elements) Pickup and Time Pickup Current 51, 51N 0.50 A to 20.00 A ) (Increments 0.05 A) Multiplier Ranges/ Time Multipliers for 0.05 s to 3.20 s (Increments 0.01 s) Resolutions or ∞...
Page 431 Technical Data t [s] t [s] 0.05 0.05 0.05 0.05 13.5 0.14 ⋅ ⋅ Very inverse: Normal Inverse: --------------------------- - T ------------------------------------- - T 0.02 ⁄ (Type A) (Type B) I I p ⁄ – – 1000 t [s] t [s] 0.1 0.2 0.05 0.05...
Page 432 Technical Data Trip Time Charac- As per ANSI/IEEE (see also Figures 10-2 and 10-3) teristics As Per ANSI   8.9341 ⋅   ,19(56( 0.17966 -------------------------------------- -  2.0938  ⁄ –   0.2663 ⋅   6+257 ,19(56( -------------------------------------- - 0.03393 ...
Page 433 Technical Data Reset Time Charac- teristic As Per ANSI   $16, ,19(56( ⋅   -------------------------------------- - Reset  2.0938  ⁄ –   0.831 $16, 6+257 ,19(56( ⋅   -------------------------------------- - Reset  1.2969  ⁄ –...
Page 434 Technical Data t [s] t [s] D [s] D [s] 0.07 0.07 0.05 0.05     INVERSE 8.9341 SHORT INVERSE   0.2663   ⋅ ⋅ 0.17966 ------------------------------------------ - 0.03393 ------------------------------------------ -     2.0938 1.2969 ⁄...
Page 435 Technical Data t [s] t [s] D [s] D [s] 0.05 0.05     3.922   5.64 ⋅   0.0982 --------------------------- - ⋅   0.02434 --------------------------- -   VERY INVERSE EXTREMELY INVERSE ⁄  ...
Page 436: Directional Time Overcurrent Protection (67 And 67N Elements)
Technical Data 10.4 Directional Time Overcurrent Protection (67 and 67N Elements) Overcurrent Ele- The same specifications and characteristics apply as for non-directional time overcur- ments rent protection (see Sub-sections 10.2 and 10.3). Determining Direc- Moreover, the following data apply for determining fault direction: tion For Phase Faults Polarization...
Page 437: Dynamic Cold Load Pick-Up Function (50C, 50Nc, 51Nc, 67C, 67Nc)
Technical Data 10.5 Dynamic Cold Load Pick-up Function (50c, 50Nc, 51Nc, 67c, 67Nc) Timed Changeover Controlled Elements Directional and non-directional time over- of Settings current protective elements (separate phase andground settings) Initiation Criteria Current Criteria“BkrClosed I MIN” or Binary input controlled, for example, by 52/b contact Timing 3 time levels (T...
Page 438: Sensitive Ground Fault Detection (64, 50Ns, 67Ns)
Technical Data 10.7 Sensitive Ground Fault Detection (64, 50Ns, 67Ns) Displacement Volt- Displacement Voltage, Measured Ve> 1.8 V to 130.0 V (increments 0.1V) age Element Char- Displacement Voltage, Calculated >10.0 V to 225.0 V (increments 0.1V) acteristics - For all Types of Ground Pickup Delay Time 0.04 s to 320.00 s...
Page 439 Technical Data Dropout Threshold approx. 1.05 · I for I > 50 mA Measurement Tolerance 2 % of setting value or 1 mA 7% of reference value for 2 ≤ I/I ≤ 20 Operating Time Tolerance in the Linear Range + 2% current tolerance, or 70 ms Influencing Vari- Power supply direct voltage in range...
Page 440: Negative Sequence Protection (46)
Technical Data 10.8 Negative Sequence Protection (46) 10.8.1 Definite–Time Elements (46-1 and 46-2) Pickup and Time Pickup Current 46-1 0.50 A to 15.00 A )(Increments 0.05 A) or ∞ (ineffective, no pickup) Delay Ranges/ Resolutions Pickup Current 46-2 0.50 A to 15.00 A )(Increments 0.05 A) or ∞...
Page 441 Technical Data Time Trip Charac- See also Figure10-4 teristics As Per 0.14 ⋅ ,(& 1250$/ ,19(56( --------------------------------------- - T IEC 60255–3 0.02 ⁄ – 13.5 ,(& 9(5< ,19(56( ⋅ --------------------------------- T ⁄ – ⋅ ,(& (;75(0(/< ,19(56( --------------------------------- T ⁄ –...
Page 442 Technical Data Reset Time Charac- teristics As Per   $16, ,19(56( ⋅   ANSI --------------------------------------------- Reset   2.0938 ⁄ –   0.97 $16, 02'(5$7(/< ⋅   --------------------------------- Reset   ⁄ ,19(56( –   4.32 ⋅...
