Siemens SIPROTEC 4,SIPROTEC 7RW80 User Manual

Preface
Table of Contents
SIPROTEC 4 Voltage and Frequency
Protection 7RW80
V4.6
Manual
Functions
Mounting and Commissioning
Technical Data
Ordering Information and Accessories
Terminal Assignments
Connection Examples Default Settings and Protocol-dependent
Functions
Functions, Settings, Information
1 2 3 4
A
B
C
D
E
C53000-G1140-C233-4
Literature
Glossary
Index
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i
NOTE
For your own safety, observe the warnings and safety instructions contained in this document, if available.
Disclaimer of Liability
We have checked the contents of this manual against the hardware and software described. However, deviations from the description cannot be completely ruled out, so that no liability can be accepted for any errors or omissions contained in the information given.
The information given in this document is reviewed regu­larly and any necessary corrections will be included in subsequent editions. We appreciate any suggested improvements.
We reserve the right to make technical improvements without notice.
Document version V04.03.00 Release date 07.2018
Copyright
Copyright © Siemens AG 2018. All rights reserved. Dissemination or reproduction of this document, or evalua-
tion and communication of its contents, is not authorized except where expressly permitted. Violations are liable for damages. All rights reserved, particularly for the purposes of patent application or trademark registration.
Registered Trademarks
SIPROTEC, SINAUT, SICAM and DIGSI are registered trade­marks of Siemens AG. Other designations in this manual might be trademarks whose use by third parties for their own purposes would infringe the rights of the owner.

Preface

Purpose of the Manual
This manual describes the functions, operation, installation, and commissioning of devices 7RW80. In partic­ular, one will find:
Information regarding the configuration of the scope of the device and a description of the device func-
tions and settings → Chapter 2;
Instructions for Installation and Commissioning → Chapter 3;
Compilation of the Technical Data → Chapter 4;
As well as a compilation of the most significant data for advanced users → Appendix.
General information with regard to design, configuration, and operation of SIPROTEC 4 devices are set out in the SIPROTEC 4 System Description /1/ SIPROTEC 4 System Description.
Target Audience
Protection-system engineers, commissioning engineers, persons entrusted with the setting, testing and main­tenance of selective protection, automation and control equipment, and operating personnel in electrical installations and power plants.
Scope
This manual applies to: SIPROTEC 4 Voltage and Frequency Protection 7RW80; Firmware-Version V4.6.
Indication of Conformity
Additional Standards IEEE Std C37.90 (see Chapter 4 "Technical Data")
This product is UL-certified according to the Technical Data. file E194016
[ul-schutz-7sx80-100310, 1, --_--]
This product complies with the directive of the Council of the European Communities on the approximation of the laws of the Member States relating to electromagnetic compatibility (EMC Council Directive 2004/108/EC) and concerning electrical equipment for use within specified voltage limits (Low-voltage Directive 2006/95 EC).
This conformity is proved by tests conducted by Siemens AG in accordance with the Council Directive in agreement with the generic standards EN 61000-6-2 and EN 61000-6-4 for EMC directive, and with the standard EN 60255-27 for the low-voltage directive.
The device has been designed and produced for industrial use. The product conforms with the international standards of the series IEC 60255 and the
German standard VDE 0435.
SIPROTEC 4, 7RW80, Manual C53000-G1140-C233-4, Edition 07.2018
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Preface
Additional Support
For questions about the system, please contact your Siemens sales partner.
Support
Our Customer Support Center provides a 24-hour service.
Phone: +49 (180) 524-7000 Fax: +49 (180) 524-2471 E-Mail: support.energy@siemens.com
Training Courses
Inquiries regarding individual training courses should be addressed to our Training Center:
Siemens AG Siemens Power Academy TD
Humboldtstraße 59 90459 Nürnberg Germany
Phone: +49 (911) 433-7415 Fax: +49 (911) 433-7929 E-Mail: poweracademy@siemens.com Internet: www.siemens.com/poweracademy
Notes on Safety
This document is not a complete index of all safety measures required for operation of the equipment (module or device). However, it comprises important information that must be followed for personal safety, as well as to avoid material damage. Information is highlighted and illustrated as follows according to the degree of danger:
DANGER
DANGER means that death or severe injury will result if the measures specified are not taken.
²
WARNING
WARNING means that death or severe injury may result if the measures specified are not taken.
²
CAUTION
Comply with all instructions, in order to avoid death or severe injuries.
Comply with all instructions, in order to avoid death or severe injuries.
CAUTION means that medium-severe or slight injuries can occur if the specified measures are not taken.
Comply with all instructions, in order to avoid moderate or minor injuries.
²
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NOTICE
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NOTICE means that property damage can result if the measures specified are not taken.
Comply with all instructions, in order to avoid property damage.
²
NOTE
Important information about the product, product handling or a certain section of the documentation which must be given particular attention.
Qualified Electrical Engineering Personnel
Only qualified electrical engineering personnel may commission and operate the equipment (module, device) described in this document. Qualified electrical engineering personnel in the sense of this manual are people who can demonstrate technical qualifications as electrical technicians. These persons may commission, isolate, ground and label devices, systems and circuits according to the standards of safety engineering.
Proper Use
The equipment (device, module) may be used only for such applications as set out in the catalogs and the technical description, and only in combination with third-party equipment recommended and approved by Siemens.
Problem-free and safe operation of the product depends on the following:
Proper transport
Proper storage, setup and installation
Proper operation and maintenance
When electrical equipment is operated, hazardous voltages are inevitably present in certain parts. If proper action is not taken, death, severe injury or property damage can result:
The equipment must be grounded at the grounding terminal before any connections are made.
All circuit components connected to the power supply may be subject to dangerous voltage.
Hazardous voltages may be present in equipment even after the supply voltage has been disconnected
(capacitors can still be charged).
Preface
Operation of equipment with exposed current-transformer circuits is prohibited. Before disconnecting the
equipment, ensure that the current-transformer circuits are short-circuited.
The limiting values stated in the document must not be exceeded. This must also be considered during
testing and commissioning.
Typographic and Symbol Conventions
The following text formats are used when literal information from the device or to the device appear in the text flow:
Parameter Names
Designators of configuration or function parameters which may appear word-for-word in the display of the device or on the screen of a personal computer (with operation software DIGSI), are marked in bold letters in monospace type style. The same applies to titles of menus.
1234A
Parameter addresses have the same character style as parameter names. Parameter addresses contain the suffix A in the overview tables if the parameter can only be set in DIGSI via the option Display additional settings.
Parameter Options
Possible settings of text parameters, which may appear word-for-word in the display of the device or on the screen of a personal computer (with operation software DIGSI), are additionally written in italics. The same applies to the options of the menus.
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Preface
Indications
Designators for information, which may be output by the relay or required from other devices or from the switch gear, are marked in a monospace type style in quotation marks.
Deviations may be permitted in drawings and tables when the type of designator can be obviously derived from the illustration.
The following symbols are used in drawings:
Device-internal logical input signal
Device-internal logical output signal
Internal input signal of an analog quantity
External binary input signal with number (binary input, input indication) External binary output signal with number (example of a value indication)
External binary output signal with number (device indication) used as input signal
Example of a parameter switch designated FUNCTION with address 1234 and the possible settings ON and OFF
Besides these, graphical symbols are used in accordance with IEC 60617-12 and IEC 60617-13 or similar. Some of the most frequently used are listed below:
Analog input variable
AND-gate operation of input values
OR-gate operation of input values
Exclusive OR gate (antivalence): output is active, if only one of the inputs is active
Coincidence gate: output is active, if both inputs are active or inactive at the same time
Dynamic inputs (edge-triggered) above with positive, below with negative edge
Formation of one analog output signal from a number of analog input signals
Limit stage with setting address and parameter designator (name)
Timer (pickup delay T, example adjustable) with setting address and parameter designator (name)
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Timer (dropout delay T, example non-adjustable)
Dynamic triggered pulse timer T (monoflop)
Static memory (SR flipflop) with setting input (S), resetting input (R), output (Q) and inverted output (Q), setting input dominant
Static memory (RS-flipflop) with setting input (S), resetting input (R), output (Q) and inverted output (Q), resetting input dominant
Preface
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Table of Contents

Preface..........................................................................................................................................................3
1 Introduction................................................................................................................................................15
1.1 Overall Operation..............................................................................................................16
1.2 Application Scope............................................................................................................. 18
1.3 Characteristics.................................................................................................................. 20
2 Functions.................................................................................................................................................... 23
2.1 General.............................................................................................................................24
2.1.1 Functional Scope......................................................................................................... 24
2.1.1.1 Functional Description........................................................................................... 24
2.1.1.2 Setting Notes......................................................................................................... 24
2.1.1.3 Settings................................................................................................................. 25
2.1.2 Device, General Settings.............................................................................................. 26
2.1.2.1 Functional Description........................................................................................... 26
2.1.2.2 Setting Notes......................................................................................................... 27
2.1.2.3 Settings................................................................................................................. 27
2.1.2.4 Information List..................................................................................................... 27
2.1.3 Power System Data 1...................................................................................................28
2.1.3.1 Functional Description........................................................................................... 28
2.1.3.2 Setting Notes......................................................................................................... 29
2.1.3.3 Settings................................................................................................................. 31
2.1.3.4 Information List..................................................................................................... 32
2.1.4 Oscillographic Fault Records........................................................................................ 32
2.1.4.1 Functional Description........................................................................................... 32
2.1.4.2 Setting Notes......................................................................................................... 33
2.1.4.3 Settings................................................................................................................. 34
2.1.4.4 Information List..................................................................................................... 34
2.1.5 Settings Groups........................................................................................................... 34
2.1.5.1 Functional Description........................................................................................... 34
2.1.5.2 Setting Notes......................................................................................................... 34
2.1.5.3 Settings................................................................................................................. 35
2.1.5.4 Information List..................................................................................................... 35
2.1.6 Power System Data 2...................................................................................................35
2.1.6.1 Functional Description........................................................................................... 35
2.1.6.2 Setting Notes......................................................................................................... 35
2.1.6.3 Settings................................................................................................................. 35
2.1.6.4 Information List..................................................................................................... 35
2.1.7 EN100-Module............................................................................................................ 36
2.1.7.1 Functional Description........................................................................................... 36
2.1.7.2 Setting Notes......................................................................................................... 36
2.1.7.3 Information List..................................................................................................... 36
2.2 Voltage Protection 27, 59..................................................................................................37
2.2.1 Measurement Principle................................................................................................ 37
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Table of Contents
2.2.2 Overvoltage Protection 59........................................................................................... 38
2.2.3 Undervoltage Protection 27......................................................................................... 39
2.2.4 Setting Notes...............................................................................................................41
2.2.5 Settings.......................................................................................................................44
2.2.6 Information List...........................................................................................................45
2.3 Frequency Protection 81 O/U.............................................................................................46
2.3.1 Functional Description.................................................................................................46
2.3.2 Setting Notes...............................................................................................................47
2.3.3 Settings.......................................................................................................................48
2.3.4 Information List...........................................................................................................49
2.4 Load Restoration............................................................................................................... 50
2.4.1 Functional Description.................................................................................................50
2.4.2 Setting Notes...............................................................................................................54
2.4.3 Settings.......................................................................................................................57
2.4.4 Information List...........................................................................................................60
2.5 Supervision Functions....................................................................................................... 61
2.5.1 Measurement Supervision........................................................................................... 61
2.5.1.1 General..................................................................................................................61
2.5.1.2 Hardware Monitoring ............................................................................................ 61
2.5.1.3 Software Monitoring ............................................................................................. 61
2.5.1.4 Monitoring of the Transformer Circuits................................................................... 62
2.5.1.5 Broken Wire Monitoring of Voltage Transformer Circuits......................................... 63
2.5.1.6 Setting Notes......................................................................................................... 64
2.5.1.7 Settings................................................................................................................. 64
2.5.1.8 Information List..................................................................................................... 65
2.5.2 Trip Circuit Supervision 74TC....................................................................................... 65
2.5.2.1 Functional Description........................................................................................... 65
2.5.2.2 Setting Notes......................................................................................................... 68
2.5.2.3 Settings................................................................................................................. 68
2.5.2.4 Information List..................................................................................................... 69
2.5.3 Malfunction Responses of the Monitoring Functions.................................................... 69
2.5.3.1 Functional Description........................................................................................... 69
2.6 Flexible Protection Functions.............................................................................................71
2.6.1 Functional Description.................................................................................................71
2.6.2 Setting Notes...............................................................................................................74
2.6.3 Settings.......................................................................................................................77
2.6.4 Information List...........................................................................................................78
2.7 Synchrocheck................................................................................................................... 80
2.7.1 Allgemeines................................................................................................................ 80
2.7.2 Functional Sequence................................................................................................... 81
2.7.3 De-energized Switching...............................................................................................82
2.7.4 Direct Command / Blocking..........................................................................................83
2.7.5 Interaction with Control and External Control...............................................................84
2.7.6 Setting Notes...............................................................................................................84
2.7.7 Settings.......................................................................................................................88
2.7.8 Information List...........................................................................................................89
2.8 24 Overexcit. Protection (Volt/Hertz)................................................................................. 91
2.8.1 Functional Description.................................................................................................91
2.8.2 Setting Notes...............................................................................................................93
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2.8.3 Settings.......................................................................................................................95
2.8.4 Information List...........................................................................................................95
2.9 Jump of Voltage Vector..................................................................................................... 96
2.9.1 Functional Description.................................................................................................96
2.9.2 Setting Notes...............................................................................................................98
2.9.3 Settings.......................................................................................................................99
2.9.4 Information List...........................................................................................................99
2.10 Phase Rotation................................................................................................................ 100
2.10.1 Functional Description...............................................................................................100
2.10.2 Setting Notes.............................................................................................................100
2.11 Function Logic................................................................................................................ 101
2.11.1 Pickup Logic of the Entire Device................................................................................101
2.11.2 Tripping Logic of the Entire Device.............................................................................101
2.11.3 Setting Notes.............................................................................................................102
2.12 Auxiliary Functions..........................................................................................................103
2.12.1 Message Processing...................................................................................................103
2.12.1.1 LED Displays and Binary Outputs (Output Relays)..................................................103
2.12.1.2 Information on the Integrated Display (LCD) or Personal Computer....................... 103
2.12.1.3 Information to a Control Center............................................................................105
2.12.2 Statistics....................................................................................................................105
2.12.2.1 Functional Description......................................................................................... 105
2.12.2.2 Setting Notes....................................................................................................... 105
2.12.2.3 Information List................................................................................................... 105
2.12.3 Measurement............................................................................................................105
2.12.3.1 Display of Measured Values.................................................................................. 106
2.12.3.2 Transfer of Measured Values................................................................................ 107
2.12.3.3 Information List................................................................................................... 107
2.12.4 Min/Max Measurement Setup.................................................................................... 108
2.12.4.1 Functional Description......................................................................................... 108
2.12.4.2 Setting Notes....................................................................................................... 108
2.12.4.3 Settings............................................................................................................... 108
2.12.4.4 Information List................................................................................................... 108
2.12.5 Set Points for Measured Values.................................................................................. 109
2.12.5.1 Setting Notes....................................................................................................... 109
2.12.6 Set Points for Statistic................................................................................................ 109
2.12.6.1 Functional Description......................................................................................... 109
2.12.6.2 Setting Notes....................................................................................................... 109
2.12.6.3 Information List................................................................................................... 110
2.12.7 Energy Metering........................................................................................................110
2.12.7.1 Setting Notes....................................................................................................... 110
2.12.7.2 Settings............................................................................................................... 110
2.12.7.3 Information List................................................................................................... 110
2.12.8 Commissioning Aids.................................................................................................. 110
2.12.8.1 Functional Description......................................................................................... 110
2.13 Breaker Control...............................................................................................................112
2.13.1 Control Device...........................................................................................................112
2.13.1.1 Functional Description......................................................................................... 112
2.13.1.2 Informationsübersicht..........................................................................................113
2.13.2 Types of Commands.................................................................................................. 113
2.13.2.1 Functional Description......................................................................................... 113
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Table of Contents
2.13.3 Command Sequence..................................................................................................113
2.13.3.1 Functional Description......................................................................................... 114
2.13.4 Switchgear Interlocking............................................................................................. 114
2.13.4.1 Functional Description......................................................................................... 114
2.13.5 Command Logging.................................................................................................... 118
2.13.5.1 Functional Description......................................................................................... 119
2.14 Notes on Device Operation..............................................................................................120
2.14.1 Different operation....................................................................................................120
3 Mounting and Commissioning................................................................................................................. 123
3.1 Mounting and Connections............................................................................................. 124
3.1.1 Configuration Information......................................................................................... 124
3.1.2 Hardware Modifications.............................................................................................127
3.1.2.1 Disassembly.........................................................................................................127
3.1.2.2 Connections of the Voltage Terminals...................................................................131
3.1.2.3 Interface Modules................................................................................................ 132
3.1.2.4 Reassembly..........................................................................................................134
3.1.3 Installation................................................................................................................ 135
3.1.3.1 General................................................................................................................135
3.1.3.2 Panel Flush Mounting...........................................................................................136
3.1.3.3 Cubicle Mounting.................................................................................................137
3.1.3.4 Panel Surface Mounting....................................................................................... 138
3.2 Checking Connections.....................................................................................................140
3.2.1 Checking the Data Connections of the Interfaces........................................................140
3.2.2 Checking the System Connections............................................................................. 142
3.3 Commissioning............................................................................................................... 144
3.3.1 Test Mode and Transmission Block.............................................................................145
3.3.2 Testing the System Interface .....................................................................................145
3.3.3 Configuring Communication Modules........................................................................146
3.3.4 Checking the Status of Binary Inputs and Outputs...................................................... 150
3.3.5 Testing User-Defined Functions..................................................................................152
3.3.6 Voltage and Phase Rotation Testing........................................................................... 152
3.3.7 Polarity Check for Voltage Input V3.............................................................................153
3.3.8 Trip/Close Tests for the Configured Operating Devices................................................ 155
3.3.9 Creating Oscillographic Recordings for Tests.............................................................. 156
3.4 Final Preparation of the Device........................................................................................157
4 Technical Data.......................................................................................................................................... 159
4.1 General Device Data........................................................................................................160
4.1.1 Analog Inputs............................................................................................................160
4.1.2 Auxiliary voltage........................................................................................................160
4.1.3 Binary Inputs and Outputs......................................................................................... 160
4.1.4 Communication Interfaces.........................................................................................161
4.1.5 Electrical Tests...........................................................................................................164
4.1.6 Mechanical Tests....................................................................................................... 165
4.1.7 Climatic Stress Tests.................................................................................................. 166
4.1.8 Service Conditions..................................................................................................... 167
4.1.9 Constructive Design...................................................................................................167
4.1.10 UL certification conditions......................................................................................... 167
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4.2 Voltage Protection.......................................................................................................... 169
4.3 Frequency Protection 81 O/U...........................................................................................171
4.4 Load Restoration............................................................................................................. 172
4.5 Flexible Protection Functions ..........................................................................................173
4.6 Synchrocheck 25 ............................................................................................................175
4.7 Overecxitation Protection 24...........................................................................................177
4.8 Jump of Voltage Vector................................................................................................... 179
4.9 User-defined Functions (CFC).......................................................................................... 180
4.10 Auxiliary Functions..........................................................................................................185
4.11 Switching Device Control................................................................................................ 188
4.12 Dimensions.....................................................................................................................189
4.12.1 Panel Flush and Cubicle Mounting (Housing Size 1/6) ................................................189
4.12.2 Panel Surface Mounting (Housing Size 1/6) ............................................................... 190
4.12.3 Bottom view..............................................................................................................190
A Ordering Information and Accessories.....................................................................................................191
A.1 Ordering Information 7RW80 V4.6 ................................................................................. 192
A.2 Accessories.....................................................................................................................195
B Terminal Assignments..............................................................................................................................197
B.1 7RW80 — Housing for Panel Flush Mounting or Cubicle Mounting...................................198
B.2 7RW80 — Housing for panel surface mounting................................................................199
C Connection Examples............................................................................................................................... 201
C.1 Connection Examples for Voltage Transformers...............................................................202
D Default Settings and Protocol-dependent Functions............................................................................... 207
D.1 LEDs............................................................................................................................... 208
D.2 Binary Input.................................................................................................................... 209
D.3 Binary Output................................................................................................................. 210
D.4 Function Keys................................................................................................................. 211
D.5 Default Display................................................................................................................212
D.6 Protocol-dependent Functions.........................................................................................213
E Functions, Settings, Information..............................................................................................................215
E.1 Functional Scope............................................................................................................ 216
E.2 Settings.......................................................................................................................... 217
E.3 Information List.............................................................................................................. 226
E.4 Group Indications............................................................................................................246
E.5 Measured Values.............................................................................................................247
Literature.................................................................................................................................................. 249
Glossary.................................................................................................................................................... 251
Index.........................................................................................................................................................261
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1

Introduction

The device family SIPROTEC 7RW80 devices is introduced in this section. An overview of the devices is presented in their application, characteristics, and scope of functions.
1.1 Overall Operation 16
1.2 Application Scope 18
1.3 Characteristics 20
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Introduction

1.1 Overall Operation

1.1
Analog Inputs
Overall Operation
The Voltage and Frequency protection SIPROTEC 7RW80 is equipped with a high performance microprocessor. This provides numerical processing of all functions in the device, from the acquisition of the measured values up to the output of commands to the circuit breakers. Figure 1-1 shows the basic structure of the device 7RW80.
The measuring inputs MI transform the voltages derived from the instrument transformers and match them to the internal signal levels for processing in the device. Three voltage inputs are available in the MI section.
[hw-struktur-7rw80-100519, 1, en_US]
Figure 1-1
Voltage inputs can either be used to measure the three phase-to-ground voltages, or two phase-to-phase voltages and the displacement voltage (e–n voltage) or for any other voltage. It is also possible to connect two phase-to-phase voltages in open-delta connection.
The analog input quantities are passed on to the input amplifiers (IA). The input amplifier IA element provides a high-resistance termination for the input quantities. It consists of filters that are optimized for measured­value processing with regard to bandwidth and processing speed.
The analog-to-digital (AD) transformer group consists of a an analog-to-digital converter and memory compo­nents for the transmission of data to the microcomputer.
Microcomputer System
Apart from processing the measured values, the microcomputer system (μC) also executes the actual protec­tion and control functions. They especially include:
16 SIPROTEC 4, 7RW80, Manual
Hardware structure of the numerical Voltage and Frequency Protection Device 7RW80
C53000-G1140-C233-4, Edition 07.2018
Filtering and preparation of the measured quantities
Continuous monitoring of the measured quantities
Monitoring of the pickup conditions for the individual protective functions
Interrogation of limit values and sequences in time
Control of signals for the logic functions
Output of control commands for switching devices
Recording of messages, fault data and fault values for analysis
Management of the operating system and the associated functions such as data recording, real-time
clock, communication, interfaces, etc.
The information is distributed via output amplifiers (OA).
Binary Inputs and Outputs
The computer system obtains external information through the binary input/output boards (inputs and outputs). The computer system obtains information from the system (e.g remote resetting) or from external equipment (e.g. blocking commands). These outputs include, in particular, trip commands to circuit breakers and signals for the remote indication of important events and conditions.
Front Panel
Introduction
1.1 Overall Operation
Information such as messages related to events, states, measured values and the functional status of the device are visualized by light-emitting diodes (LEDs) and a display screen (LCD) on the front panel.
Integrated control and numeric keys in conjunction with the LCD enable interaction with the remote device. These elements can be used to access the device for information such as configuration and setting parame­ters. Similarly, setting parameters can be accessed and changed if needed.
In addition, control of circuit breakers and other equipment is possible from the front panel of the device.
Interfaces
Communication with a PC can be implemented via the USB DIGSI interface using the DIGSI software, allowing all device functions to be easily executed.
Communication with a PC is also possible via port A (Ethernet interface) and port B (System/Service interface) using DIGSI.
In addition to the device communication via DIGSI, port B can also be used to transmit all device data to a central evaluator or a control center. This interface may be provided with various protocols and physical trans­mission schemes to suit the particular application.
Power Supply
A power supply unit (Vaux or PS) delivers power to the functional units using the different voltage levels. Voltage dips may occur if the voltage supply system (substation battery) becomes short-circuited. Usually, they are bridged by a capacitor (see also Technical Data).
A buffer battery is located under the flap at the lower end of the front cover.
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Introduction

1.2 Application Scope

1.2
Protection Functions
Control Functions
Application Scope
The digital voltage and frequency protection SIPROTEC 4 7RW80 is a versatile device designed for protection, control, and monitoring of transformers, electrical machines and distribution systems.
The device can be used for
System decoupling or for load shedding if ever there is a risk of a system collapse as a result of inadmis-
sibly large frequency drops
Monitoring voltage and frequency thresholds
Voltage, frequency and overexcitation protection can be used to protect generators and transformers in the event of
Defective voltage control or defective frequency control
Full load rejection
Islanding generation systems.
Multilevel voltage and frequency protection is the basic function of the device. Further protection functions included are load restoration, synchrocheck, overexcitation protection, vector
jump and flexible protective functions.
The device provides a control function which can be accomplished for activating and deactivating the switch­gear via operator buttons, port B, binary inputs and - using a PC and the DIGSI software - via the front inter­face.
The status of the primary equipment can be transmitted to the device via auxiliary contacts connected to binary inputs. The present status (or position) of the primary equipment can be displayed on the device, and used for interlocking or alarm condition monitoring. The number of operating equipments to be switched is limited by the binary inputs and outputs available in the device or the binary inputs and outputs allocated for the switch position indications. Depending on the primary equipment being controlled, one binary input (single point indication) or two binary inputs (double point indication) may be used for this process.
The capability of switching primary equipment can be restricted by a setting associated with switching authority (Remote or Local), and by the operating mode (interlocked/non-interlocked, with or without pass­word request).
Processing of interlocking conditions for switching (e.g. switchgear interlocking) can be established with the aid of integrated, user-configurable logic functions.
Messages and Measured Values; Recording of Event and Fault Data
The operational indications provide information about conditions in the power system and the device. Meas­urement quantities and values that are calculated can be displayed locally and communicated via the serial interfaces.
Device messages can be assigned to a number of LEDs on the front cover (allocatable), can be externally processed via output contacts (allocatable), linked with user-definable logic functions and/or issued via serial interfaces.
During a fault (system fault) important events and changes in conditions are saved in fault protocols (Event Log or Trip Log). Instantaneous fault values are also saved in the device and may be analyzed subsequently.
Communication
The following interfaces are available for communication with external operating, control and memory systems.
The USB DIGSI interface on the front cover serves for local communication with a PC. By means of the SIPROTEC 4 operating software DIGSI, all operational and evaluation tasks can be executed via this operator interface, such as specifying and modifying configuration parameters and settings, configuring user-specific
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Introduction
1.2 Application Scope
logic functions, retrieving operational messages and measured values, inquiring device conditions and meas­ured values, issuing control commands.
Depending on the ordered variant, additional interfaces are located at the bottom of the device. They serve for establishing extensive communication with other digital operating, control and memory components:
Port A serves for DIGSI communication directly on the device or via network. Port B serves for central communication between the device and a control center. It can be operated via data
lines or fiber optic cables. For the data transfer, there are standard protocols in accordance with IEC 60870-5­103 available. The integration of the devices into the SINAUT LSA and SICAM automation systems can also be implemented with this profile.
Alternatively, additional connection options are available with PROFIBUS DP and the DNP3.0 and MODBUS protocols. If an EN100 module is available, you can use the protocol IEC 61850.
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Introduction

1.3 Characteristics

1.3
General Characteristics
Characteristics
Powerful 32-bit microprocessor system
Complete digital processing and control of measured values, from the sampling of the analog input quan-
tities to the initiation of outputs, for example, tripping or closing circuit breakers or other switchgear devices
Total electrical separation between the internal processing stages of the device and the external trans-
former, control, and DC supply circuits of the system because of the design of the binary inputs, outputs, and the DC or AC converters
Easy device operation through an integrated operator panel or by means of a connected personal
computer running DIGSI
Continuous calculation and display of measured and metered values on the front of the device
Storage of min./max. measured values (slave pointer function) and storage of long-term mean values
Recording of event and fault data for the last 8 system faults (fault in a network) with real-time informa-
tion as well as instantaneous values for fault recording for a maximum time range of 20 s
Constant monitoring of the measured quantities, as well as continuous self-diagnostics covering the
hardware and software
Communication with SCADA or substation controller equipment via serial interfaces through the choice
of data cable, modem, or optical fibers
Battery-buffered clock which can be synchronized via a synchronization signal at the binary input or via a
protocol
Statistics: Recording of the number of trip signals instigated by the device.
Commissioning aids such as connection and direction check, status indication of all binary inputs and
outputs, easy testing of port B, and influencing of information at port B during test operation.
Voltage Protection 27, 59
Three-element undervoltage detection via the positive sequence system of the voltages, phase-to-phase
or phase-ground voltages
Separate overvoltage detection of the voltages applied or detection of the positive or negative sequence
component of the voltages
Settable dropout ratio for all elements of the undervoltage and overvoltage protection
User-defined characteristic
Frequency Protection 81 O/U
Monitoring of falling below (f<) and/or exceeding (f>) with 4 frequency limits and time delays that are
independently adjustable
Insensitive to harmonics and abrupt phase angle changes
Adjustable undervoltage threshold.
Load Restoration
4 separately adjustable load restoration stages
Individually assignable low frequency stages, which start the load restoration stage (1 to 4 for each load
restoration element)
Settable dropout ratio for all stages of the load restoration
Monitoring of the settable restoration cycles (no ON/OFF chattering)
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Monitoring Functions
Increased reliability due to monitoring of the internal measurement circuits as well as the hardware and
software
Monitoring of the current transformer and voltage transformer secondary circuits using sum and
symmetry supervision with optional protection function blocking
Broken-wire Monitoring of Voltage Transformer Circuits
Trip circuit monitoring possible
Phase rotation check.
Flexible Protective Functions
Up to 20 customizable protection functions with three-phase or single-phase operation
Any calculated or directly measured quantity can be evaluated on principle
Standard protection logic with definite time characteristic
Internal and configurable pickup and dropout delay
Modifiable message texts.
Synchrocheck
Introduction
1.3 Characteristics
Check of the synchronism conditions or de-energized state before manual closing of the circuit breaker
Fast measurement of the voltage difference ΔV, the phase angle difference Δϕ and the frequency differ-
ence Δf
Setable minimum and maximum voltage
Measurement also possible via transformer without external intermediate matching transformer
Measuring voltages optionally phase–to–phase or phase–to–ground.
Overecxitation Protection
Calculation of the V/f ratio V/f
Adjustable warning and tripping stage
Standard characteristic or arbitrary trip characteristic selectable for calculation of the thermal stress.
Jump of Voltage Vector
Sensitive phase jump detection to be used for network disconnection.
Phase Rotation
Selectable ABC or ACB by setting (static) or binary input (dynamic).
User Defined Functions
Freely programmable linking of internal and external signals in order to implement user-defined logic
functions
All standard logic functions (AND, OR, NOT, EXCLUSIVE-OR, etc.)
Time delays and limit value interrogations
Processing of measured values, including zero suppression, adding a knee curve for a transducer input,
and live-zero monitoring.
Linking of multiple devices for load restoration with prioritization of the stages
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Introduction
1.3 Characteristics
Breaker Control
Switching devices can be opened and closed manually using control keys, programmable function keys, via port B (e.g. of SICAM or LSA), or via the user interface (using a personal computer and the DIGSI oper­ating software)
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2

Functions

This chapter describes the numerous functions available on the SIPROTEC 4 device 7RW80. It shows the setting possibilities for each function in maximum configuration. Information with regard to the determina­tion of setting values as well as formulas, if required, are also provided.
Based on the following information, it can also be determined which of the provided functions should be used.
2.1 General 24
2.2 Voltage Protection 27, 59 37
2.3 Frequency Protection 81 O/U 46
2.4 Load Restoration 50
2.5 Supervision Functions 61
2.6 Flexible Protection Functions 71
2.7 Synchrocheck 80
2.8 24 Overexcit. Protection (Volt/Hertz) 91
2.9 Jump of Voltage Vector 96
2.10 Phase Rotation 100
2.11 Function Logic 101
2.12 Auxiliary Functions 103
2.13 Breaker Control 112
2.14 Notes on Device Operation 120
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Functions

2.1 General

2.1
2.1.1
2.1.1.1
Setting the Functional Scope
General
The settings associated with the various device functions can be modified using the operating or service inter­face in DIGSI in conjunction with a personal computer. Some parameters can also be changed using the controls on the front panel of the device. The procedure is described in detail in the SIPROTEC System Descrip­tion /1/ SIPROTEC 4 System Description.

Functional Scope

The 7RW80 relay contains protection functions as well as auxiliary functions. The hardware and firmware is designed for this scope of functions. Additionally, the control functions can be matched to the system require­ments. Individual functions can be enabled or disabled during the configuration procedure. The interaction of functions may also be modified.
Functional Description
The available protection and additional functions can be configured as Enabled or Disabled. For individual functions, a choice between several alternatives may be possible, as described below.
Functions configured as Disabled are not processed by the 7RW80. There are no messages and corre­sponding settings (functions, limit values) queried during configuration.
NOTE
Available functions and default settings are depending on the order variant of the relay (see A Ordering
Information and Accessories).
2.1.1.2
Setting the Functional Scope
Special Features
Setting Notes
Your protection device is configured using the DIGSI software. Connect your personal computer either to the USB port on the device front or to port A or port B on the bottom side of the device depending on the device version (ordering code). The operation via DIGSI is explained in the SIPROTEC 4 System Description.
The Device Configuration dialog box allows you to adjust your device to the specific system conditions. Password no. 7 is required (for parameter set) for changing configuration parameters in the device. Without
the password the settings can only be read but not edited and transmitted to the device.
Most settings are self-explanatory. The special cases are described in the following. If you want to use the setting group change function, set address 103 Grp Chge OPTION to Enabled. In
this case, you can select up to four different groups of function parameters between which you can switch quickly and conveniently during operation. Only one setting group can be used when selecting the option Disabled.
The synchronization function is activated in address 161 25 Function 1 by the setting SYNCHROCHECK or it is set to Disabled.
Under address 182 74 Trip Ct Supv it can be selected whether the trip-circuit supervision works with two (2 Binary Inputs) or only one binary input (1 Binary Input), or whether the function is configured Disabled.
In address 617 ServiProt (CM) you can specify for which purpose port B is used. T103 means that the device is connected to a control and protection facility via serial port, DIGSI means that you are using the port to connect DIGSI or you are not using port B (Disabled).
The flexible protection functions can be configured via parameter FLEXIBLE FUNC.. You can create up to 20 flexible functions by setting a checkmark in front of the desired function. If the checkmark of a function is
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Functions
2.1 General
removed, all settings and configurations made previously will be lost. After re-selecting the function, all settings and configurations are in default setting. Setting of the flexible function is done in DIGSI under “Parameters”, “Additional Functions” and “Settings”. The configuration is done, as usual, under “Parameters” and “Configuration”.
2.1.1.3
Settings
Addr. Parameter Setting Options Default Setting Comments
103 Grp Chge OPTION Disabled
Disabled Setting Group Change Option
Enabled
104 OSC. FAULT REC. Disabled
Enabled Oscillographic Fault Records
Enabled
143 24 V/f Disabled
Enabled
146 VECTOR JUMP Disabled
Disabled 24 Overexcit. Protection (Volt/
Hertz)
Disabled Jump of Voltage Vector
Enabled
150 27/59 Disabled
Enabled
152 VT BROKEN WIRE Disabled
Enabled 27, 59 Under/Overvoltage Protec-
tion
Enabled VT broken wire supervision
Enabled
154 81 O/U Disabled
Enabled
155 Load Restore Disabled
Enabled 81 Over/Underfrequency Protec-
tion
Disabled Load Restoration
Enabled
161 25 Function 1 Disabled
Disabled 25 Function group 1
SYNCHROCHECK
182 74 Trip Ct Supv Disabled
Disabled 74TC Trip Circuit Supervision 2 Binary Inputs 1 Binary Input
617 ServiProt (CM) Disabled
T103 Port B usage T103 DIGSI
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Functions
2.1 General
Addr. Parameter Setting Options Default Setting Comments
- FLEXIBLE FCT. 1...20 Flexible Function 01
Please select Flexible Functions 1...20 Flexible Function 02 Flexible Function 03 Flexible Function 04 Flexible Function 05 Flexible Function 06 Flexible Function 07 Flexible Function 08 Flexible Function 09 Flexible Function 10 Flexible Function 11 Flexible Function 12 Flexible Function 13 Flexible Function 14 Flexible Function 15 Flexible Function 16 Flexible Function 17 Flexible Function 18 Flexible Function 19 Flexible Function 20
2.1.2