Page 443 Technical Data t [s] t [s] 0.05 0.05 0.05 0.05 0.14 13.5 ⋅ IEC NORMAL INVERSE: -------------------------------------------- - T ⋅ IEC VERY INVERSE: ----------------------------------- - T 0.02 ⁄ ⁄ – I 2 I 2p – t [s] = Trip time in seconds = Setting value of the time multiplier = Negative Sequence Current = Setting value of the pickup current...
Page 444 Technical Data t [s] t [s] 0.07 0.07 0.05 0.05     8.9341    0.0103  ⋅ 0.17966 ⋅ ANSI INVERSE: -------------------------------------------------- - D I2p 0.0228   ANSI MODERATELY INV.: -------------------------------------------- - D I2p  ...
Page 445: Motor Starting Protection (48)
Technical Data 10.9 Motor Starting Protection (48) Setting Ranges/In- Motor Starting Current 5.00 A to 80.00 A ) (Increments 0.05 A) STARTUP crements Pickup Threshold 3.00 A to 50.00 A )(Increments 0.05 A) MOTOR START Permissible Starting Time T 1.0 to 180.0 s (Increments 0.1 s) STARTUP Permissible Locked Rotor Time T...
Page 446: Thermal Overload Protection (49)
Technical Data 10.10 Thermal Overload Protection (49) Setting Ranges/ K-Factor per IEC 60255-8 0.10 to 4.00 (Increments 0.01) Resolutions τ Time Constant 1.0 min to 999.9 min (Increments 0.1 min) Θ Thermal Alarm /Θ 50% to 100% of the trip temperature rise Alarm Trip (Θ...
Page 447 Technical Data t [min] t [min] Parameter: Setting Value of Time Con- stant τ [min] 1000 Parameter: Setting Value of Time Con- stant τ [min] 1000 0.05 0.05 6 7 8 10 12 6 7 8 10 12 · · without pre-load: with 90 % pre-load: ...
Page 448: Start Inhibit For Motors (66/68)
Technical Data 10.11 Start Inhibit for Motors (66/68) Setting Ranges / Starting Current 3.0 to 10.0 (Increments 0.1) Start Motor nom Resolutions Relative to Nominal Motor Current Nominal Motor Current 1.0 A to 6.0 A (Increments 0.5 A) Motor nom Maximum Permissible 3 s to 120 s (Increments 1 s)
Page 449: Voltage Protection (27 And 59)
Technical Data 10.12 Voltage Protection (27 and 59) Setting Ranges / Undervoltage 27-1, 27-2 Measurement Quantities: Resolution PositiveSequence Voltages - Pickup Voltage, 30 V to 210 V (Increments 1 V) phase-ground voltages - Pickup Voltage 30 V to 120 V (Increments 1 V) phase-phase voltages Dropout Ratio for 27-1...
Page 450: Frequency Protection (81 Over-Frequency And Under-Frequency)
Technical Data 10.13 Frequency Protection (81 Over-Frequency and Under-Frequency) Setting Ranges/ Number of Frequency Elements 4: each can be 81/O or 81/U Resolutions Pickup Frequency 81–1 to 81–4 45.50 Hz to 54.50 Hz (Increments 0.01 Hz) = 50 Hz 81–1 to 81–4 55.50 Hz to 64.50 Hz(Increments 0.01 Hz) = 60 Hz Time Delay...
Page 451: Breaker Failure Protection (50Bf)
Technical Data 10.14 Breaker Failure Protection (50BF) Pickup and Time Pickup of 50 Element BkrClosed I MIN 0.20 A to 5.00 A ) (Increments 0.05 A) Delay Ranges/ Time Delay TRIP-Timer 0.06 s to 60.00 s (Increments 0.01 s) Resolutions or ∞...
Page 452: Automatic Reclosing System (79M)
Technical Data 10.15 Automatic Reclosing System (79M) Number of Reclosures 0 to 9 (for both phase and ground) Shots 1 to 4 individually adjustable For Phase Faults-Processing 79 Initiates: Selectable 50-1, 50-2, 51, 67-1, 67-2, 67-TOC, 46-1, 46-2, 46-TOC, Binary Inputs For Ground Faults-Processing 79 Initiates: Selectable 50-1, 50-2, 51, 67-1, 67-2, 67-TOC,...
Page 453: Fault Location
Technical Data 10.16 Fault Location Secondary Ω, Units of Distance Measurement Miles or km of line length Trigger Trip command, Pickup of an Element, Dropout of an Element, or External command via binary input Reactance Setting (secondary) 0.005 to 6.215Ω/km (Increments 0.001 Ω/km) 0.010 to 10.000 Ω/mile Reactance Setting (secondary)
Page 454: Additional Functions
Technical Data 10.18 Additional Functions Operational Mea- Operating Measured Values for Currents in A or kA primary; in A secondary, sured Values – Ia, Ib, Ic or in % of I - Range 10% to 200% I - Tolerance 1% of measure value or 0.5 % of I –...