Device, General Settings

The device requires some general information. This may be, for example, the type of annunciation to be issued in the event of an occurrence of a power system fault.
2.1.2.1
Functional Description
Command-Dependent Messages "No Trip – No Flag"
The storage of indications assigned to local LEDs and the availability of spontaneous indications can be made dependent on whether the device has issued a trip command. This information is then not issued if during a system disturbance one or more protection functions have picked up but the 7RW80 did not trip because the fault was cleared by another device (e.g. on another line). These messages are then limited to faults in the line to be protected.
The following figure illustrates the generation of the reset command for stored indications. The instant the device drops out, the presetting of parameter 610 FltDisp.LED/LCD decides whether the new fault remains stored or is reset.
[dw_ruecksetzbefehl-fuer-n-speicher-led-lcd-meld, 1, en_US]
Figure 2-1 Creation of the reset command for the latched LED and LCD messages
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Spontaneous Messages on the Display
You can determine whether or not the most important data of a fault event is displayed automatically after the fault has occurred (see also Subsection "Fault Messages" in Section "Auxiliary Functions").
Functions
2.1 General
2.1.2.2
Setting Notes
Fault Messages
A new pickup of a protection function generally turns off any previously set light displays so that only the latest fault is displayed at any one time. It can be selected whether the stored LED displays and the sponta­neous messages on the display appear after the new pickup or only after a new trip signal is issued. In order to select the desired mode of display, select the Device submenu in the SETTINGS menu. Under address 610 FltDisp.LED/LCD the two options Target on PU and Target on TRIP ("No trip – no flag") can be selected.
For devices with graphic display, use parameter 611 Spont. FltDisp. to specify whether a spontaneous fault message should appear automatically on the display (YES) or not (NO). For devices with text display such indications will appear after a system fault in any case.
Selection of Default Display
The start page of the default display appearing after startup of the device can be selected in the device data via parameter640 Start image DD. The pages available for each device version are listed in the Appendix
D Default Settings and Protocol-dependent Functions.
2.1.2.3
Addr.
Settings
Parameter Setting Options Default Setting Comments
610 FltDisp.LED/LCD Target on PU
Target on TRIP
611 Spont. FltDisp. YES
NO
640 Start image DD image 1
image 2 image 3
Target on PU Fault Display on LED / LCD
NO Spontaneous display of flt.annun-
ciations
image 1 Start image Default Display
2.1.2.4
No.
Information List
Information Type of
Comments Informa­tion
- >Light on SP >Back Light on
- Reset LED IntSP Reset LED
- DataStop IntSP Stop data transmission
- Test mode IntSP Test mode
- Feeder gnd IntSP Feeder GROUNDED
- Brk OPENED IntSP Breaker OPENED
- HWTestMod IntSP Hardware Test Mode
- SynchClock IntSP_Ev Clock Synchronization
- Distur.CFC OUT Disturbance CFC 1 Not configured SP No Function configured 2 Non Existent SP Function Not Available 3 >Time Synch SP_Ev >Synchronize Internal Real Time Clock 5 >Reset LED SP >Reset LED 15 >Test mode SP >Test mode
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Functions
2.1 General
No. Information Type of
Informa­tion
16 >DataStop SP >Stop data transmission 51 Device OK OUT Device is Operational and Protecting 52 ProtActive IntSP At Least 1 Protection Funct. is Active 55 Reset Device OUT Reset Device 56 Initial Start OUT Initial Start of Device 67 Resume OUT Resume 68 Clock SyncError OUT Clock Synchronization Error 69 DayLightSavTime OUT Daylight Saving Time 70 Settings Calc. OUT Setting calculation is running 71 Settings Check OUT Settings Check 72 Level-2 change OUT Level-2 change 73 Local change OUT Local setting change 110 Event Lost OUT_Ev Event lost 113 Flag Lost OUT Flag Lost 125 Chatter ON OUT Chatter ON 140 Error Sum Alarm OUT Error with a summary alarm 160 Alarm Sum Event OUT Alarm Summary Event 177 Fail Battery OUT Failure: Battery empty 178 I/O-Board error OUT I/O-Board Error 181 Error A/D-conv. OUT Error: A/D converter 191 Error Offset OUT Error: Offset 193 Alarm NO calibr OUT Alarm: NO calibration data available
236.2127 BLK. Flex.Fct. IntSP BLOCK Flexible Function 301 Pow.Sys.Flt. OUT Power System fault 302 Fault Event OUT Fault Event 303 sens Gnd flt OUT sensitive Ground fault 320 Warn Mem. Data OUT Warn: Limit of Memory Data exceeded 321 Warn Mem. Para. OUT Warn: Limit of Memory Parameter exceeded 322 Warn Mem. Oper. OUT Warn: Limit of Memory Operation exceeded 323 Warn Mem. New OUT Warn: Limit of Memory New exceeded 502 Relay Drop Out SP Relay Drop Out 510 Relay CLOSE SP General CLOSE of relay 545 PU Time VI Time from Pickup to drop out 546 TRIP Time VI Time from Pickup to TRIP 10080 Error Ext I/O OUT Error Extension I/O 10081 Error Ethernet OUT Error Ethernet 10083 Error Basic I/O OUT Error Basic I/O
Comments
2.1.3
2.1.3.1
28 SIPROTEC 4, 7RW80, Manual

Power System Data 1

Functional Description
The device requires certain basic data regarding the protected equipment so that the device can adapt to its desired application. These may be, for instance, nominal power system and transformer data, measured quan­tity polarities and their physical connections, breaker properties (where applicable) etc. There are also certain parameters that are common to all functions, i.e. not associated with a specific protection, control or moni­toring function. The following section discusses these parameters.
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Functions
2.1 General
2.1.3.2
Setting Notes
General
Some P.System Data 1 can be entered directly at the device. See Section 2.14 Notes on Device Operation for more information regarding this topic.
In DIGSI double-click Settings to open the corresponding dialog box. In doing so, a dialog box with tabs will open under P.System Data 1 where individual parameters can be configured. The following descriptions are therefore structured according to these tabs.
Rated Frequency (Power System)
The nominal frequency of the system is set under the Address 214 Rated Frequency. The factory pre­setting in accordance with the model need only be changed if the device will be employed for a purpose other than that which was planned when ordering.
In the US device versions (ordering data position 10= C), parameter 214 is preset to 60 Hz. 214.
Voltage Connection (Power System)
Address 213 specifies how the voltage transformers are connected. VT Connect. 3ph = Van, Vbn, Vcn means that the three phase voltages are wye connected, i.e. the
three phase-to-ground voltages are measured.ground. VT Connect. 3ph = Vab, Vbc, VGnd means that two phase-to-phase voltages (open delta voltage) and
the displacement voltage V VT Connect. 3ph = Vab, Vbc means that two phase-to-phase voltages (open delta voltage) are
connected. The third voltage transformer of the device is not used. VT Connect. 3ph = Vab, Vbc, Vx means that two phase-to-phase voltages (open delta voltage) are
connected. Furthermore, any third voltage Vx is connected that is used exclusively for the flexible protection functions. The transformer nominal voltages for Vx are set at address 232 and 233.
VT Connect. 3ph = Vab, Vbc, VSyn means that two phase-to-phase voltages (open delta voltage) and the reference voltage for V
device is used. VT Connect. 3ph = Vph-g, VSyn is used if the synchronization function of the device is used and only
phase-to-ground voltages are available for the protected object to be synchronized. One of these voltages is connected to the first voltage transformer; the reference voltage V
former. The selection of the voltage transformer connection affects the operation of all device functions that require
voltage input. The settings Vab, Vbc or Vab, Vbc, Vx or Vab, Vbc, VSyn or Vph-g, VSyn do not allow determining
the zero sequence voltage. The associated protection functions are inactive in this case. The table gives an overview of the functions that can be activated for the corresponding connection type
(depends also on the ordering number). The functions which are not shown are available for all connection types.
are connected.
GND
are connected. This setting is enabled if the synchronization function of the
SYN
is connected to the third voltage trans-
SYN
Table 2-1
Connection Types of the Voltage Transformers
Connection type Synchronization
Van, Vbn, Vcn
Vab, Vbc, VGnd
Vab, Vbc
Vab, Vbc, Vx
Vab, Vbc, VSyn
Vph-g, VSyn
no no no
no yes yes
Measured values, which due to the chosen voltage connection cannot be calculated, will be displayed as dots.
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Functions
2.1 General
The Appendix provides some connection examples for all connection types atC Connection Examples.
Nominal Values of Voltage Transformers (VTs)
At addresses 202 Vnom PRIMARY and 203 Vnom SECONDARY, information is entered regarding the primary nominal voltage and secondary nominal voltage (phase-to-phase) of the connected voltage transformers.
Transformation Ratio of Voltage Transformers (VTs)
Address 206 Vph / Vdelta informs the device of the adjustment factor between the phase voltage and the displacement voltage. This information is relevant for the processing of ground faults (in grounded systems and ungrounded systems), for the operational measured value VN and measured-variable monitoring.
If the voltage transformer set provides open delta windings and if these windings are connected to the device, this must be specified accordingly in address 213 (see above margin heading “Voltage Connection”). Since the voltage transformer ratio is normally as follows:
[uebersetzung-spannungswandler-020313-kn, 1, en_US]
the factor V
(secondary voltage, address 206 Vph / Vdelta) must be set to 3/ √3 = √3 = 1.73 which
ph/VN
must be used if the VN voltage is connected. For other transformation ratios, i.e. the formation of the displacement voltage via an interconnected transformer set, the factor must be corrected accordingly.
Please take into consideration that also the calculated secondary V0-voltage is divided by the value set in address 206. Thus, even if the V0-voltage is not connected, address 206 has an impact on the secondary operational measured value VN.
If Vab, Vbc, VGnd is selected as voltage connection type, parameter Vph / Vdelta is used to calculate the phase-to-ground voltages and is therefore important for the protection function. With voltage connection type Van, Vbn, Vcn, this parameter is used only to calculate the operational measured value of the secon­dary voltage VN.
Trip and Close Command Duration (Breaker)
In address 210 the minimum trip command duration TMin TRIP CMD is set. This setting applies to all protec­tion functions that can initiate tripping.
In address 211 the maximum close command duration TMax CLOSE CMD is set. It applies to the integrated reclosing function. It must be set long enough to ensure that the circuit breaker has securely closed. An exces­sive duration causes no problem since the closing command is interrupted in the event another trip is initiated by a protection function.
Pickup Thresholds of the Binary Inputs (Thresholds BI)
At address 220 Threshold BI 1 to 226 Threshold BI 7 you can set the pickup thresholds of the binary inputs of the device. The settings Thresh. BI 176V, Thresh. BI 88V or Thresh. BI 19V are possible.
Voltage Protection (Protection Operating Quantities)
In a three-phase connection, the fundamental harmonic of the three phase-to-phase voltages (Vphph) or phase-ground voltages (Vph-n) or the positive sequence voltage (V1) or the negative sequence voltage (V2) is supplied to the overvoltage protection elements.
In three-phase connection, undervoltage protection relies either on the positive sequence voltage (V1) or the phase-to-phase voltages (Vphph) or the phase-to-ground voltages (Vph-n).
This is configured by setting the parameter value in address 614 OP. QUANTITY 59 and 615 OP. QUAN- TITY 27.
Via Parameter 5009 59 Phases and 5109 27 Phases you may configure which measured quantity is to be evaluated (All phases or Largest phase or Smallest phase).
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Functions
2.1 General
With single-phase voltage transformers, a direct comparison of the measured quantities with the threshold values is carried out and the parameterization of the characteristic quantity switchover is ignored.
NOTE
If parameter 213 VT Connect. 3ph is set to Vph-g, VSyn, the voltage measured by voltage trans­former 1 is always used for voltage protection. Then parameters 614 and 615 are not available.
NOTE
If parameter 213 VT Connect. 3ph is set to Vab, Vbc, VSyn or Vab, Vbc or Vab, Vbc, Vx, the setting option Vph-n for parameter 614 and 615 is not available.
2.1.3.3
Addr. Parameter Setting Options Default Setting Comments
202 Vnom PRIMARY 0.10 .. 800.00 kV 20.00 kV Rated Primary Voltage 203 Vnom SECONDARY 34 .. 225 V 100 V Rated Secondary Voltage (L-L) 206A Vph / Vdelta 1.00 .. 3.00 1.73 Matching ratio Phase-VT To Open-
209 PHASE SEQ. A B C
210A TMin TRIP CMD 0.01 .. 32.00 sec 0.15 sec Minimum TRIP Command Duration 211A TMax CLOSE CMD 0.01 .. 32.00 sec 1.00 sec Maximum Close Command Dura-
213 VT Connect. 3ph Van, Vbn, Vcn
214 Rated Frequency 50 Hz
220 Threshold BI 1 Thresh. BI 176V
221 Threshold BI 2 Thresh. BI 176V
222 Threshold BI 3 Thresh. BI 176V
223 Threshold BI 4 Thresh. BI 176V
224 Threshold BI 5 Thresh. BI 176V
Settings
Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Delta-VT
A B C Phase Sequence
A C B
tion
Van, Vbn, Vcn VT Connection, three-phase Vab, Vbc, VGnd Vab, Vbc, VSyn Vab, Vbc Vph-g, VSyn Vab, Vbc, Vx
50 Hz Rated Frequency 60 Hz
Thresh. BI 176V Threshold for Binary Input 1 Thresh. BI 88V Thresh. BI 19V
Thresh. BI 176V Threshold for Binary Input 2 Thresh. BI 88V Thresh. BI 19V
Thresh. BI 176V Threshold for Binary Input 3 Thresh. BI 88V Thresh. BI 19V
Thresh. BI 176V Threshold for Binary Input 4 Thresh. BI 88V Thresh. BI 19V
Thresh. BI 176V Threshold for Binary Input 5 Thresh. BI 88V Thresh. BI 19V
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Functions
2.1 General
Addr. Parameter Setting Options Default Setting Comments
225 Threshold BI 6 Thresh. BI 176V
Thresh. BI 176V Threshold for Binary Input 6 Thresh. BI 88V Thresh. BI 19V
226 Threshold BI 7 Thresh. BI 176V
Thresh. BI 176V Threshold for Binary Input 7 Thresh. BI 88V Thresh. BI 19V
232 VXnom PRIMARY 0.10 .. 800.00 kV 20.00 kV Rated Primary Voltage X 233 VXnom SECONDARY 100 .. 225 V 100 V Rated Secondary Voltage X 614A OP. QUANTITY 59 Vphph
Vph-n
Vphph Opera. Quantity for 59 Overvolt.
Prot.
V1 V2
615A OP. QUANTITY 27 V1
Vphph
V1 Opera. Quantity for 27 Undervolt.
Prot.
Vph-n
2.1.3.4
No. Information Type of
Information List
Comments Informa­tion
5145 >Reverse Rot. SP >Reverse Phase Rotation 5147 Rotation ABC OUT Phase rotation ABC 5148 Rotation ACB OUT Phase rotation ACB
2.1.4