Page 455 Technical Data Operating Measured Values for Power Factor – cos ϕ - Range -1 to 1 5% for |cos ϕ| ≥ 0.707 - Tolerance Counter Values for Energy – Wp, Wq (real and reactive energy) in kWh (MWh or GWh) and in kVARh (MVARh or GVARh) - Range digits (28 bit) for VDEW protocol...
Page 456 Technical Data Min/Max Values for Averages Admd Bdmd Cdmd 1dmd (positive sequence) (LOG of Primary Values) Measured Values Current Asymmetry > I - balance factor, for I > I - bal- Supervision ance limit. Factor and limit are adjustable. Voltage Asymmetry >...
Page 457 Technical Data Trip Circuit Monitor With one or two binary inputs. (74TC) Commissioning Phase Rotation Field Check Start-up Aids Operating Measured Values Circuit Breaker / Switching Device Test Creation of a Test Measurement Report Clock Time Synchronization IRIG-B/DCF77-signal Binary signal Communication 10-39 7SJ62 Manual...
Page 458: Dimensions
Technical Data 10.19 Dimensions Panel and Cubical Installation 1.16 1.34 1.16 1.14 6.77 6.77 5.90 5.70 Mounting plate Mounting plate 0.08 0.08 1.34 Side view (with threaded terminals) Side view (with plug-in terminals) Rear view + 0.08 5.75 0.2 diameter 0.24 diameter ±...
Page 459 Technical Data Panel Mounting 0.41 5.67 10.24 1.16 0.36 2.05 diameter Front view Side view Dimensions in inches Figure 10-8 Dimensional Drawing Of A 7SJ62 For Panel Mounting 10-41 7SJ62 Manual C53000-G1140-C121-1...
Page 460 Technical Data 10-42 7SJ62 Manual C53000-G1140-C121-1...
Page 461: Appendix
Appendix This appendix is primarily a reference for the experienced user. This section provides ordering information for the models of 7SJ62. General diagrams indicating the termi- nal connections of the 7SJ62 models are included. Following the general diagrams are diagrams that show the proper connections of the device to primary equipment in many typical power system configurations.
Page 462: Ordering Information And Accessories
Appendix Ordering Information and Accessories 9 10 11 12 15 16 SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ62 Number of Binary Inputs and Outputs 8 Binary Inputs, 8 Binary Outputs, 1 Live Status Contact 11 Binary Inputs, 6 Binary Outputs, 1 Live Status Contact Nominal Current = 1 A = 5 A...
Page 463 Appendix 9 10 11 12 15 16 SIPROTEC 4 Multifunction Protection with Controls Order No. 7SJ62 Protective Elements and Control Basic Elements: Controls (included in all versions) Time-overcurrent protection phase 50-1, 50-2, 51 and Time-overcurrent protection ground 50N-1, 50N-2, 51N, Overload protection (with 2 time constants) 49, Negative sequence protection 46-1, 46-2, 46-TOC, Circuit breaker failure protection,...
Page 464: Accessories
Appendix A.1.1 Accessories Terminal Block Co- vering Caps Covering cap for terminal block type Order No. 18 terminal voltage, 12 terminal current block C73334-A1-C31-1 12 terminal voltage, 8 terminal current block C73334-A1-C32-1 Short Circuit Links Short circuit links for terminal type Order No.
Page 465 Appendix Graphical Analysis Software for graphical visualization, analysis, and evaluation of fault data. Option pak- ® Program DIGRA kage of the complete version of DIGSI ® Order No. Graphical analysis program DIGRA Full version with license for 10 PCs 7XS5410-0AA0 Display Editor Software for creating basic and power system control pictures.
Page 466: Elementary Diagrams
Appendix Elementary Diagrams A.2.1 Panel Flush Mounting or Cubicle Mounting ∗D/E − 7SJ621∗ 52 Breaker, Relay TRIP 52 Breaker, 79 Close 52 Breaker, 79 Close Measurement Supervision Relay PICKUP Vc/VG >Block 50-2, >Block 50N-2 >Reset LED Live Status Contact >Light on Power Supply >52–b, 52 Breaker...
Page 467 Appendix ∗D/E − 7SJ622∗ 52 Breaker, Relay TRIP 52 Breaker, 79 Close 52 Breaker, 79 Close Measurement Supervision Relay PICKUP Vc/VG >Block 50-2, >Block 50N-2 >Reset LED Live Status Contact >Light on Power Supply >52–b, 52 Breaker >52–a, 52 Breaker Rear SCADA Port Rear Service...
Page 468: Panel Surface Mounting
Appendix A.2.2 Panel Surface Mounting ∗B − 7SJ621∗ 52 Breaker, Relay TRIP 52 Breaker, 79 Close 52 Breaker, 79 Close Measurement Supervision Relay PICKUP Vc/VG >Block 50-2, >Block 50N-2 >Reset LED Live Status Contact >Light on L+ (V+) Power Supply >52–b, 52 Breaker L–...