Oscillographic Fault Records

The Multifunctional Protection with Control 7RW80 is equipped with a fault record memory. The instanta­neous values of the measured values
vA, vB, vC, vA2, vB3, vC1, vN, vX, v
ph-n
, v
SYN
(voltages depending on connection) are sampled at intervals of 1.0 ms (at 50 Hz) and stored in a revolving buffer (20 samples per cycle). In the event of a fault, the data are recorded for a set period of time, but not for more than 5 seconds. A maximum of 8 faults can be recorded in this buffer. The fault record memory is auto­matically updated with every new fault, so no acknowledgment for previously recorded faults is required. In addition to protection pickup, the recording of the fault data can also be started via a binary input or via the serial interface.
2.1.4.1
Functional Description
The data of a fault event can be read out via the device interface and evaluated with the help of the SIGRA 4 graphic analysis software. SIGRA 4 graphically represents the data recorded during the fault event and also calculates additional information from the measured values. Currents and voltages can be presented either as primary or as secondary values. Signals are additionally recorded as binary tracks (marks), e.g. "pickup", "trip".
If port B of the device has been configured correspondingly, the fault record data can be imported by a central controller via this interface and evaluated. Currents and voltages are prepared for a graphic representation. Signals are additionally recorded as binary tracks (marks), e.g. "pickup", "trip".
The retrieval of the fault data by the central controller takes place automatically either after each protection pickup or after a tipping.
Depending on the selected type of connection of the voltage transformers (address 213 VT Connect. 3ph), the following measured values are recorded in the fault record:
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2.1 General
Voltage connection
Van, Vbn, Vcn Vab, Vbc,
VGnd
v
AB
v
BC
v
CA
v
A
v
B
v
C
v yes v
en
v
SYN
v
x
yes yes yes yes yes
yes yes yes yes yes
yes yes yes yes yes
yes yes
yes yes
yes yes
yes yes
NOTE
The signals used for the binary tracks can be allocated in DIGSI.
Vab, Vbc Vab, Vbc, Vx Vab, Vbc, VSyn Vph-g, VSyn
yes yes
yes
Functions
2.1.4.2
Configuration
Setting Notes
Fault recording (waveform capture) will only take place if address 104 OSC. FAULT REC. is set to Enabled. Other settings pertaining to fault recording (waveform capture) are found in the Osc. Fault Rec. submenu of the SETTINGS menu. Waveform capture makes a distinction between the trigger instant for an oscillographic record and the criterion to save the record (address 401 WAVEFORMTRIGGER). Normally, the trigger is the pickup of a protection element, i.e. the time 0 is defined as the instant the first protection func­tion picks up. The criterion for saving may be both the device pickup (Save w. Pickup) or the device trip (Save w. TRIP). A trip command issued by the device can also be used as trigger instant (Start w. TRIP), in this case it is also the saving criterion.
A fault event starts with the pickup by any protection function and ends when the last pickup of a protection function has dropped out. Usually this is also the extent of a fault recording (address 402 WAVEFORM DATA = Fault event). If automatic reclosing is performed by external equipments, the entire system fault — with several reclosing attempts if necessary — can be recorded until the fault has been cleared for good (address 402 WAVEFORM DATA = Pow.Sys.Flt.). This facilitates the representation of the entire system fault history, but also consumes storage capacity during the automatic reclosing dead time(s).
The actual storage time begins at the pre-fault time PRE. TRIG. TIME (address 404) ahead of the reference instant, and ends at the post-fault time POST REC. TIME (address 405) after the storage criterion has reset. The maximum storage duration of each fault record (MAX. LENGTH) is entered at address 403. Recording per fault must not exceed 5 seconds. In maximum 8 records can be saved altogether with a maximum total time of 20 s 18 s .
An oscillographic record can be triggered by a status change of a binary input, or from a PC via the operator interface. Storage is then triggered dynamically. The length of the fault recording is set in address 406 BinIn CAPT.TIME (but not longer than MAX. LENGTH, address 403). Pre-fault and post-fault times will add to this. If the binary input time is set to ∞, the length of the record equals the time that the binary input is activated (static), but not longer than the MAX. LENGTH (address 403).
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Functions
2.1 General
2.1.4.3
Addr. Parameter Setting Options Default Setting Comments
401 WAVEFORMTRIGGER Save w. Pickup
402 WAVEFORM DATA Fault event
403 MAX. LENGTH 0.30 .. 5.00 sec 2.00 sec Max. length of a Waveform
404 PRE. TRIG. TIME 0.05 .. 0.50 sec 0.10 sec Captured Waveform Prior to
405 POST REC. TIME 0.05 .. 0.50 sec 0.10 sec Captured Waveform after Event 406 BinIn CAPT.TIME 0.10 .. 5.00 sec 0.50 sec Capture Time via Binary Input
2.1.4.4
No. Information Type of
- FltRecSta IntSP Fault Recording Start 4 >Trig.Wave.Cap. SP >Trigger Waveform Capture 203 Wave. deleted OUT_Ev Waveform data deleted 30053 Fault rec. run. OUT Fault recording is running
Settings
Save w. Pickup Waveform Capture Save w. TRIP Start w. TRIP
Fault event Scope of Waveform Data Pow.Sys.Flt.
Capture Record
Trigger
Information List
Comments Informa­tion
2.1.5
2.1.5.1
Changing Setting Groups
2.1.5.2
General

Settings Groups

Up to four different setting groups can be created for establishing the device's function settings.
Functional Description
During operation the user can switch back and forth setting groups locally, via the operator panel, binary inputs (if so configured), the service interface using a personal computer, or via the system interface. For reasons of safety it is not possible to change between setting groups during a power system fault.
A setting group includes the setting values for all functions that have been selected as Enabled during configuration (see Section 2.1.1.2 Setting Notes). In 7RW80 relays, four independent setting groups (A to D) are available. While setting values may vary, the selected functions of each setting group remain the same.
Setting Notes
If setting group change option is not required, Group A is the default selection. Then, the rest of this section is not applicable.
If the changeover option is desired, group changeover must be set to Grp Chge OPTION = Enabled (address 103) when the function extent is configured. For the setting of the function parameters, each of the required setting groups A to D (a maximum of 4) must be configured in sequence. The SIPROTEC 4 System Description gives further information on how to copy setting groups or reset them to their status at delivery and also how to change from one setting group to another.
Section 3.1 Mounting and Connections of this manual tells you how to change between several setting groups externally via binary inputs.
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Functions
2.1 General
2.1.5.3
Addr. Parameter Setting Options Default Setting Comments
302 CHANGE Group A
2.1.5.4
No. Information Type of
- P-GrpA act IntSP Setting Group A is active
- P-GrpB act IntSP Setting Group B is active
- P-GrpC act IntSP Setting Group C is active
- P-GrpD act IntSP Setting Group D is active 7 >Set Group Bit0 SP >Setting Group Select Bit 0 8 >Set Group Bit1 SP >Setting Group Select Bit 1
2.1.6
Settings
Group A Change to Another Setting Group Group B Group C Group D Binary Input Protocol
Information List
Comments Informa­tion

Power System Data 2

2.1.6.1
Applications
2.1.6.2
Rated Values of the System
2.1.6.3
Addr.
1101 FullScaleVolt. 0.10 .. 800.00 kV 20.00 kV Measurem:FullScale-
2.1.6.4
Functional Description
The general protection data (P.System Data 2) include settings associated with all functions rather than a specific protection or monitoring function. In contrast to the P.System Data 1 as discussed before, they can be changed with the setting group.
When the primary reference voltage and the primary reference current of the protected object are set, the device is able to calculate and output the operational measured value percentage.
Setting Notes
At address 1101 FullScaleVolt. the reference voltage (phase-to-phase) of the monitored equipment is entered. If these reference values match the primary values of the voltage transformer, they correspond to the setting at Address 202 (Section 2.1.3.2 Setting Notes). They are generally used to show values referenced to full scale.
Settings
Parameter Setting Options Default Setting Comments
Voltage(Equipm.rating)
Information List
No.
126 ProtON/OFF IntSP Protection ON/OFF (via system port)
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Information Type of
Informa­tion
Comments
Functions
2.1 General
No. Information Type of
Informa­tion
356 >Manual Close SP >Manual close signal 501 Relay PICKUP OUT Relay PICKUP 511 Relay TRIP OUT Relay GENERAL TRIP command 561 Man.Clos.Detect OUT Manual close signal detected 4601 >52-a SP >52-a contact (OPEN, if bkr is open) 4602 >52-b SP >52-b contact (OPEN, if bkr is closed)
2.1.7
2.1.7.1
2.1.7.2
Interface Selection

EN100-Module

Functional Description
The Ethernet EN100-Modul enables integration of the 7RW80 in 100-Mbit communication networks in control and automation systems with the protocols according to IEC 61850 standard. This standard permits uniform communication of the devices without gateways and protocol converters. Even when installed in heteroge­neous environments, SIPROTEC 4 relays therefore provide for open and interoperable operation. Parallel to the process control integration of the device, this interface can also be used for communication with DIGSI and for inter-relay communication via GOOSE.
Setting Notes
Comments
No special settings are required for operating the Ethernet system interface module (IEC 1850, Ethernet EN100-Modul). If the ordered version of the device is equipped with such a module, it is automatically allo- cated to the interface available for it, namely Port B.
2.1.7.3
No.
009.0100 Failure Modul IntSP Failure EN100 Modul
009.0101 Fail Ch1 IntSP Failure EN100 Link Channel 1 (Ch1)
009.0102 Fail Ch2 IntSP Failure EN100 Link Channel 2 (Ch2)
Information List
Information Type of
Informa­tion
Comments
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Functions

2.2 Voltage Protection 27, 59

2.2
2.2.1
Connection/Measured Values
Voltage Protection 27, 59
Voltage protection has the task to protect electrical equipment against undervoltage and overvoltage. Both operational states are abnormal as overvoltage may cause for example insulation problems or undervoltage may cause stability problems.
There are three elements each available for overvoltage protection and undervoltage protection.
Applications
Abnormally high voltages often occur e.g. in low loaded, long distance transmission lines, in islanded
systems when generator voltage regulation fails, or after full load rejection of a generator from the system.
The undervoltage protection function detects voltage collapses on transmission lines and electrical
machines and prevents inadmissible operating states and a possible loss of stability.

Measurement Principle

The voltages supplied to the device may correspond to the three phase-to-ground voltages V the two phase-to-phase voltages (V of a single-phase connection - any phase-to-ground voltage. The connection type has been specified during
the configuration in parameter 213 VT Connect. 3ph (see Section 2.1.3.2 Setting Notes). The following table indicates which voltages can be evaluated by the function. The settings for this are made
in the P.System Data 1 (see Section 2.1.3.2 Setting Notes). Furthermore, it is indicated to which value the threshold must be set. All voltages are fundamental frequency values.
A-N
, V
) and the displacement voltage (ground voltage VN) or - in the case
A-B
B-C
, V
B-N
, V
C-N
or
Table 2-2
Connection, threephase
(parameter213)
Overvoltage
Van, Vbn, Vcn
Vab, Vbc, VGnd
Vab, Vbc
Vab, Vbc, VSyn
Vab, Vbc, Vx
Vph-g, VSyn
Undervoltage
Van, Vbn, Vcn
Voltage protection, selectable voltages
Selectable voltage
parameter 614/ 615
Vphph (largest phase-to-phase voltage) Phase-to-phase voltage Vph-n ((largest phase-to-ground voltage) Phase-to-ground voltage V1(positive sequence voltage) Positive sequence voltage calculated
V2 (negative sequence voltage) Negative sequence voltage Vphph (largest phase-to-phase voltage) Leiter-Leiter-Spannung V1(positive sequence voltage) Positive sequence voltage V2 (negative sequence voltage) Negative sequence voltage
None (direct evaluation of the voltage connected to voltage input 1)
Vphph (smallest phase-to-phase voltage) Phase-to-phase voltage Vph-n (smallest phase-to-ground voltage) Phase-to-ground voltage V1 (positive sequence voltage) Positive sequence voltage· √3
Threshold to be set as
from phase-to-groundvoltage or phase-tophase voltage / √3
Direct voltage value
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Functions
2.2 Voltage Protection 27, 59
Connection, threephase
(parameter213)
Vab, Vbc, VGnd
Vab, Vbc
Vab, Vbc, VSyn
Vab, Vbc, Vx
Vph-g, VSyn
The positive and negative sequence voltages stated in the table are calculated from the phase-to-ground voltages.
2.2.2

Overvoltage Protection 59

Function
The overvoltage protection includes three elements (59-1 PICKUP, 59-2 PICKUP, 59 Vp>). In case of a high overvoltage, the switchoff is performed with a short-time delay, whereas in case of lower overvoltages, the switchoff is performed with a longer time delay. When an adjustable setting is exceeded, the 59 element picks up, and after an adjustable time delay elapses, initiates a trip signal. The time delay is not dependent on the magnitude of the overvoltage.
Additionally the element 59 Vp> allows the definition of a user defined tripping curve with 20 value pairs (voltage/ time). Parameterization is done via DIGSI.
For both over-voltage elements 59-1 PICKUP, 59-2 PICKUP the dropout ratio (= V parameterized. A parameter is set to specify, whether the measured values of all phases or only phases with the highest value
for monitoring are being used. The following figure shows the logic diagram of the overvoltage protection function.
Selectable voltage
Threshold to be set as
parameter 614/ 615
Vphph (smallest phase-to-phase voltage) Phase-to-phase voltage V1 ((positive sequence voltage) Positive sequence voltage· √3
None (direct evaluation of the voltage connected to
Direct voltage value
voltage input 1)
dropout/Vpickup
) can be
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Functions
2.2 Voltage Protection 27, 59
[7rw80-ueberspgs-schutz-20100716, 1, en_US]
2.2.3
Figure 2-2

Undervoltage Protection 27

Logic diagram of the overvoltage protection
Funktion
Undervoltage protection consists of three elements (27-1 PICKUP, 27-2 PICKUP, 27 Vp<). Therefore, trip­ping can be time-graded depending on how severe voltage collapses are. Voltage thresholds and time delays can be set individually for both elements 27-1 PICKUP and 27-2 PICKUP.
Additionally the element27 Vp< allows the definition of a user defined tripping curve with 20 value pairs (voltage/ time). Parameterization is done via DIGSI.
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Functions
2.2 Voltage Protection 27, 59
For both under-voltage elements 27-1 PICKUP and 27-2 PICKUP the dropout ratio (= V
dropout/Vpickup
) can be parameterized. A parameter is set to specify, whether the measured values of all phases or only phases with the lowest value
for monitoring are being used. The undervoltage protection works in an additional frequency range. This ensures that the protective function
is preserved even when it is applied e.g. as motor protection in context with decelerating motors. However, the r.m.s. value of the positive-sequence voltage component is considered too small when severe frequency deviations exist. This function therefore exhibits an overfunction.
Figure 2-3 shows a typical voltage profile during a fault for source side connection of the voltage trans-
formers. After the voltage has decreased below the pickup setting, tripping is initiated after time delay 27-1 DELAY. As long as the voltage remains below the drop out setting, reclosing is blocked. Only after the fault
has been cleared, i.e. when the voltage increases above the drop out level, the element drops out and allows reclosing of the circuit breaker.
[stoerfallverlauf-speiseseitig-20100525, 1, en_US]
Figure 2-3 Typical fault profile for supply-side connection of the voltage transformers
The following Figure shows the logic diagram of the undervoltage protection function.
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Functions
2.2 Voltage Protection 27, 59
[7rw80-unterspgs-schutz-20100525, 1, en_US]
Logic diagram of the undervoltage protection
2.2.4
Figure 2-4