Page 469 Appendix ∗B − 7SJ622∗ 52 Breaker, Relay TRIP 52 Breaker, 79 Close 52 Breaker, 79 Close Measurement Supervision Relay PICKUP Vc/VG >Block 50-2, >Block 50N-2 >Reset LED Live Status Contact >Light on L+ (V+) Power Supply >52–b, 52 Breaker L– (V–) >52–a, 52 Breaker BI10 Assignment of Pins...
Page 470 Appendix ∗B − 7SJ62∗∗ Channel B Profibus RS232 RS485 Optical Rear SCADA – Port Electrical – Channel C RS232 RS485 Optical – Rear Service Port Electrical – IN 12 V COMMON Time IN 5 V Synchronization IN 24 V Shield Figure A-5 Connection Diagram For 7SJ62∗∗–∗B (Panel Surface Mounted) A-10 7SJ62 Manual...
Page 471: Connection Examples
Appendix Connection Examples Panel Surface Mounted Flush-mounted/Cubicle 7SJ62 Figure A-6 Current connections to three current transformers with a starpoint connection for ground current(Grounded-Wye Connection with residual Neutral Current), nor- mal circuit layout – appropriate for all networks. Panel Surface Mounted Flush-mounted/Cubicle 7SJ62 Figure A-7...
Page 472 Appendix Panel Surface Mounted Flush-mounted/Cubicle 7SJ62 Important! Cable shield grounding must be done on the cable side! Note: Change of Address 0201 setting changes polarity of 3I Current Input ! Figure A-8 Current connections to three current transformers and a core balance neutral current transformer for ground current - preferred for effectively or low-resistance grounded networks Panel Surface Mounted...
Page 473 Appendix Panel Surface Mounted Flush-mounted/Cubicle 7SJ62 Important! Cable shield grounding must be done on the cable side! Note: Change of Address 0201 setting changes polarity of I Current Input ! Figure A-10 Current connections to three current transformers – core balance neutral current transformers for sensitive ground fault detection.
Page 474 Appendix Busbar Panel Surface Mounted Flush-mounted/Cubicle Va-b Vc-b 7SJ62 Figure A-12 Current and voltage connections to three current transformers, two voltage trans- formers (phase-phase) and open delta VT for 3V , appropriate for all networks. Busbar Panel Surface Mounted Flush-mounted/Cubicle Va-b Vc-b 7SJ62...
Page 475 Appendix Busbar If only 2 VTs are present on system side, device should be connected in open delta, short unused voltage input. Panel Surface Mounted Flush-mounted/Cubicle Va-b Vc-b 7SJ62 Figure A-14 Current and voltage connections to three current transformers with starpoint con- nection(Grounded-Wye Connection with residual Neutral Current), two voltage transformers, for ungrounded or compensated networks.
Page 476 Appendix Busbar Panel Surface Mounted Flush-mounted/Cubicle Va-b Vc-b 7SJ62 Important! Cable shield grounding must be done on the cable side! Note: Change of Address 0201 setting changes polarity of I Current Input ! Figure A-15 Current and voltage connections to three current transformers, core balance neu- tral current transformers and open delta voltage transformers, maximum preci- sion for sensitive ground fault detection.
Page 477: Settings
Appendix Settings NOTE: The following table lists all data which are available in the maximum complement of the device. Depen- dent on the ordered model, only those data may be present which are valid for the individual version. Addr. Setting Title Setting Options Default Setting Comments...
Page 478 Appendix Addr. Setting Title Setting Options Default Setting Comments 1102 I PRIMARY OP. 10..50000 A 100 A Primary Operating Current 1103 RG/RL Ratio -0.33..7.00 1.00 RG/RL - Ratio of Gnd to Line Resi- stance 1104 XG/XL Ratio -0.33..7.00 1.00 XG/XL - Ratio of Gnd to Line Reac- tance 1105 x’...
Page 479 Appendix Addr. Setting Title Setting Options Default Setting Comments 1305 50N-1 DELAY 0.00..60.00 sec 0.50 sec 50N-1 Time Delay 1307 51N PICKUP 0.50..20.00 A 1.00 A 51N Pickup 1308 51N TIME DIAL 0.05..3.20 sec 0.20 sec 51N Time Dial (IEC) 1309 51N TIME DIAL 0.50..15.00...
Page 480 Appendix Addr. Setting Title Setting Options Default Setting Comments 1513 MANUALCLOSEMODE 67-2 instantaneously 67-2 instantane- Manual Close Mode 67-1 instantaneously ously 67-TOC instantane- ously Inactive 1514 67 active with 79 active always 67 active always 1515 Normal Load Inductive (135°) Inductive (135°) Normal Load (Torque angle of dir.