Setting Notes

General
Voltage protection is only in effect and accessible if address 150 27/59 is set to Enabled during configura­tion of protective functions. If the function is not required Disabled is set.
The voltage to be evaluated is selected in Power System Data 1 (see Chapter 2.2 Voltage Protection 27, 59,
Table 2-2).
Overvoltage protection can be turned ON or OFF or set to Alarm Only at address 5001 FCT 59.
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Functions
2.2 Voltage Protection 27, 59
Undervoltage protection can be turned ON or OFF or set to Alarm Only at address 5101 FCT 27. With the protection function ON tripping, fault record and fault recording will occur when limit values were
exceeded and after time delays expired. When setting Alarm Only no trip command is given, no fault is recorded and no spontaneous fault annunci-
ation is shown on the display. For over-voltage and under-voltage protection user-defined curves with 20 value pairs (voltage/time) may be
configured. Usage of a curve has to be activated at address 5035 Pickup - Time for the element 59 Vp> and at address 5133 Pickup - Time for the element 27 Vp<.
Overvoltage Protection (59-1, 59-2) with phase-to-phase / phase-to-ground voltage
For over-voltage protection with phase-to-phase or phase-to-ground voltages you have to configure at address 5009 59 Phases the measured quantity that is to be evaluated for the over voltage protection. While being configuredAll phases all voltages have to exceed their threshold. AtLargest phase only one voltage has to exceed its threshold.
The threshold values are set in the value to be evaluated (see Chapter 2.2 Voltage Protection 27, 59,
Table 2-2).
Overvoltage protection includes three elements. The pickup value of the lower threshold is set at address 5002 or 5003, 59-1 PICKUP, (depending on if the phase-to-ground or the phase-to-phase voltages are connected), while time delay is set at address 5004, 59-1 DELAY (a longer time delay). The pickup value of the upper element is set at address 5005 or 5006, 59-2 PICKUP, while the time delay is set at address 5007, 59-2 DELAY (a short time delay). A third element can be activated at address 5031 59 Vp>, which works with a user-defined curve (address 5035).
There are not clear cut procedures on how to set the pickup values. However, since the overvoltage function is primarily intended to prevent insulation damage on equipment and loads, the setting value 5002 , 5003 59-1
PICKUP should be set between 110 % and 115 % of nominal voltage, and setting value 5005, 5006 59-2 PICKUP should be set to about 130 % of nominal voltage.
The time delays of the overvoltage elements are entered at addresses 5004 59-1 DELAY, 5007 59-2 DELAY and 5034 59 T Vp> and should be selected to allow the brief voltage spikes that are generated during switching operations and to enable clearance of stationary overvoltages in time.
The option to choose between phase-to-ground and phase-to-phase voltage, allows voltage asymmetries (e.g. caused by a ground fault) to be taken into account (phase-to-ground) or to remain unconsidered (phase–to­phase) during evaluation.
Overvoltage Protection - Positive Sequence System V1
In a three-phase voltage transformer connection the positive sequence system can be evaluated for the over­voltage protection by means of configuring parameter 614 OP. QUANTITY 59 to V1. In this case, the threshold values of the overvoltage protection must be set in parameters 5019 59-1 PICKUP V1 or 5020 59-2 PICKUP V1. A third element can be activated at address 5032 59 Vp> V1, which works with a user­defined curve (address 5035).
Overvoltage Protection - Negative Sequence System V2
In a three-phase transformer connection, parameter 614 OP. QUANTITY 59 can determine that the negative sequence system V2 can be evaluated as a measured value for the overvoltage protection. The negative sequence system detects voltage asymmetries.
Overvoltage protection includes three elements. Thus, with configuration of the negative system, a longer time delay (Adresse 5004, 59-1 DELAY) may be assigned to the lower element (address 5015, 59-1 PICKUP V2) depending on whether phase-to-ground or phase-to-phase voltages are connected) and a shorter time delay (address 5007, 59-2 DELAY) may be assigned to the upper element (Address 5016, 59-2 PICKUP V2). A third element can be activated at address 5033 59 Vp> V2, which works with a user-defined curve (address 5035).
There are not clear cut procedures on how to set the pickup values 59-1 PICKUP V2 or 59-2 PICKUP V2, as they depend on the respective station configuration.
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The time delays of the overvoltage elements are entered at addresses 5004 59-1 DELAY and 5007 59-2 DELAY, and should be selected in such manner that they make allowance for brief voltage peaks that are generated during switching operations and also enable clearance of stationary overvoltages in due time.
Dropout Threshold of the Overvoltage Protection
The dropout thresholds of the 59-1 element and the 59-2 element can be configured via the dropout ratio r = V
Dropout/VPickup
at addresses 5017 59-1 DOUT RATIO or 5018 59-2 DOUT RATIO. The following marginal condition applies to r: r · (configured pickup threshold) ≤ 150 V with connection of phase-to-phase voltages and phase-to-ground
voltages or r · (configured pickup threshold) ≤ 260 V with calculation of the measured values from the connected voltages
(e.g. phase-to-phase voltages calculated from the connected phase-to-ground voltages). The minimum hysteresis is 0.6 V.
Undervoltage Protection - Positive Sequence System V1
The positive sequence component (V1) can be evaluated for the undervoltage protection. Especially in case of stability problems, their acquisition is advantageous because the positive sequence system is relevant for the limit of the stable energy transmission. Concerning the pickup values there are no specific notes on how to set them. However, because the undervoltage protection function is primarily intended to protect induction machines from voltage dips and to prevent stability problems, the pickup values will usually be between 60 % and 85 % of the nominal voltage.
The threshold value is multiplied as positive sequence voltage and set to √ nominal voltage.
Undervoltage protection with evaluation of the positive sequence componentscomprises two elements. The pickup value of the lower threshold is set at address 5110 or 5111, 27-2 PICKUP (depending on the voltage transformer connection, phase-to-ground or phase-to-phase), while time delay is set at address 5112, 27-2
DELAY (short time delay). The pickup value of the upper element is set at address 5102 or 5103, 27-1 PICKUP, while the time delay is set at address 5106, 27-1 DELAY (a somewhat longer time delay). Setting
these elements in this way allows the undervoltage protection function to closely follow the stability behavior of the system.
The time settings should be selected such that tripping occurs in response to voltage dips that lead to unstable operating conditions. On the other hand, the time delay should be long enough to avoid tripping on short­term voltage dips.
Functions
2.2 Voltage Protection 27, 59
3, thus realizing the reference to the
Undervoltage Protection with Phase-to-phase or Phase-to-ground Voltages
For undervoltage protection with phase-to-phase or phase-to-ground voltages you have to configure at address 5109 27 Phases the measured quantity that is to be evaluated for the undervoltage protection. While being configured All phases all voltages have to underrun their threshold. At Smallest phase only one voltage has to underrun its threshold.
The threshold values are set in the value to be evaluated (see Chapter 2.2 Voltage Protection 27, 59,
Table 2-2)
Undervoltage protection includes three elements. The pickup value of the lower threshold is set at address 5110 or 5111, 27-2 PICKUP (depending on the voltage transformer connection, phase-to-ground or phaseto- phase), while time delay is set at address 5112, 27-2 DELAY (short time delay). The pickup value of the upper element is set at address 5102 or 5103, 27-1 PICKUP, while the time delay is set at address 5106, 27-1 DELAY (a somewhat longer time delay). Setting these elements in this matter allows the undervoltage protection function to closely follow the stability behaviour of the system. A third element can be activated at address 5131 27 Vp<, which works with a user-defined curve (address 5133). The corresponding delay time can be configured at address 5132 27 T Vp<.
The time settings should be selected such that tripping occurs in response to voltage dips that lead to unstable operating conditions. On the other hand, the time delay should be long enough to avoid tripping on short­term voltage dips.
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i
i
Functions
2.2 Voltage Protection 27, 59
Dropout Threshold of the Undervoltage Protection
The dropout thresholds of the 59-1 element and the 59-2 element can be parameterized via the dropout ratio r = V
dropout/Vpickup
applies to r: r · (configured pickup threshold) ≤ 130 V with connection of phase-to-phase voltages and phase-to-ground
voltages) or r· (configured pickup threshold) ≤ 225 V with calculation of the measured values from the connected voltages
(e.g. calculated phase-to-phase voltages from the connected phase-to-ground voltages). The minimum hysteresis is 0.6 V.
NOTE
If a setting is selected such that the dropout threshold (= pickup threshold · dropout ratio) results in a greater value than 130 V/225 V, it will be limited automatically. No error message occurs.
(5113 27-1 DOUT RATIO or 5114 27-2 DOUT RATIO). The following marginal condition
2.2.5
Addr. Parameter Setting Options Default Setting Comments
5001 FCT 59 OFF
5002 59-1 PICKUP 20 .. 260 V 110 V 59-1 Pickup 5003 59-1 PICKUP 20 .. 150 V 110 V 59-1 Pickup 5004 59-1 DELAY 0.00 .. 100.00 sec 0.50 sec 59-1 Time Delay 5005 59-2 PICKUP 20 .. 260 V 120 V 59-2 Pickup 5006 59-2 PICKUP 20 .. 150 V 120 V 59-2 Pickup 5007 59-2 DELAY 0.00 .. 100.00 sec 0.50 sec 59-2 Time Delay 5009 59 Phases All phases
5015 59-1 PICKUP V2 2 .. 150 V 30 V 59-1 Pickup V2 5016 59-2 PICKUP V2 2 .. 150 V 50 V 59-2 Pickup V2 5017A 59-1 DOUT RATIO 0.90 .. 0.99 0.95 59-1 Dropout Ratio 5018A 59-2 DOUT RATIO 0.90 .. 0.99 0.95 59-2 Dropout Ratio 5019 59-1 PICKUP V1 20 .. 150 V 110 V 59-1 Pickup V1 5020 59-2 PICKUP V1 20 .. 150 V 120 V 59-2 Pickup V1 5030 59 Vp> 20 .. 260 V 110 V 59 Pickup Vp> 5031 59 Vp> 20 .. 150 V 110 V 59 Pickup Vp> 5032 59 Vp> V1 20 .. 150 V 110 V 59 Pickup Vp> V1 5033 59 Vp> V2 2 .. 150 V 30 V 59 Pickup Vp> V2 5034 59 T Vp> 0.1 .. 5.0 sec 5.0 sec 59 T Vp> Time Delay 5035 Pickup - Time 1.00 .. 20.00
5101 FCT 27 OFF
5102 27-1 PICKUP 10 .. 210 V 75 V 27-1 Pickup 5103 27-1 PICKUP 10 .. 120 V 45 V 27-1 Pickup 5106 27-1 DELAY 0.00 .. 100.00 sec 1.50 sec 27-1 Time Delay

Settings

Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
OFF 59 Overvoltage Protection ON Alarm Only
Largest phase Phases for 59 Largest phase
Pickup - Time
0.01 .. 999.00
OFF 27 Undervoltage Protection ON Alarm Only
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2.2 Voltage Protection 27, 59
Addr. Parameter Setting Options Default Setting Comments
5109 27 Phases Smallest phase
All phases 5110 27-2 PICKUP 10 .. 210 V 70 V 27-2 Pickup 5111 27-2 PICKUP 10 .. 120 V 40 V 27-2 Pickup 5112 27-2 DELAY 0.00 .. 100.00 sec 0.50 sec 27-2 Time Delay 5113A 27-1 DOUT RATIO 1.01 .. 3.00 1.20 27-1 Dropout Ratio 5114A 27-2 DOUT RATIO 1.01 .. 3.00 1.20 27-2 Dropout Ratio 5130 27 Vp< 10 .. 210 V 75 V 27 Pickup Vp< 5131 27 Vp< 10 .. 120 V 45 V 27 Pickup Vp< 5132 27 T Vp< 0.1 .. 5.0 sec 1.0 sec 27 T Vp< Time Delay 5133 Pickup - Time 0.05 .. 1.00
0.01 .. 999.00
All phases Phases for 27
Pickup - Time
Functions
2.2.6
No. Information Type of
234.2100 27, 59 blk IntSP 27, 59 blocked via operation 6503 >BLOCK 27 SP >BLOCK 27 undervoltage protection 6506 >BLOCK 27-1 SP >BLOCK 27-1 Undervoltage protection 6508 >BLOCK 27-2 SP >BLOCK 27-2 Undervoltage protection 6513 >BLOCK 59 SP >BLOCK 59 overvoltage protection 6530 27 OFF OUT 27 Undervoltage protection switched OFF 6531 27 BLOCKED OUT 27 Undervoltage protection is BLOCKED 6532 27 ACTIVE OUT 27 Undervoltage protection is ACTIVE 6533 27-1 picked up OUT 27-1 Undervoltage picked up 6534 27-1 PU CS OUT 27-1 Undervoltage PICKUP w/curr. superv 6537 27-2 picked up OUT 27-2 Undervoltage picked up 6538 27-2 PU CS OUT 27-2 Undervoltage PICKUP w/curr. superv 6539 27-1 TRIP OUT 27-1 Undervoltage TRIP 6540 27-2 TRIP OUT 27-2 Undervoltage TRIP 6565 59 OFF OUT 59 Overvoltage protection switched OFF 6566 59 BLOCKED OUT 59 Overvoltage protection is BLOCKED 6567 59 ACTIVE OUT 59 Overvoltage protection is ACTIVE 6568 59-1 picked up OUT 59-1 Overvoltage V> picked up 6570 59-1 TRIP OUT 59-1 Overvoltage V> TRIP 6571 59-2 picked up OUT 59-2 Overvoltage V>> picked up 6573 59-2 TRIP OUT 59-2 Overvoltage V>> TRIP 17370 >BLOCK Vp< SP >Block Undervoltage protection Vp< 17371 >BLOCK Vp> SP >Block Overvoltage protection Vp> 17372 Vp< picked up OUT Vp< Undervoltage picked up 17373 Vp> picked up OUT Vp> Overvoltage picked up 17374 Vp< TRIP OUT Vp< Undervoltage TRIP 17375 Vp> TRIP OUT Vp> Overvoltage TRIP

Information List

Comments Informa­tion
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Functions

2.3 Frequency Protection 81 O/U

2.3
2.3.1
Detection of Frequency
Frequency Protection 81 O/U
The frequency protection function detects abnormally high and low frequencies in the system or in electrical machines. If the frequency lies outside the allowable range, appropriate actions are initiated, such as load shedding or separating a generator from the system.
Applications
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. The frequency protection function is also used for generators which (for a certain time) operate to an island network. This is due to the fact that the reverse power protection cannot operate in case of a drive power failure. The generator can be disconnected from the power system by means of the frequency decrease protection.
Increase in system frequency occurs e.g. when large blocks of load (island network) are removed from
the system, or again when a malfunction occurs with a generator governor. This entails risk of self-excita­tion for generators feeding long lines under no-load conditions.

Functional Description

The frequency is detected preferably from the positive sequence voltage. If this voltage is too low, the phase­to-phase voltage V
to-phase voltages is used instead. Through the use of filters and repeated measurements, the frequency evaluation is free from harmonic influ-
ences and very accurate.
at the device is used. If the amplitude of this voltage is too small, one of the other phase-
A-B
Overfrequency/Underfrequency
Frequency protection consists of four frequency elements. To make protection flexible for different power system conditions, theses elements can be used alternatively for frequency decrease or increase separately, and can be independently set to perform different control functions.
Operating Range
The frequency can be determined as long as in a three-phase voltage transformer connection the positive­sequence system of the voltages, or alternatively, in a single-phase voltage transformer connection, the respective voltage is present and of sufficient magnitude. If the measured voltage drops below a settable value Vmin, the frequency protection is blocked because no precise frequency values can be calculated from the signal.
Time Delays / Logic
Each frequency element has an associated settable time delay. When the time delay elapses, a trip signal is generated. When a frequency element drops out, the tripping command is immediately terminated, but not before the minimum command duration has elapsed.
Each of the four frequency elements can be blocked individually via binary inputs. The following figure shows the logic diagram for the frequency protection function.
46 SIPROTEC 4, 7RW80, Manual
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Functions
2.3 Frequency Protection 81 O/U
[dw_7sj6x_frequenzschutz, 1, en_US]
Logic diagram of the frequency protection
2.3.2
Figure 2-5

Setting Notes

General
Frequency protection is only in effect and accessible if address 154 81 O/U is set to Enabled during configu­ration of protective functions. If the function is not required Disabled is set. The function can be turned ON or OFF under address 5401 FCT 81 O/U.
By setting the parameters 5421 to 5424, the function of each of the elements 81-1 PICKUP to 81-4 PICKUP is set individually as overfrequency or underfrequency protection or set to OFF, if the element is not required.
Minimum Voltage
Address 5402 Vmin is used to set the minimum voltage. Frequency protection is blocked as soon as the minimum voltage is undershot.
The threshold value has to be set as phase-to-phase quantity if the connection is three-phase. With a single­phase phase-to-ground connection the threshold is set as phase voltage.
SIPROTEC 4, 7RW80, Manual 47 C53000-G1140-C233-4, Edition 07.2018
Functions
2.3 Frequency Protection 81 O/U
Pickup Values
The setting as overfrequency or underfrequency element does not depend on the parameter threshold values of the respective element. An element can also function, for example, as an overfrequency element if its threshold value is set below the nominal frequency and vice versa.
If frequency protection is used for load shedding purposes, the setting values depend on the actual power system conditions. Normally, a time coordinated load shedding is required that takes into account the impor­tance of the consumers or consumer groups.
Further application examples exist in the field of power stations. Here too, the frequency values to be set mainly depend on the specifications of the power system / power station operator. The underfrequency protection safeguards the power station's own demand by disconnecting it from the power system on time. The turbo governor regulates the machine set to the nominal speed. Consequently, the station's own demands can be continuously supplied at nominal frequency.
Under the assumption that the apparent power is reduced by the same degree, turbine-driven generators can, as a rule, be continuously operated down to 95% of the nominal frequency. However, for inductive consumers, the frequency reduction not only means an increased current input, but also endangers stable operation. For this reason, only a short-term frequency reduction down to about 48 Hz (for fN = 50 Hz) or 58 Hz (for fN = 60 Hz) is permissible.
A frequency increase can, for example, occur due to a load shedding or malfunction of the speed regulation (e.g. in an island network). In this way, the frequency increase protection can, for example, be used as over­speed protection.
Dropout Thresholds
The dropout threshold is defined via the adjustable dropout-difference address 5415 DO differential. It can thus be adjusted to the network conditions. The dropout difference is the absolute-value difference between pickup threshold and dropout threshold. The default value of 0.02 Hz can usually remain. Should, however, frequent minor frequency fluctuations be expected, this value should be increased.
Time Delays
The delay times 81-1 DELAY to 81-4 DELAY (addresses 5405, 5408, 5411 and 5414) allow the frequency elements to be time coordinated, e.g. for load shedding equipment. The set times are additional delay times not including the operating times (measuring time, dropout time) of the protection function.
2.3.3
Addr.
5401 FCT 81 O/U OFF
5402 Vmin 10 .. 150 V 65 V Minimum required voltage for
5402 Vmin 20 .. 150 V 35 V Minimum required voltage for
5403 81-1 PICKUP 40.00 .. 60.00 Hz 49.50 Hz 81-1 Pickup 5404 81-1 PICKUP 50.00 .. 70.00 Hz 59.50 Hz 81-1 Pickup 5405 81-1 DELAY 0.00 .. 100.00 sec 60.00 sec 81-1 Time Delay 5406 81-2 PICKUP 40.00 .. 60.00 Hz 49.00 Hz 81-2 Pickup 5407 81-2 PICKUP 50.00 .. 70.00 Hz 59.00 Hz 81-2 Pickup 5408 81-2 DELAY 0.00 .. 100.00 sec 30.00 sec 81-2 Time Delay 5409 81-3 PICKUP 40.00 .. 60.00 Hz 47.50 Hz 81-3 Pickup 5410 81-3 PICKUP 50.00 .. 70.00 Hz 57.50 Hz 81-3 Pickup 5411 81-3 DELAY 0.00 .. 100.00 sec 3.00 sec 81-3 Time delay

Settings

Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Parameter Setting Options Default Setting Comments
OFF 81 Over/Under Frequency Protec-
ON
tion
operation
operation
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2.3 Frequency Protection 81 O/U
Addr. Parameter Setting Options Default Setting Comments
5412 81-4 PICKUP 40.00 .. 60.00 Hz 51.00 Hz 81-4 Pickup 5413 81-4 PICKUP 50.00 .. 70.00 Hz 61.00 Hz 81-4 Pickup 5414 81-4 DELAY 0.00 .. 100.00 sec 30.00 sec 81-4 Time delay 5415A DO differential 0.02 .. 1.00 Hz 0.02 Hz Dropout differential 5421 FCT 81-1 O/U OFF
ON f> ON f<
5422 FCT 81-2 O/U OFF
ON f> ON f<
5423 FCT 81-3 O/U OFF
ON f> ON f<
5424 FCT 81-4 O/U OFF
ON f> ON f<
OFF 81-1 Over/Under Frequency
Protection
OFF 81-2 Over/Under Frequency
Protection
OFF 81-3 Over/Under Frequency
Protection
OFF 81-4 Over/Under Frequency
Protection
Functions
2.3.4
No. Information Type of
5203 >BLOCK 81O/U SP >BLOCK 81O/U 5206 >BLOCK 81-1 SP >BLOCK 81-1 5207 >BLOCK 81-2 SP >BLOCK 81-2 5208 >BLOCK 81-3 SP >BLOCK 81-3 5209 >BLOCK 81-4 SP >BLOCK 81-4 5211 81 OFF OUT 81 OFF 5212 81 BLOCKED OUT 81 BLOCKED 5213 81 ACTIVE OUT 81 ACTIVE 5214 81 Under V Blk OUT 81 Under Voltage Block 5232 81-1 picked up OUT 81-1 picked up 5233 81-2 picked up OUT 81-2 picked up 5234 81-3 picked up OUT 81-3 picked up 5235 81-4 picked up OUT 81-4 picked up 5236 81-1 TRIP OUT 81-1 TRIP 5237 81-2 TRIP OUT 81-2 TRIP 5238 81-3 TRIP OUT 81-3 TRIP 5239 81-4 TRIP OUT 81-4 TRIP

Information List

Comments Informa­tion
SIPROTEC 4, 7RW80, Manual 49 C53000-G1140-C233-4, Edition 07.2018
Functions

2.4 Load Restoration

2.4
2.4.1
General
Load Restoration
The Load Restoration has the task to reconnect elements of the system automatically, which have been disconnected due to overload. Overload causes the network frequency to drop, which is detected by the underfrequency protection and leads to separation of system components.