Page 481 Appendix Addr. Setting Title Setting Options Default Setting Comments 1630 M.of PU TD Multiples of PU Time-Dial 1631 I/IEp Rf T/TEp 67N TOC 1701 COLDLOAD PICKUP Cold-Load-Pickup Function 1702 Start Condition No Current No Current Start Condition Breaker Contact 1703 CB Open Time 0..21600 sec 3600 sec...
Page 482 Appendix Addr. Setting Title Setting Options Default Setting Comments 2202 2nd HARMONIC 10..45 % 15 % 2nd. harmonic in % of fundamental 2203 CROSS BLOCK Cross Block 2204 CROSS BLK TIMER 0.00..180.00 sec 0.00 sec Cross Block Time 2205 I Max 1.50..125.00 A 37.50 A Maximum Current for Inrush Res-...
Page 483 Appendix Addr. Setting Title Setting Options Default Setting Comments 4001 FCT 46 46 Negative Sequence Protection 4002 46-1 PICKUP 0.50..15.00 A 0.50 A 46-1 Pickup 4003 46-1 DELAY 0.00..60.00 sec 1.50 sec 46-1 Time Delay 4004 46-2 PICKUP 0.50..15.00 A 2.50 A 46-2 Pickup 4005...
Page 484 Appendix Addr. Setting Title Setting Options Default Setting Comments 5001 FCT 59 59 Overvoltage Protection Alarm Only 5002 59-1 PICKUP 40..225 V 110 V 59-1 Pickup 5003 59-1 PICKUP 40..130 V 110 V 59-1 Pickup 5004 59-1 DELAY 0.00..60.00 sec 0.50 sec 59-1 Time Delay 5101...
Page 485 Appendix Addr. Setting Title Setting Options Default Setting Comments 7005 TRIP-Timer 0.06..60.00 sec 0.25 sec TRIP-Timer 7101 FCT 79 79 Auto-Reclose Function 7103 BLK MAN. CLOSE Block Manual close 7105 TIME RESTRAINT 0.50..320.00 sec 3.00 sec 79 Auto Reclosing reset time 7108 SAFETY 79 ready 0.01..300.00 sec...
Page 486 Appendix Addr. Setting Title Setting Options Default Setting Comments 7155 67-TOC/67N-TOC No influence No influence 67-TOC, 67N-TOC Starts 79 Stops 79 7156 sens Ground Flt No influence No influence Sensitive Ground Fault Starts 79 Stops 79 7157 No influence No influence Starts 79 Stops 79 7158...
Page 487 Appendix Addr. Setting Title Setting Options Default Setting Comments 7182 4.Cy: 50(N)-1 Not Blocked Not Blocked 4. Cycle: 50-1, 50N-1 Blocked Via 79 Auto Recl. 7183 4.Cy: 50(N)-2 Not Blocked Not Blocked 4. Cycle: 50-2, 50N-2 Blocked Via 79 Auto Recl.
Page 488: Interoperability List
Appendix Interoperability List Physical layer Electrical interface EIA RS-485 Number of loads for one equipment: 32 Optical interface Glass fibre F-SMA type connector Plastic fibre BFOC/2,5 type connector Transmission speed 9600 bit/s 19200 bit/s Link layer There are no choices for the link layer Application layer Transmission mode for application data Mode 1 (least significant octet first) as defined in 4.10 of IEC 60870-5-4...
Page 489 Appendix 3.4.3 Generic functions in control direction Read headings of all defined groups Read values of all entries of one group Read directory of a single entry Read value of a single entry General interrogation of generic data Write entry Write entry with confirmation Write entry with execution Write entry abort...
Page 490: Information List
Information List NOTE: The following table lists all data which are available in the maximum complement of the device. Dependent on the ordered model, only those data may be present which are valid for the individual version. The symbol ’ > ’ indicates that the source of the indication is a binary input. –...
Page 491 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Device is Operational and Protecting O/O GI 135 81 (Device OK) At Least 1 Protection Funct. is Active IntSP O/O GI 160 18 (ProtActive) Reset Device (Reset Device) O/O GI Initial Start of Device (Initial Start) O/O GI...
Page 492 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Error 0V (Error 0V) O/O GI Error -5V (Error -5V) O/O GI Error Power Supply (Error PwrSupply) O/O GI Failure: Battery empty (Fail Battery) O/O GI Setting calculation is running (Settings O/O GI 160 22...
Page 493 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Clock Synchronization (SynchClock) IntSP_Ev O/O GI 5145 >Reverse Phase Rotation (>Reverse LED BI O/O GI Rot.) 5147 Phase rotation ABC (Rotation ABC) O/O GI 128 1 5148 Phase rotation ACB (Rotation ACB) O/O GI 129 1...