Functional Description

The load restoration function has 4 independently adjustable load restoration elements. Elements of the load restoration are switched on or off separately by parameters. Every element can be assigned up to 4 underfre­quency elements, which start the load restoration when tripped.
The process can be canceled via the binary input The binary input The binary input Started elements are processed in descending order. The highest number element connects first. You may find
an example in the instructions manual. The Load Restoration can be applied across several 7RW80 devices. The Load Restoration across several
devices can be coordinated using the CFC. The procedure is described in the instructions manual. The following figure gives an overview of the load restoration's functionality.
>LR Break >LR Reset
breaks the load restoration process. resets external blocking or a blocked monitoring.
>LR Block
.
[7rw80-uebersicht-20100525, 1, en_US]
Figure 2-6
50 SIPROTEC 4, 7RW80, Manual
Load Restoration - Overview
C53000-G1140-C233-4, Edition 07.2018
Procedure
Functions
2.4 Load Restoration
The start of a load restoration element is triggered by the tripping of the associated underfrequency element. Processing will terminate, if the restoration signal for the circuit breaker is issued or the function has been blocked. If the underfrequency trips again during the output of the restoration signal, the load restoration element will restart.
The following figure shows the interaction of underfrequency protection and load restoration.
[7rw80-start-20100525, 1, en_US]
Figure 2-7
Load Restoration - Start
You can adjust the trip- and dropout time for every load restoration element. Furthermore, you can adjust the pickup- and dropout time as a difference to the starting frequency, which together form the threshold of the load restoration. The frequency must reach this threshold value of the set trip time, before the restoration signal for the circuit breaker is issued. If the frequency drops below the the set pickup threshold value during the set dropout time, the time for the pickup will be halted. If the frequency drops to a value below the dropout threshold value, pickup and dropout time will be reset. This takes into account that the frequency is not restored monotonously, but rather is subject to intermittent fluctuations.
The following figure shows the interaction of thresholds and timers.
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Functions
2.4 Load Restoration
[7rw80-prozess-20100525, 1, en_US]
Figure 2-8 Load Restoration - Sequence
Blocking and Monitoring
The load restoration can be blocked by:
Binary Input
Tripping of another protective function of the device, which is not set to “Alarm Only”.
An exception is the underfrequency protection. Tripping of a underfrequency element initiates the load restoration.
Inaccurate or invalid frequency measurements at undervoltage
The blocking condition can be reset by a binary input or disappearing device pickup. The number of restoration cycles is limited by a parameter. This prevents short-cyclical on- and off switching
of the underfrequency protection and load restoration at major frequency fluctuations. If the number of resto­ration cycles exceeds the configured value, the load restoration will be blocked. The restoration cycle is time monitored. The monitoring time of load restoration cycles is configurable.
Pending power system/network faults are kept open during the restoration cycle. The following figure shows the operation of the blocking and the monitoring parameters. The overvoltage
function is an example, the same applies to other protection functions except for underfrequency.
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Functions
2.4 Load Restoration
[7rw80-block-monitor-20100508, 1, en_US]
Figure 2-9
After the monitoring time of the restoration cycle has elapsed, the success of the load restoration will be eval­uated.
Success basically depends on the following criteria:
The load restoration is not blocked, e.g. by another protective function, binary input, undervoltage,
monitoring
The monitoring time of restoration cycles of every started load restoration elements has elapsed
The maximum number of configured cycles was not exceeded
All started load restoration elements are connected
To better illustrate the mode of operation, the following examples demonstrate different scenarios of the load restoration procedure.
SIPROTEC 4, 7RW80, Manual 53 C53000-G1140-C233-4, Edition 07.2018
Load Restoration - Blocking and Monitoring
Functions
2.4 Load Restoration
[7rw80-monitor-log-bsp-20100525, 1, en_US]
Load Restoration – Blocking and Monitoring, Example
2.4.2
Figure 2-10

Setting Notes

General
The load restoration is active, if Load Restore = Enabled has been set at address 155 during configuration. If the function is not required Disabled is set.
The various elements of the load restoration are configured ON or OFF at addresses 5520, 5540, 5560 and
5580.
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Pickup- and Dropout Values
At addresses 5521, 5541, 5561 and 5581 you configure the start frequency LZx Start for the elements. The start frequency must be adjusted to a value equal or higher than the tripping frequency of the underfrequency element.
At addresses 5523, 5543, 5563 and 5583 configure the pickup frequency LRx Pickup for the elements. The pickup frequency and the start frequency add up to the pickup threshold of the load restoration element.
At addresses 5524, 5544, 5564 and 5584 you configure the delay time LRx t pickup for the pickup of elements.
At addresses 5525, 5545, 5565 and 5585 you configure the dropout frequency LRx Dropout the elements. The dropout frequency and the start frequency add up to the dropout threshold of the load restoration element.
At addresses 5526, 5546, 5566 and 5586 you may configure the dropout time LRx t dropout for the elements.
At addresses 5527, 5547, 5567 and 5587 you may configure the close command duration of the circuit breaker LRx t CB Close.
The following example illustrates the interaction of the pickup- and dropout values of the load restoration elements and underfrequency elements.
The pickup threshold of the underfrequency elements 81-1, 81-2 and 81-3 are set to the following frequen­cies:
81-1 PICKUP 5403 = 49,5 Hz 81-2 PICKUP 5406 = 49 Hz 81-3 PICKUP 5409 = 47,5 Hz
Functions
2.4 Load Restoration
Table 2-3
Settings Example
Parameter LZ1 LZ2 LZ3
Start LR1 Start 5521 = 49,5 Hz LR2 Start 5541 = 49 Hz LR3 Start 5561 = 49 Hz Pickup LR1 Pickup 5523 = 0,25 Hz LR2 Pickup 5543 = 0,50 Hz LR3 Pickup 5563 = 0,50 Hz Dropout LR1 Dropout 5525 = 0 Hz LR2 Dropout 5545 = 0,25 Hz LR3 Dropout 5565 = 0,25 Hz Pickup Time LR1 t pickup 5524 = 14 s LR2 t pickup 5544 = 13 s LR3 t pickup 5564 = 7 s Dropout Time LR1 t dropout 5526 = 10 s LR2 t dropout 5546 = 10 s LR3 t dropout 5566 = 10 s CB Close time LR1 t CB Close 5527 = 1 s LR2 t CB Close 5547 = 1 s LR3 t CB Close 5567 = 1s Underfrequency
elements
LR1 after 81-1 5528 =
YES
LR1 after 81-2 5529 =
YES
LR1 after 81-3 5530 =
YES
LR1 after 81-4 5531 =
LR2 after 81-1 5548 = NO LR2 after 81-2 5549 =
YES
LR2 after 81-3 5550 =
YES
LR2 after 81-4 5551 =
YES
LR3 after 81-1 5568 = NO LR3 after 81-2 5569 =
YES
LR3 after 81-3 5570 =
YES
LR3 after 81-4 5571 =
YES
YES
SIPROTEC 4, 7RW80, Manual 55 C53000-G1140-C233-4, Edition 07.2018
Functions
2.4 Load Restoration
[7rw80-beispiel-20100525, 1, en_US]
Figure 2-11
Example for Load Restoration with 3 elements
In the above example the frequency initially drops below the pickup threshold of the underfrequency element 81-1. The element 81-1 trips.
Because of the configured settings (see Table 2-3) load restoration element LR1 is started with the tripping of 81-1. LR1 is at this point the only running/started element and is therefore processed immediately.
Afterwards the network frequency drops below the pickup threshold of the underfrequency element 81-2. Element 81-2 trips as well and initiates load restoration elements LR2 and LR3.
LR3 has at that point the highest number of all load restoration elements and is processed immediately. The processing of element LR1 is interrupted.
When the pickup frequency of 49.5 Hz is reached, load restoration element LR3 picks up. Once the frequency remains above the threshold during the pickup time of LR3, LR3 issues the CB Close command.
The pickup of the next restoration element LR2 will be processed immediately after the LR3 restoration CB Close signal.
During the pickup time of LR2 the network frequency drops briefly below the pickup threshold, but not below the dropout threshold of LR2. This stops the pickup of load restoration element LR2, but does not reset this procedure in the dropout delay time. When the frequency reaches the pickup threshold of LR2 (49.5 Hz) again, the pickup time of LR2 will be continued.
When pickup time has expired, the element LR2 initiates the load restoration.
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Subsequently the pickup of load restoration LR1 is processed. When the pickup frequency of LR1 (49.75 Hz) is
i
i
reached, LR1 picks up. LR1 initiates the restoration when pickup time has expired. When the monitoring time has expired (address 5501 LR t Monitor), the message 17335
Successful
Assignments to Frequency Elements
At addresses 5528 to 5531, 5548 to 5551, 5568 to 5571 and 5588 to 5591 you may assign the underfre­quency elements, which trigger the load restoration element (when tripping).
Monitoring
At address 5501 LR t Monitor you may configure the monitoring time of the load restoration cycles. At address 5502 LR Max. Cycles you may configure the maximum number of restoration cycles of the load
restoration.
Load restoration across several devices
The Load Restoration can be applied across several 7RW80 devices. The Load Restoration across several devices can be coordinated using the CFC.
To ensure the correct restoration sequence between several v devices you must connect the output 17338
Process
Furthermore you have to configure the user defined messages The output messages
opposite devices 17330 In the CFC the following logic is applied:
is displayed (not shown in the figure).
of the first restoring device with the input 17332
LZ TxBlock
>LR Block
and
LZ TxPause
and 17331
>LR Process
LZ TxBlock
are connected to the according binary inputs of the
>LR Break
.
of the other devices.
and
LZ TxPause
Functions
2.4 Load Restoration
LR
LR
.
[7rw80-lz-cfc-20100720, 1, en_US]
Figure 2-12 Load Restoration across several devices - CFC-Logic
NOTE
Use the fast CFC task level PLC1_BEARB.
2.4.3
Addr.
5501 LR t Monitor 1 .. 3600 sec 3600 sec Load restoration monitor time 5502 LR Max. Cycles 1 .. 10 2 Load restoration maximal no. of
5520 LR1 ON
5520 LR1 ON
5521 LR1 Start 40.00 .. 60.00 Hz 49.50 Hz Load restoration elem. 1 start
SIPROTEC 4, 7RW80, Manual 57 C53000-G1140-C233-4, Edition 07.2018

Settings

Parameter Setting Options Default Setting Comments
cycles
OFF Load restoration element 1
OFF
OFF Load restoration element 1
OFF
frequency
Functions
2.4 Load Restoration
Addr. Parameter Setting Options Default Setting Comments
5522 LR1 Start 50.00 .. 70.00 Hz 59.50 Hz Load restoration elem. 1 start
frequency 5523 LR1 Pickup 0.02 .. 2.00 Hz 0.04 Hz Load restoration element 1 Pickup 5524 LR1 t pickup 0 .. 10800 sec 600 sec Load restoration element 1 Pickup
time 5525 LR1 Dropout 0.00 .. 2.00 Hz 0.02 Hz Load restoration element 1
Dropout 5526 LR1 t dropout 0 .. 10800 sec 60 sec Load restoration element 1
Dropout time 5527 LR1 t CB Close 0.01 .. 32.00 sec 1.00 sec Load restoration element 1 CB
Close time 5528 LR1 after 81-1 YES
NO
5529 LR1 after 81-2 YES
NO
5530 LR1 after 81-3 YES
NO
5531 LR1 after 81-4 YES
NO
5540 LR2 ON
NO Load restoration element 1 after
81-1
NO Load restoration element 1 after
81-2
NO Load restoration element 1 after
81-3
NO Load restoration element 1 after
81-4
OFF Load restoration element 2
OFF
5540 LR2 ON
OFF Load restoration element 2
OFF
5541 LR2 Start 40.00 .. 60.00 Hz 49.00 Hz Load restoration elem. 2 start
frequency 5542 LR2 Start 50.00 .. 70.00 Hz 59.00 Hz Load restoration elem. 2 start
frequency 5543 LR2 Pickup 0.02 .. 2.00 Hz 0.04 Hz Load restoration element 2 Pickup 5544 LR2 t pickup 0 .. 10800 sec 600 sec Load restoration element 2 Pickup
time 5545 LR2 Dropout 0.00 .. 2.00 Hz 0.02 Hz Load restoration element 2
Dropout 5546 LR2 t dropout 0 .. 10800 sec 60 sec Load restoration element 2
Dropout time 5547 LR2 t CB Close 0.01 .. 32.00 sec 1.00 sec Load restoration element 2 CB
Close time 5548 LR2 after 81-1 YES
NO
5549 LR2 after 81-2 YES
NO
5550 LR2 after 81-3 YES
NO
5551 LR2 after 81-4 YES
NO
5560 LR3 ON
NO Load restoration element 2 after
81-1
NO Load restoration element 2 after
81-2
NO Load restoration element 2 after
81-3
NO Load restoration element 2 after
81-4
OFF Load restoration element 3
OFF
5560 LR3 ON
OFF Load restoration element 3
OFF
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Functions
2.4 Load Restoration
Addr. Parameter Setting Options Default Setting Comments
5561 LR3 Start 40.00 .. 60.00 Hz 47.50 Hz Load restoration elem. 3 start
frequency
5562 LR3 Start 50.00 .. 70.00 Hz 57.50 Hz Load restoration elem. 3 start
frequency 5563 LR3 Pickup 0.02 .. 2.00 Hz 0.04 Hz Load restoration element 3 Pickup 5564 LR3 t pickup 0 .. 10800 sec 600 sec Load restoration element 3 Pickup
time 5565 LR3 Dropout 0.00 .. 2.00 Hz 0.02 Hz Load restoration element 3
Dropout 5566 LR3 t dropout 0 .. 10800 sec 60 sec Load restoration element 3
Dropout time 5567 LR3 t CB Close 0.01 .. 32.00 sec 1.00 sec Load restoration element 3 CB
Close time 5568 LR3 after 81-1 YES
NO
5569 LR3 after 81-2 YES
NO
5570 LR3 after 81-3 YES
NO
5571 LR3 after 81-4 YES
NO
5580 LR4 ON
NO Load restoration element 3 after
81-1
NO Load restoration element 3 after
81-2
NO Load restoration element 3 after
81-3
NO Load restoration element 3 after
81-4
OFF Load restoration element 4
OFF
5580 LR4 ON
OFF Load restoration element 4
OFF
5581 LR4 Start 40.00 .. 60.00 Hz 47.50 Hz Load restoration elem. 4 start
frequency 5582 LR4 Start 50.00 .. 70.00 Hz 57.50 Hz Load restoration elem. 4 start
frequency 5583 LR4 Pickup 0.02 .. 2.00 Hz 0.04 Hz Load restoration element 4 Pickup 5584 LR4 t pickup 0 .. 10800 sec 600 sec Load restoration element 4 Pickup
time 5585 LR4 Dropout 0.00 .. 2.00 Hz 0.02 Hz Load restoration element 4
Dropout 5586 LR4 t dropout 0 .. 10800 sec 60 sec Load restoration element 4
Dropout time 5587 LR4 t CB Close 0.01 .. 32.00 sec 1.00 sec Load restoration element 4 CB
Close time 5588 LR4 after 81-1 YES
NO
5589 LR4 after 81-2 YES
NO
5590 LR4 after 81-3 YES
NO
5591 LR4 after 81-4 YES
NO
NO Load restoration element 4 after
81-1
NO Load restoration element 4 after
81-2
NO Load restoration element 4 after
81-3
NO Load restoration element 4 after
81-4
SIPROTEC 4, 7RW80, Manual 59 C53000-G1140-C233-4, Edition 07.2018
Functions
2.4 Load Restoration
2.4.4
No. Information Type of
17330 >LR Block SP >Load restoration Block 17331 >LR Break SP >Load restoration break 17332 >LR Process SP >Load restoration Process 17333 >LR Reset SP >Load restoration Reset 17334 LR OFF OUT Load restoration is OFF 17335 LR Successful OUT Load restoration successful 17336 LR Block OUT Load restoration Block 17337 LR Break OUT Load restoration break 17338 LR Process OUT Load restoration Process 17339 LR1 Start OUT Load restoration element 1 Start 17340 LR1 Pickup OUT Load restoration element 1 Pickup 17341 LR1 CB Close OUT Load restoration element 1 CB Close 17343 LR1 Active OUT Load restoration element 1 Active 17344 LR1 Set-Error OUT Load restoration element 1 Setting Error 17345 LR1 Monitor OUT Load restoration element 1 monitor mode 17346 LR2 Start OUT Load restoration element 2 Start 17347 LR2 Pickup OUT Load restoration element 2 Pickup 17348 LR2 CB Close OUT Load restoration element 2 CB Close 17350 LR2 Active OUT Load restoration element 2 Active 17351 LR2 Set-Error OUT Load restoration element 2 Setting Error 17352 LR2 Monitor OUT Load restoration element 2 monitor mode 17353 LR3 Start OUT Load restoration element 3 Start 17354 LR3 Pickup OUT Load restoration element 3 Pickup 17355 LR3 CB Close OUT Load restoration element 3 CB Close 17357 LR3 Active OUT Load restoration element 3 Active 17358 LR3 Set-Error OUT Load restoration element 3 Setting Error 17359 LR3 Monitor OUT Load restoration element 3 monitor mode 17360 LR4 Start OUT Load restoration element 4 Start 17361 LR4 Pickup OUT Load restoration element 4 Pickup 17362 LR4 CB Close OUT Load restoration element 4 CB Close 17364 LR4 Active OUT Load restoration element 4 Active 17365 LR4 Set-Error OUT Load restoration element 4 Setting Error 17366 LR4 Monitor OUT Load restoration element 4 monitor mode

Information List

Comments Informa­tion
60 SIPROTEC 4, 7RW80, Manual
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Functions

2.5 Supervision Functions

2.5
2.5.1
2.5.1.1
2.5.1.2
Auxiliary and Reference Voltages
Buffer Battery
Supervision Functions
The device is equipped with extensive monitoring capabilities - both for hardware and software. In addition, the measured values are also constantly monitored for plausibility, therefore, the voltage transformer circuits are largely integrated into the monitoring.

Measurement Supervision

General
The device monitoring extends from the measuring inputs to the binary outputs. Monitoring checks the hard­ware for malfunctions and abnormal conditions.
Hardware and software monitoring described in the following are enabled continuously. Settings (including the possibility to activate and deactivate the monitoring function) refer to the monitoring of external trans­former circuits.
Hardware Monitoring
Failure of or switching off the supply voltage removes the device from operation and a message is immedi­ately generated by a normally closed contact. Brief auxiliary voltage interruptions of less than 50 ms do not disturb the readiness of the device (for nominal auxiliary voltage > 110 VDC).
The buffer battery, which ensures operation of the internal clock and storage of counters and messages if the auxiliary voltage fails, is periodically checked for charge status. If it is less than an allowed minimum voltage, then the
Memory Components
All working memories (RAMs) are checked during startup. If a malfunction occurs then, the starting sequence is interrupted and an LED blinks. During operation the memories are checked with the help of their checksum. For the program memory, the cross sum is formed cyclically and compared to the stored program cross sum.
For the settings memory, the cross sum is formed cyclically and compared to the cross sum that is freshly generated each time a setting process takes place.
If a fault occurs the processor system is restarted.
Scanning
Scanning and the synchronization between the internal buffer components are constantly monitored. If any deviations cannot be removed by renewed synchronization, then the processor system is restarted.
AD Transformer Monitoring
The digitized sampled values are being monitored in respect of their plausibility. If the result is not plausible, message 181 Furthermore, a fault record is generated for recording of the internal fault.
2.5.1.3
Watchdog
Software Monitoring
Fail Battery
Error A/D-conv.
message is issued.
is issued. The protection is blocked, thus preventing unwanted operation.
For continuous monitoring of the program sequences, a time monitor is provided in the hardware (hardware watchdog) that expires upon failure of the processor or an internal program, and causes a complete restart of the processor system.
An additional software watchdog ensures that malfunctions during the processing of programs are discov­ered. This also initiates a restart of the processor system.
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Functions
2.5 Supervision Functions
If such a malfunction is not cleared by the restart, an additional restart attempt is begun. After three unsuc­cessful restarts within a 30 second window of time, the device automatically removes itself from service and the red “Error” LED lights up. The readiness relay drops out and indicates „device malfunction“ with its normally closed contact.
Offset Monitoring
This monitoring function checks all ring buffer data channels for corrupt offset replication of the analog/digital transformers and the analog input paths using offset filters. Possible offset errors are detected using DC filters, and the associated sampled values are corrected up to a specific limit. If this limit is exceeded, an indication is generated (191 values impair the measurements, we recommend sending the device to the OEM plant for corrective action should this indication persist.
The Offset monitoring can be blocked via the binary input signal
Error Offset
) and integrated into the warning group indication (160). As increased offset
>Blk.offset s.
(No. 17565).
2.5.1.4
Monitoring of the Transformer Circuits
Open circuits or short circuits in the secondary circuits of the voltage transformers, as well as faults in the connections (important during commissioning!), 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.
Voltage Symmetry
During normal system operation, balance among the voltages is expected. Since the phase-to-phase voltages are insensitive to ground faults, the phase-to-phase voltages are used for balance monitoring. If the device is connected to the phase-to-ground voltages, then the phase-to-phase voltages are calculated accordingly, whereas, if the device is connected to phase-to-phase voltages and the displacement voltage V0, then the third
phase-to-phase voltage is calculated accordingly. From the phase-to-phase voltages, the device generates the rectified average values and checks the balance of their absolute values. The smallest phase voltage is compared with the largest phase voltage.
Asymmetry is recognized if | V
| / | V
min
three voltages and V allowable asymmetry of the conductor voltages while the limit value BALANCE V-LIMIT (address 8102) is
the lower limit of the operating range of this monitoring (see Figure 2-70). Both parameters can be set. The dropout ratio is about 97%.
This fault is signalled after settable delay time with
| < BAL. FACTOR V as long as | V
max
the smallest. The symmetry factor BAL. FACTOR V (address 8103) represents the
min
| > BALANCE V-LIMIT. Where V
max
Fail V balance
.
is the highest of the
max
[dw_spannungssymmetrieueberwachung, 1, en_US]
Figure 2-13 Voltage symmetry monitoring
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Phase sequence of the voltages
To detect swapped phase connections in the voltage input circuits, the direction of rotation of the phase­tophase voltages is checked. Therefore the sequence of the zero crossings of the currents (having the same sign) is checked.
Phase rotation of measurement quantities is checked by verifying the phase sequences. Here, the phase sequence supervision requires the phase-phase voltages VA2, VB3, VC1.
Voltages:
VA2 before VB3 before V
Verification of the voltage phase rotation is done when each measured voltage is at least |VA2|, |VB3|, |VC1| > 40 V.
For abnormal phase sequences, the messages this message
Fail Ph. Seq.
For applications in which an opposite phase sequence is expected, the protective relay should be adjusted via a binary input or a programmable setting PHASE SEQ. (Addresse 209). If the phase sequence is changed in the device, phases B and C internal to the relay are reversed, and the positive and negative sequence currents are thereby exchanged (see also Section 2.10.2 Setting Notes). The phase-related messages, malfunction values, and measured values are not affected by this.
Functions
2.5 Supervision Functions
C1
Fail Ph. Seq. V
or are issued, along with the switching of
.
2.5.1.5
Broken Wire Monitoring of Voltage Transformer Circuits
Requirements
The measurement of all three phase-to-ground voltages is a requirement for the functionality. If only two phaseto- phase voltages were measured, it would not be possible to evaluate two of the required criteria.
Task
The “Broken Wire” monitoring function monitors the voltage transformer circuits of the secondary system with regard to failure. One distinguishes between
Mode of Operation / Logic
All three phase-to-ground voltages, the displacement voltage and the displacement voltage are measured. The required values are calculated for the respective criteria and eventually a decision is made. The resulting alarm message may be delayed. A blocking of the protection functions is however not effected.
The broken wire monitoring is also active during a fault. The function may be enabled or disabled. The following logic diagram shows how the broken wire monitoring functions.
single-phase and two-phase failures.
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Functions
2.5 Supervision Functions
[7rw80-broken-wire-20100716, 1, en_US]
Logic diagram of the “Broken-wire” Monitoring
2.5.1.6
Figure 2-14
Setting Notes
Measured Value Monitoring
The sensitivity of the measured value monitor can be modified. Default values are set at the factory, which are sufficient in most cases. If especially high operating asymmetry in the voltages is to be expected for the appli­cation, or if it becomes apparent during operation that certain monitoring functions activate sporadically, then the setting should be less sensitive.
Address 8102 BALANCE V-LIMIT determines the limit voltage (phase-to-phase) above which the voltage symmetry monitor is effective. Address 8103 BAL. FACTOR V is the associated symmetry factor; that is, the slope of the symmetry characteristic curve. In address 5208 T DELAY ALARM you set the delay time of fault message no. 167
Fail V balance
.
Measured value monitoring can be set to ON or OFF at address 8101 MEASURE. SUPERV.
2.5.1.7
Addr.
5201 VT BROKEN WIRE ON
Settings
Parameter Setting Options Default Setting Comments
OFF VT broken wire supervision
OFF 5202 Σ V> 1.0 .. 100.0 V 8.0 V Threshold voltage sum 5203 Vph-ph max< 1.0 .. 100.0 V 16.0 V Maximum phase to phase voltage 5204 Vph-ph min< 1.0 .. 100.0 V 16.0 V Minimum phase to phase voltage 5205 Vph-ph max-min> 10.0 .. 200.0 V 16.0 V Symmetry phase to phase voltages
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Addr. Parameter Setting Options Default Setting Comments
5208 T DELAY ALARM 0.00 .. 32.00 sec 1.25 sec Alarm delay time 8101 MEASURE. SUPERV OFF
ON
8102 BALANCE V-LIMIT 10 .. 100 V 50 V Voltage Threshold for Balance
8103 BAL. FACTOR V 0.58 .. 0.90 0.75 Balance Factor for Voltage
ON Measurement Supervision
Monitoring
Monitor
2.5.1.8
No. Information Type of
167 Fail V balance OUT Failure: Voltage Balance 171 Fail Ph. Seq. OUT Failure: Phase Sequence 176 Fail Ph. Seq. V OUT Failure: Phase Sequence Voltage 197 MeasSup OFF OUT Measurement Supervision is switched OFF 253 VT brk. wire OUT Failure VT circuit: broken wire 255 Fail VT circuit OUT Failure VT circuit 256 VT b.w. 1 pole OUT Failure VT circuit: 1 pole broken wire 257 VT b.w. 2 pole OUT Failure VT circuit: 2 pole broken wire 6509 >FAIL:FEEDER VT SP >Failure: Feeder VT 6510 >FAIL: BUS VT SP >Failure: Busbar VT
2.5.2
Information List
Comments Informa­tion

Trip Circuit Supervision 74TC

Devices 7RW80 are equipped with an integrated trip circuit supervision. Depending on the number of available binary inputs (not connected to a common potential), supervision with one or two binary inputs can be selected. If the allocation of the required binary inputs does not match the selected supervision type, then a message to this effect is generated (
74TC ProgFail
).
Applications
When using two binary inputs, malfunctions in the trip circuit can be detected under all circuit breaker
conditions.
When only one binary input is used, malfunctions in the circuit breaker itself cannot be detected.
Prerequisites
A requirement for the use of trip circuit supervision is that the control voltage for the circuit breaker is at least twice the voltage drop across the binary input (Vct > 2 · V
Since at least 19 V are needed for the binary input, the supervision can only be used with a system control voltage of over 38 V.
2.5.2.1
Supervision with Two Binary Inputs
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Functional Description
When using two binary inputs, these are connected according to Figure 2-15, parallel to the associated trip contact on one side, and parallel to the circuit breaker auxiliary contacts on the other.
BImin
).
Functions
2.5 Supervision Functions
[dw_prinzip-ausloesekreisueberwachung-2-binein, 1, en_US]
Figure 2-15
Principle of the trip circuit supervision with two binary inputs
Supervision with two binary inputs not only detects interruptions in the trip circuit and loss of control voltage, it also supervises the response of the circuit breaker using the position of the circuit breaker auxiliary contacts.
Depending on the conditions of the trip contact and the circuit breaker, the binary inputs are activated (logical condition "H" in Table 2-4), or not activated (logical condition "L").
In healthy trip circuits the condition that both binary inputs are not actuated (”L") is only possible during a short transition period (trip contact is closed but the circuit breaker has not yet opened). A continuous state of this condition is only possible when the trip circuit has been interrupted, a short-circuit exists in the trip circuit, a loss of battery voltage occurs, or malfunctions occur with the circuit breaker mechanism. Therefore, it is used as supervision criterion.
Table 2-4
Condition table for binary inputs, depending on RTC and CB position
No. Trip contact Circuit breaker 52a Contact 52b Contact BI 1 BI 2
1 Open Closed Closed Open H L 2 Open Open Open Closed H H 3 Closed Closed Closed Open L L 4 Closed Open Open Closed L H
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 (after 1.8 s), an annunciation is reported (see
Figure 2-16). The repeated measurements determine the delay of the alarm message and avoid that an alarm
is output during short transition periods. After the malfunction in the trip circuit is cleared, the fault annuncia­tion is reset automatically after the same time period.
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[dw_7sj6x_ausloesekreis_2_binaerein, 1, en_US]
Figure 2-16 Logic diagram of the trip circuit supervision with two binary inputs
Supervision with One Binary Input
The binary input is connected according to the following figure in parallel with the associated trip contact of the protection relay. The circuit breaker auxiliary contact is bridged with a bypass resistor R.
Functions
2.5 Supervision Functions
[dw_prinzip-ausloesekreisueberwachung-1-binein, 1, en_US]
Figure 2-17
Trip circuit supervision with one binary input
During normal operation, the binary input is activated (logical condition "H") when the trip contact is open and the trip circuit is intact, because the monitoring circuit is closed by either the 52a circuit breaker auxiliary contact (if the circuit breaker is closed) or through the bypass resistor R by the 52b circuit breaker auxiliary contact. Only as long as the trip contact is closed, the binary input is short circuited and thereby deactivated (logical condition "L").
If the binary input is continuously deactivated during operation, this leads to the conclusion that there is an interruption in the trip circuit or loss of control voltage.
As the trip circuit supervision does not operate during system faults, the closed trip contact does not lead to a fault message. If, however, tripping contacts from other devices operate in parallel with the trip circuit, then the fault message must be delayed (see also Figure 2-18). The delay time can be set via parameter 8202 Alarm Delay. A message is only released after expiry of this time. After clearance of the fault in the trip circuit, the fault message is automatically reset.
[dw_7sj6x_ausloesekreis_1_binaerein, 1, en_US]
Figure 2-18 Logic diagram of trip circuit supervision with one binary input
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Functions
2.5 Supervision Functions
The following figure shows the logic diagram for the message that can be generated by the trip circuit monitor, depending on the control settings and binary inputs.
[dw_7sj6x_ausloesekreis_meldelogik, 1, en_US]
Figure 2-19 Message logic for trip circuit supervision
2.5.2.2
Setting Notes
General
The function is only effective and accessible if address 182 (Section 2.1.1.2 Setting Notes) was set to either 2 Binary Inputs or 1 Binary Input during configuration, the appropriate number of binary inputs has
been configured accordingly for this purpose and the function FCT 74TC is ON at address 8201. If the alloca­tion of the required binary inputs does not match the selected supervision type, a message to this effect is generated (
74TC ProgFail
address 182. In order to ensure that the longest possible duration of a trip command can be reliably bridged, and an indica-
tion is generated in case of an actual fault in the trip circuit, the indication regarding a trip circuit interruption is delayed. The time delay is set under address 8202 Alarm Delay.
Supervision with One Binary Input
Note: When using only one binary input (BI) for the trip circuit monitor, malfunctions, such as interruption of the trip circuit or loss of battery voltage are detected in general, but trip circuit failures while a trip command is active cannot be detected. Therefore, the measurement must take place over a period of time that bridges the longest possible duration of a closed trip contact. This is ensured by the fixed number of measurement repetitions and the time between the state checks.
When using only one binary input, a resistor R is inserted into the circuit on the system side, instead of the missing second binary input. Through appropriate sizing of the resistor and depending on the system condi­tions, a lower control voltage is mostly sufficient.
Information for dimensioning resistor R is given in the Chapter "Installation and Commissioning" under Config­uration Notes in the Section "Trip Circuit Supervision".
). If the trip circuit monitor is not to be used at all, then Disabled is set at
2.5.2.3
Addr.
8201 FCT 74TC ON
Settings
Parameter Setting Options Default Setting Comments
ON 74TC TRIP Circuit Supervision
OFF
8202 Alarm Delay 1 .. 30 sec 2 sec Delay Time for alarm
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Functions
2.5 Supervision Functions
2.5.2.4
No. Information Type of
Information List
Comments Informa­tion
6851 >BLOCK 74TC SP >BLOCK 74TC 6852 >74TC trip rel. SP >74TC Trip circuit superv.: trip relay 6853 >74TC brk rel. SP >74TC Trip circuit superv.: bkr relay 6861 74TC OFF OUT 74TC Trip circuit supervision OFF 6862 74TC BLOCKED OUT 74TC Trip circuit supervision is BLOCKED 6863 74TC ACTIVE OUT 74TC Trip circuit supervision is ACTIVE 6864 74TC ProgFail OUT 74TC blocked. Bin. input is not set 6865 74TC Trip cir. OUT 74TC Failure Trip Circuit
2.5.3

Malfunction Responses of the Monitoring Functions

Im folgenden sind die Fehlerreaktionen der Überwachungseinrichtungen zusammengefasst.
2.5.3.1
Functional Description
Malfunction Responses
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 unsuccessful restart attempts, the device is taken out of service. The operational readiness NC contact operates to indicate the device is malfunctioning. Also, the red LED ”ERROR" lights up on the front cover, if the internal auxiliary voltage is present, and the green ”RUN" LED goes out. If the internal auxiliary voltage fails, all LEDs are dark. Table 2-5 provides a summary of the monitoring functions and the malfunction responses of the relay.
Table 2-5
Monitoring Possible Causes Malfunction
Summary of malfunction responses by the protection relay
Message (No.) Output
Response
AC/DC supply voltage loss External
Device shutdown All LEDs dark
(Nominal voltage) internal (power supply)
Buffer battery Internal (buffer
Message
Fail Battery
battery)
Hardware watchdog Internal
Device shutdown
1)
LED "ERROR"
(processor failure)
Software watchdog Internal
Restart attempt
1)
LED "ERROR"
(processor failure)
Working memory ROM Internal (hardware) Relay aborts restart,
LED blinkt
device shutdown
Program memory RAM Internal (hardware) During boot sequence LED "ERROR"
Detection during oper-
LED "ERROR"
ation:
1)
1)
LED "ERROR"
Settings memory Internal (hardware)
Restart attempt Restart attempt
Sampling frequency Internal (hardware) Device shutdown LED "ERROR"
DOK2) drops out
(177)
DOK2) drops out
DOK2) drops out
DOK2) drops out
DOK2) drops out
DOK2) drops out
DOK2) drops out
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Functions
2.5 Supervision Functions
Monitoring Possible Causes Malfunction
Response
Error in the I/O-board Internal (hardware) Device shutdown
Offset monitoring Internal (hardware) Device shutdown
Voltage symmetry External (power
Message system or voltage transformer)
Voltage phase sequence External (power
Message system or connec­tion)
Trip circuit monitoring External (trip circuit
Message or control voltage)
Secondary voltage transformer circuit monitoring
External (voltage transformer circuit
Message
interruption)
Calibration data fault Internal (hardware) Message
1)
After three unsuccessful restart attempts, the device is shut down.
2)
DOK = "Device Okay" = Ready for service relay drops off, protection and control functions are blocked.
Message (No.) Output
I/O-Board error
(178),
DOK2) drops out
LED "ERROR"
Error Offset
(191)
DOK2) drops out
Fail V balance
As allocated
(167)
Fail Ph. Seq. V
As allocated
176)
74TC Trip cir.
As allocated
(6865)
VT brk. wire
(253)
Alarm NO calibr
As allocated
As allocated
(193)
Group Alarms
Certain messages of the monitoring functions are already combined to group alarms. A listing of the group alarms and their composition is given in the Appendix E.4 Group Indications. In this case, it must be noted that message 160 MEASURE. SUPERV) are activated.
Alarm Sum Event
is only issued when the measured value monitoring functions (8101
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Functions

2.6 Flexible Protection Functions

2.6
2.6.1
General
Characteristic Group
Voltage V RMS value of fundamental
Frequency f Frequency Frequency protection 81U/O without phase
Binary input Binary input Direct coupling without phase
Flexible Protection Functions
The flexible protection function is applicable for a variety of protection principles. The user can create up to 20 flexible protection functions and configure them according to their function. Each function can be used either as an autonomous protection function, as an additional protective element of an existing protection function or as a universal logic, e.g. for monitoring tasks.