Page 494 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Wp Forward MVMV 133 51 Wq Forward MVMV 133 52 Wp Reverse MVMV 133 53 Wq Reverse MVMV 133 54 Pulsed Energy Wp (active) 133 55 Pulsed Energy Wq (reactive) 133 56 Primary fault current Ia (Ia =)
Page 495 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1761 50(N)/51(N) O/C PICKUP (50(N)/51(N) 160 84 1791 50(N)/51(N) TRIP (50(N)/51(N)TRIP) O/O GI 160 68 1704 >BLOCK 50/51 (>BLK 50/51) LED BI O/O GI 1721 >BLOCK 50-2 (>BLOCK 50-2) LED BI O/O GI 1722 >BLOCK 50-1 (>BLOCK 50-1)
Page 496 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1815 50-1 TRIP (50-1 TRIP) O/O GI 160 90 1820 51 picked up (51 picked up) O/O GI 1825 51 TRIP (51 TRIP) O/O GI 1866 51 Disk emulation Pickup (51Disk PU) O/O GI 1804 50-2 Time Out (50-2 TimeOut) O/O GI...
Page 497 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1833 50N-2 TRIP (50N-2 TRIP) O/O GI 160 93 1834 50N-1 picked up (50N-1 picked up) O/O GI 1836 50N-1 TRIP (50N-1 TRIP) O/O GI 160 92 1837 51N picked up (51N picked up) O/O GI 1839 51N TRIP (51N TRIP)
Page 498 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1842 Phase C trip blocked by inrush detection O/O GI 103 2 (PhC InrushBlk) 1843 Cross blk: PhX blocked PhY (INRUSH O/O GI 104 2 X-BLK) 7551 50-1 InRush picked up (50-1 InRushPU) OUT O/O GI 7552 50N-1 InRush picked up (50N-1 InRus-...
Page 499 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 7565 Phase A InRush picked up (Ia InRush O/O GI 7566 Phase B InRush picked up (Ib InRush O/O GI 7567 Phase C InRush picked up (Ic InRush O/O GI 7564 Ground InRush picked up (Gnd InRush O/O GI...
Page 500 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 2660 67-1 picked up (67-1 picked up) O/O GI 2665 67-1 TRIP (67-1 TRIP) O/O GI 2670 67-TOC picked up (67-TOC pickedup) O/O GI 2675 67-TOC TRIP (67-TOC TRIP) O/O GI 2692 67/67-TOC Phase A picked up (67 A O/O GI...
Page 501 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 2655 67-2 is BLOCKED (67-2 BLOCKED) O/O O/O O/O GI 2669 67-TOC is BLOCKED (67-TOC BLOK- O/O O/O O/O GI KED) 2676 67-TOC disk emulation is ACTIVE (67- O/O GI TOC DiskPU) 2614 >BLOCK 67N/67N-TOC (>BLK 67N/...
Page 502 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 2684 67N-TOC picked up (67N-TOCPicke- O/O GI dup) 2686 67N-TOC TRIP (67N-TOC TRIP) O/O GI 2695 67N/67N-TOC picked up (67N picked O/O GI 2648 67N-2 Time Out (67N-2 Time Out) O/O GI 2682 67N-1 Time Out (67N-1 Time Out) O/O GI...
Page 503 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1994 Cold-Load-Pickup switched OFF (CLP O/O GI 244 1 OFF) 1995 Cold-Load-Pickup is BLOCKED (CLP O/O O/O O/O GI 245 1 BLOCKED) 1996 Cold-Load-Pickup is RUNNING (CLP O/O GI 246 1 running)
Page 504 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 6533 27-1 Undervoltage picked up (27-1 pik- O/O GI ked up) 6534 27-1 Undervoltage PICKUP w/curr. O/O GI superv (27-1 PU CS) 6537 27-2 Undervoltage picked up (27-2 pik- O/O GI ked up) 6538 27-2 Undervoltage PICKUP w/curr.
Page 505 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 5151 46 switched OFF (46 OFF) O/O GI 131 1 5152 46 is BLOCKED (46 BLOCKED) O/O O/O O/O GI 132 1 5153 46 is ACTIVE (46 ACTIVE) O/O GI 133 1 5159 46-2 picked up (46-2 picked up)
Page 506 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 6823 Startup supervision Pickup (START- O/O GI 169 56 SUP pu) 4822 >BLOCK Motor Startup counter LED BI O/O GI (>BLOCK 66) 4823 >Emergency start (>66 emer.start) LED BI O/O GI 168 51...
Page 507 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 5214 81 Under Voltage Block (81 Under V O/O O/O O/O GI 184 1 Blk) 5232 81-1 picked up (81-1 picked up) O/O GI 230 2 5233 81-2 picked up (81-2 picked up) O/O GI 231 2...
Page 508 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1515 49 Overload Current Alarm (I alarm) (49 O/O GI 167 15 O/L I Alarm) 1516 49 Overload Alarm! Near Thermal Trip O/O GI 167 16 (49 O/L Θ...
Page 509 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 6510 >Failure: Busbar VT (>FAIL: BUS VT) LED BI O/O GI 6575 Voltage Transformer Fuse Failure (VT O/O GI Fuse Failure) 6851 >BLOCK 74TC (>BLOCK 74TC) LED BI O/O GI 6853 >74TC Trip circuit superv.: bkr relay...
Page 510 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1207 >BLOCK 50Ns/67Ns (>BLK 50Ns/67Ns) SP LED BI O/O GI 151 107 1 1211 50Ns/67Ns is OFF (50Ns/67Ns OFF) O/O GI 151 111 1 1212 50Ns/67Ns is ACTIVE (50Ns/67Ns O/O GI 151 112 1 ACT)
Page 511 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1276 Sensitive Gnd fault in forward direction O/O O O/O GI 160 51 (SensGnd Forward) 1277 Sensitive Gnd fault in reverse direction O/O O O/O GI 160 52 (SensGnd Reverse) 1278 Sensitive Gnd fault direction undefined...
Page 512 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 2781 79 Auto recloser is switched OFF (79 O/O GI OFF) 2782 79 Auto recloser is switched ON (79 IntSP O/O GI 160 16 2784 Circuit breaker is NOT ready (CB is NOT O/O O/O O/O GI 160 130 1...
Page 513 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 2884 Zone sequence coordination switched O/O GI ON (ZSC ON) 2885 Zone sequence coordination switched O/O GI OFF (ZSC OFF) 79 ON/OFF (via system port) (79 ON/ IntSP O/O GI OFF)
Page 514 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1451 50BF is switched OFF (50BF OFF) O/O GI 166 151 1 1452 50BF is BLOCKED (50BF BLOCK) O/O O/O O/O GI 166 152 1 1453 50BF is ACTIVE (50BF ACTIVE) O/O GI 166 153 1 1456 50BF (internal) PICKUP (50BF int PU)
Page 515 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Interlocking: 52 Open (52 Open) IntSP Interlocking: 52 Close (52 Close) IntSP Interlocking: Disconnect switch Open IntSP (Disc.Open) Interlocking: Disconnect switch Close IntSP (Disc.Close) Interlocking: Ground switch Open IntSP (GndSw Open) Interlocking: Ground switch Close...
Page 516 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 >Cabinet door open (>Door open) LED BI REL OM O/O GI 101 1 >CB waiting for Spring charged (>CB LED BI REL OM O/O GI 101 2 wait) >No Voltage (Fuse blown) (>No Volt.) LED BI...
Page 517 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Vb (Vb =) O/O GI 134 137 Vc (Vc =) O/O GI 134 137 Va-b (Va-b=) O/O GI Vb-O (Vb-c=) O/O GI 134 137 Vc-a (Vc-a=) O/O GI 134 137 VN (VN =)
Page 518 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Reactive ground current in isol systems O/O GI 134 137 (INs Reac) Temperature of Stator (Θ Stator) O/O GI Temperature of Rotor (Θ Rotor) O/O GI I A demand (Ia dmd=) O/O GI I B demand (Ib dmd=)
Page 519 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Ia Max (Ia Max=) O/O GI Ib Min (Ib Min=) O/O GI Ib Max (Ib Max=) O/O GI Ic Min (Ic Min=) O/O GI Ic Max (Ic Max=) O/O GI I1 (positive sequence) Minimum (I1 O/O GI...
Page 520 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 >V MIN/MAX Buffer Reset (>V MiMaRe- O/O GI set) >Vphph MIN/MAX Buffer Reset (>Vph- O/O GI phMiMaRes) >V1 MIN/MAX Buffer Reset (>V1 MiMa O/O GI Reset) >P MIN/MAX Buffer Reset (>P MiMa O/O GI Reset)
Page 521 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Va-n Min (Va-nMin=) O/O GI Va-n Max (Va-nMax=) O/O GI Vb-n Min (Vb-nMin=) O/O GI Vb-n Max (Vb-nMax=) O/O GI Vc-n Min (Vc-nMin=) O/O GI Vc-n Max (Vc-nMax=) O/O GI Va-b Min (Va-bMin=) O/O GI...
Page 522 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 Active Power Maximum (Pmax=) O/O GI Reactive Power Minimum (Qmin=) O/O GI Reactive Power Maximum (Qmax=) O/O GI Apparent Power Minimum (Smin=) O/O GI Apparent Power Maximum (Smax=) O/O GI Frequency Minimum (fmin=) O/O GI...
Page 523 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 I C dmd> (I Cdmd>) I1dmd> (I1dmd>) Set Point Phase A dmd> (SP. I A dmd>) OUT REL OM O/O GI 135 230 1 Set Point Phase B dmd> (SP. I B dmd>) OUT REL OM O/O GI 135 234 1...
Page 524 Description Type of Log-Buffers Configurable in Matrix SCADA Interface Informa- tion General IEC 60870-5-103 1020 Counter of operating hours (Op.Hours=) OUT O/O GI >BLOCK Op Counter (>BLOCK Op LED BI REL OM O/O GI Count) 1021 Accumulation of interrupted current Ph A (Σ...
Page 525: Overview Of The Masking Features Of The User Defined Informations
Appendix Overview of the masking features of the user defined informations Type of Information Source Destination CFC Task level • Annunciation: Single Point – SP_Ev Single Point Indication Event – – – – – – – – – – – SP Single Point Indication ON/OFF –...
Page 526 Appendix Type of Information Source Destination CFC Task level – C_SN ON/OFF – – – – – C_SN Open/Close – – – – Double Controls 1 Trip 1 Close – C_D2 ON/OFF – – – – – C_D2 Open/Close – –...
Page 527 Appendix Type of Information Source Destination CFC Task level • Control Commands with feedback: Single Controls – CF_S Single Point Indication ON/OFF Control – – – – – SP Feedback – – – CF_S Single Point Indication Open/Close Control – –...
Page 528 Appendix Type of Information Source Destination CFC Task level – CF_D4 Double Point Indication (Breaker indication Control – – – – “ ” “ ” = not valid/transmitted as – DP Feedback – – – – – CF_D4 Double Point Indication (Breaker indication Control –...
Page 529: Default Settings
Appendix Default Settings ® Some CFC Charts are already supplied with the SIPROTEC device: Device and System Logic OUT: Control Device Block Data IntSP IN: Device, General SP OUT: Device, General Feeder gnd IntSP IN: Control Device GndSwit. DP Figure A-16Device and System Logic Set points Using modules on the running sequence “measured value processing”, a low current monitor for the three phase currents is implemented.
Page 530 Appendix OUT: Set points SP. I A dmd> OUT IN: Set points I Admd> LV IN: Demand meter Ia dmd= MV OUT: Set points SP. I B dmd> OUT IN: Set points I Bdmd> LV IN: Demand meter Ib dmd= MV OUT: Set points SP.
Page 531 Index Index Numerics Annunciations 4-9 Automatic Reclosing 1-10, 6-137 27 1-9, 6-111, 10-31 Automatic Reclosing System 6-129, 10-34 46 1-9, 6-86, 10-22 Auxiliary and Reference Voltages 6-148 46-1 6-86, 10-22 Average Calculation 6-171 46-2 6-86, 10-22 46-TOC 1-9, 6-87, 10-22 48 6-94, 10-27 49 6-99, 10-28 50 1-8, 6-18, 10-11...
Page 532 Index Configuration Matrix 4-7, 4-21, 5-11 Destination 5-14 Configuration of Functions 5-2 Determination of Direction 6-45, 6-74 Configuration of Inputs and Outputs 4-21 Determination of the Phase with a Ground Configuring Connection 6-79 an Indication Buffer as a Destination 5-26 DIGRA A-5 Binary Inputs as Sources 5-21 DIGSI REMOTE 4 A-5...
Page 533 Index Filtering 5-16 Frequency Protection 1-9, 6-120, 6-122, 10-32 Keys 2-3, 2-14, 4-6 Front Elements 1-3 Function Keys 2-3, 4-22 Functional Scope 5-2 Fuse-Failur-Monitor 6-153 LEDs 2-3, 2-15, 4-6, 7-2 Light-Emitting Diodes 7-2 Limit Values 6-171 Limit Values User Defined (LVU) 5-18 General Device Pickup and Dropout 6-162 Load Side Fuse Protection 6-134 General Interrogation 7-11...
Page 534 Index No Trip – No Flag 6-164 Profibus DP 4-3 Nominal Currents 8-6 PROFIBUS FMS 4-3 Nominal Frequency 6-11 Programmable Logic CFC 4-24 Nominal rated values 6-15 Protective Functions 1-5 Numerical Values 6-4, 6-7 Rack Mounting 8-3 Open Breaker Times 6-136 Reactance Setting 6-15 Operating Hours Counter 10-38 Rear Service–/Modem–...
Page 535 Index Start Inhibit for Motors 1-9, 6-106, 10-30 Using DIGSI® 4 3-8 Starting Time Monitoring for Motors 1-9 Static Blocking 6-132 Statistical Counters 6-165 Statistics 7-12, 10-38 Statistics Counters 7-14 Vibration and Shock Stress 10-8 Storage 3-13 Voltage Connection 6-11 Switching Authority 6-180, 7-47 Voltage Inputs 10-2 Switching Mode 6-181, 7-47...
Page 536: Index
Index Index-6 7SJ62 Instruction Manual C53000-G1140-C121-1...

Siemens SIPROTEC 7SJ62 Instruction Manual

1 Introduction

2 Hardware and Connections

3 Initial Inspections

4 SIPROTEC 4 Devices

5 Configuration

6 Functions

7 Operators Tools

8 Installation and Commissioning

9 Routine Checks and Maintenance

10 Technical Data

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Summary of Contents for Siemens SIPROTEC 7SJ62