Functional Description

The function is a combination of a standard protection logic and a characteristic (measured quantity or derived quantity) that is adjustable via parameters. The characteristics listed in table 2-20 and the derived protection functions are available.
Table 2-6 Realisierbare Schutzfunktionen
Characteristic / Measured Quantity Protective Function ANSI-No. Mode of Operation
3–phase 1–phase
Voltage protection
component
V
3V
V
V
dV/dt Voltage change Voltage change protection X
df/dt Frequency change Frequency change protec-
True RMS (r.m.s. value) Voltage protection
rms
Zero sequence system Displacement voltage 59N X
0
Positive-sequence component Voltage protection 27, 59 X
1
Negative-sequence component Voltage asymmetry 47 X
2
Displacement voltage
Displacement voltage
tion
27, 59, 59G
27, 59, 59G
81R
X X
X X
reference
reference
The maximum 20 configurable protection functions operate independently of each other. The following description concerns one function; it can be applied accordingly to all other flexible functions. The logic diagram Figure 2-20 illustrates the description.
Functional Logic
The function can be switched OFF and ON or, it can be set to Alarm Only. In this status, a pickup condition will neither initiate fault recording nor start the trip time delay. Tripping is thus not possible.
Changing the Power System Data 1 after flexible functions have been configured may cause these functions to be set incorrectly. Message (FNo.235.2128 in this case and function's setting has to be modified.
Blocking Functions
The function can be blocked via binary input (FNo. 235.2110 (“Control”->“Tagging”->“Set”). Blocking will reset the function's entire measurement logic as well as all running times and indications. Blocking via the local operating terminal may be useful if the function is in a status of permanent pickup which does not allow the function to be reset.
In context with voltage-based characteristics, the function can be blocked if one of the measuring voltages fails. Recognition of this status is via auxiliary contacts of the voltage transformer CB (FNo. 6509
>FAIL:FEEDER VT
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and FNo. 6510
$00 inval.set
>FAIL: BUS VT
) reports this condition. The function is inactive
>BLOCK $00
). This blocking mechanism can be enabled or disabled
) or via local operating terminal
Functions
2.6 Flexible Protection Functions
in the according parameters. The associated parameter BLK.by Vol.Loss is only available if the character­istic is based on a voltage measurement.
When using the flexible function for power protection or power monitoring, it will be blocked if currents fall below 0.03 · Ι
Nom
.
Operating Mode, Measured Quantity, Measurement Method
The flexible function can be tailored to assume a specific protective function for a concrete application in parameters OPERRAT. MODE, MEAS. QUANTITY, MEAS. METHOD and PICKUP WITH. Parameter
OPERRAT. MODE can be set to specify whether the function works 3-phase, 1-phase oder no refer- ence, i.e. without a fixed phase reference. The three-phase method evaluates all three phases in parallel. This
implies that threshold evaluation, pickup indications and trip time delay are accomplished selectively for each phase and parallel to each other.
When operating single-phase, the function employs a phase's measured quantity, which must be stated explic­itly.
If the characteristic relates to the frequency or if external trip commands are used, the operating principle is without (fixed) phase reference. Additional parameters can be set to specify the used MEAS. QUANTITY and the MEAS. METHOD. The MEAS. METHOD determines for voltage measured values whether the function uses the RMS value of the fundamental component or the normal RMS value (true RMS) that evaluates also harmonics. All other characteristics use always the rms value of the fundamental component. Parameter PICKUP WITH moreover specifies whether the function picks up on exceeding the threshold (>-element) or on falling below the threshold (<-element).
Characteristic Curve
The function's characteristic curve is always “definite time”; this means that the time delay is not affected by the measured quantity.
Function Logic
The following figure shows the logic diagram of a three-phase function. If the function operates on one phase or without phase reference, phase selectivity and phase-specific indications are not relevant.
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2.6 Flexible Protection Functions
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Figure 2-20
Logic diagram of the flexible protection functions
The parameters can be set to monitor either exceeding or dropping below of the threshold. The configurable pickup time delay will be started once the threshold (>-element) has been exceeded. When the time delay has elapsed and the threshold is still violated, the pickup of the phase (e.g. no. 235.2122 the function (no. 235.2121
$00 picked up
) is reported. If the pickup delay is set to zero, the pickup will
$00 pickup A
)and of
occur simultaneously with the detection of the threshold violation. If the function is enabled, the pickup will start the trip time delay and the fault log. This is not the case if set to "Alarm only". If the threshold violation persists after the trip time delay has elapsed, the trip will be initiated upon its expiration (no. 235.2126
TRIP
). The timeout is reported via (no. 235.2125
blocked via binary input (no. 235.2113
>$00 BLK.TDly
$00 Time Out
). Expiry of the trip time delay can be
). The time delay will not be started as long as the
$00
binary input is active; a trip can thus be initiated. The time delay is started after the binary input has dropped out and the pickup is still present. It is also possible to bypass the expiration of the time delay by activating binary input (no. 235.2111
SIPROTEC 4, 7RW80, Manual 73 C53000-G1140-C233-4, Edition 07.2018
>$00 instant.
). The trip will be launched immediately when the pickup is
Functions
2.6 Flexible Protection Functions
present and the binary input has been activated. The trip command can be blocked via binary inputs (no.
235.2115 command is required for interaction with the inrush restraint (see “Interaction with other functions”). The function's dropout ratio can be set. If the threshold (>-element) is undershot after the pickup, the dropout time delay will be started. The pickup is maintained during that time, a started trip delay time continues to count down. If the trip time delay has elapsed while the dropout time delay is still during, the trip command will only be given if the current threshold is exceeded. The element will only drop out when the dropout time delay has elapsed. If the time is set to zero, the dropout will be initiated immediately once the threshold is undershot.
External Trip Commands
The logic diagram does not explicitly depict the external trip commands since their functionality is analogous. If the binary input is activated for external trip commands (no. 235.2112 treated as threshold overshooting, i.e. once it has been activated, the pickup time delay is started. If the pickup time delay is set to zero, the pickup condition will be reported immediately starting the trip time delay. Otherwise, the logic is the same as depicted in Figure 2-20.
Interaction with Other Functions
The pickup message of the flexible function is included in the general fault detection, and tripping in the general trip (see Chapter 2.11 Function Logic). All functionalities linked to the general fault detection and general trip therefore also apply to the flexible function.
The trip commands by the flexible protection function are maintained after reset of the pickup for at least the configured minimum trip-command duration 210 TMin TRIP CMD.
>$00 BL.TripA
) and (no. 235.2114
>$00 BLK.TRIP
). The phase-selective blocking of the trip
>$00 Dir.TRIP
), it will be logically
2.6.2
General
Measured Quantity

Setting Notes

The setting of the functional scope determines the number of flexible protection functions to be used (see Section 2.1.1 Functional Scope). If a flexible function in the functional scope is disabled (by removing the checkmark), this will result in losing all settings and configurations of this function or its settings will be reset to their default settings.
In the DIGSI setting dialog “General”, parameter FLEXIBLE FUNC. can be set to OFF, ON or Alarm Only. If the function is enabled in operational mode Alarm Only, no faults are recorded, no “Effective”indication is generated, no trip command issued and neither will the circuit-breaker protection be affected. Therefore, this operational mode is preferred when a flexible function is not required to operate as a protection function. Furthermore, the OPERRAT. MODE can be configured:
3-phase – functions evaluate the three-phase measuring system, i.e. all three phases are processed simultane­ously.
1-phase functions evaluate only the individual measured value. This can be an individual phase value (e.g VB) or Vx or a ground variable (VN).
Setting no reference determines the evaluation of measured variables irrespective of a single or threep­hase connection of voltage. Table 2-6 provides an overview regarding which variables can be used in which mode of operation.
In the setting dialog “Measured Variable” the measured variables to be evaluated by the flexible protection functions can be selected, which may be a calculated or a directly measured variable. The setting options that can be selected here are dependant on the mode of measured-value processing as predefined in parameter OPERRAT. MODE (see the following table).
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Table 2-7 Parameter OPERRAT. MODE and MEAS. QUANTITY
Functions
2.6 Flexible Protection Functions
Parameter OPERRAT. MODE Setting 1-phase 3-phase 3-phase
Without Reference
Measurement Process
The following table lists configurable measurement procedures depending on parameterized measured quan­tities.
Table 2-8 Parameter in the Setting Dialog "Measurement Procedure", Mode of Operation 3-phase
Parameter OPERRAT. MODE = 3-phase
Parameter MEAS. QUANTITY = Voltage Parameter MEAS. METHOD
Fundamental
Only the fundamental harmonic is evaluated, higher harmonics are suppressed. This is the standard measurement procedure of the protection functions.
Important: The voltage threshold value is always parameterized as phase-to-phase voltage. If parameter VOLTAGE SYSTEM is selected as phase-to-ground, the voltage threshold will be devided by √3.
True RMS
The "true" RMS value is determined, i.e. higher harmonics are evaluated. Important: The voltage threshold value is always parameterized as phase-to-phase
voltage. If parameter VOLTAGE SYSTEM is selected as phase-to-ground, the voltage threshold will be devided by √3.
Positive seq., Negative seq.,
Zero sequence
In order to realize certain applications, the positive sequence system or negative sequence system can be configured as measurement procedure for example U2 (voltage asymmetry)
Via the selection zero sequence system, additional zero sequence voltage functions can be realized that operate independent of the ground variable VN, which are measured
directly via transformers. Important: The voltage threshold is always parameterized according to the definition of
the balanced components independently of parameter VOLTAGE SYSTEM. Parameter MEAS. QUANTITY = Voltage Parameter VOLTAGE
SYSTEM
Phase-Phase
Phase-Ground
If you have configured address 213 VT Connect. 3ph to Van, Vbn, Vcn or Vab,
Vbc, VGnd, you can select whether a 3- phase voltage function will evaluate the phase-
to-ground voltage or the phase-to-phase voltages.
When selecting phase-to-phase, these variables are derived from the phase-to-ground
voltages. The selection is, for example, important for single-pole faults. If the faulty
voltage drops to zero, the affected phase-to-ground voltage is zero, whereas the affected
phase-to-phase voltages collapse to the size of a phase-to-ground voltage.
With phase-to-phase voltage connections the parameter is hidden.
Parameter MEAS. QUANTITY Setting Options
Voltage
dV/dt rising
dV/dt falling
Frequency
df/dt rising
df/dt falling
Binray Input
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i
i
Functions
2.6 Flexible Protection Functions
NOTE
With regard to the phase-selective pickup messages, a special behavior is observed in the three-phase voltage protection with phase-to-phase variables, because the phase-selective pickup message "Flx01 Pickup Lx" is allocated to the respective measured-value channel "Lx".
Single-phase faults: If, for example, voltage VA drops to such degree that voltages VAB and VA exceed their threshold values, the device indicates pickups “Flx01 Pickup A” and “Flx01 Pickup C”, because the undershooting was detected in
the first and third measured-value channel. Two-phase faults: If, for example, voltage VAB drops to such degree that its threshold value is reached, the device then indi­cates pickup "Flx01 Pickup A", because the undershooting was detected in the first measured-value
channel.
Table 2-9 Parameter in the Setting Dialog "Measurement Procedure", Mode of Operation 1-phase
Parameter OPERRAT. MODE = 1-phase
Parameter MEAS. QUANTITY = Voltage Parameter
MEAS. METHOD
Fundamental
True RMS
Parameter MEAS. QUANTITY = Voltage Parameter VOLTAGE
Va-n
Vb-n
Vc-n
Va-b
Vb-c
Vc-a
Vn
Vx
Only the fundamental harmonic is evaluated, higher harmonics are suppressed. This is the standard measurement procedure of the protection functions.
The “True” RMS value is determined, i.e. higher harmonics are evaluated.
It is determined which voltage-measuring channel is evaluated by the function. When selecting phase-to-phase voltage, the threshold value must be set as a phase-to-phase value, when selecting a phase-to-ground variable as phase-toground voltage. The extent of the setting texts depends on the connection of the voltage transformer (see address213 VT Connect. 3ph).
Settings
The pickup thresholds, delay times and dropout ratios of the flexible protection function are set in the “Settings” dialog box in DIGSI.
The pickup threshold of the function is configured via parameter P.U. THRESHOLD. The TRIP-command delay time is set via parameter T TRIP DELAY. Both setting values must be selected according to the required application.
The pickup can be delayed via parameter T PICKUP DELAY. This parameter is usually set to zero (default setting) in protection applications, because a protection function should pick up as quickly as possible. A setting deviating from zero may be appropriate if a trip log is not desired to be started upon each short-term exceeding of the pickup threshold, for example, when a function is not used as a protection, but as a moni­toring function.
The dropout of pickup can be delayed via parameter T DROPOUT DELAY. This setting is also set to zero by default (standard setting) A setting deviating from zero may be required if the device is utilized together with electro-magnetic devices with considerably longer dropout ratios than the digital protection device. When utilizing the dropout time delay, it is recommended to set it to a shorter time than the OFF-command delay time in order to avoid both times to “race”.
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Parameter BLK.by Vol.Loss determines whether a function, with measured variable based on a voltage measurement (measured variables voltage), should be blocked in case of a measured voltage failure/loss of potential (set to YES) or not (set to NO).
The dropout ratio for the function can be set via the parameter DROPOUT RATIO. The standard dropout ratio of protection functions is 0.95 (default setting). If the dropout ratio is decreased, it would be sensible to test the pickup of the function regarding possible “chatter”.
The dropout difference of the frequency elements is set under parameter DO differential. Usually, the default setting of 0.02 Hz can be retained. A higher dropout difference should be set in weak systems with larger, short-term frequency fluctuations to avoid chattering of the message.
The frequency change measured value (df/dt) works with a fixed dropout difference of 0.1 Hz/s. The same applies to the voltage change (dU/dt) measurand. The permanent dropout difference here is 3 V/s.
Renaming Messages, Checking Configurations
After parameterization of a flexible function, the following steps should be noted:
Open matrix in DIGSI
Rename the neutral message texts in accordance with the application.
Check configurations on contacts and in operation and fault buffer, or set them according to the require-
ments.
Functions
2.6 Flexible Protection Functions
2.6.3
Addr.
0 FLEXIBLE FUNC. OFF
0 OPERRAT. MODE 3-phase
0 MEAS. QUANTITY Please select
0 MEAS. METHOD Fundamental
0 PICKUP WITH Exceeding

Settings

Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Parameter Setting Options Default Setting Comments
ON Alarm Only
1-phase no reference
Voltage Frequency df/dt rising df/dt falling Binray Input dV/dt rising dV/dt falling
True RMS Positive seq. Negative seq. Zero sequence Ratio I2/I1
Dropping below
OFF Flexible Function
3-phase Mode of Operation
Please select Selection of Measured Quantity
Fundamental Selection of Measurement Method
Exceeding Pickup with
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Functions
2.6 Flexible Protection Functions
Addr. Parameter Setting Options Default Setting Comments
0 VOLTAGE Please select
Va-n Vb-n Vc-n Va-b Vb-c Vc-a Vn Vx
0 VOLTAGE SYSTEM Phase-Phase
Phase-Ground 0 P.U. THRESHOLD 2.0 .. 260.0 V 110.0 V Pickup Threshold 0 P.U. THRESHOLD 2.0 .. 200.0 V 110.0 V Pickup Threshold 0 P.U. THRESHOLD 2.0 .. 260.0 V 110.0 V Pickup Threshold 0 P.U. THRESHOLD 40.00 .. 60.00 Hz 51.00 Hz Pickup Threshold 0 P.U. THRESHOLD 50.00 .. 70.00 Hz 61.00 Hz Pickup Threshold 0 P.U. THRESHOLD 0.10 .. 20.00 Hz/s 5.00 Hz/s Pickup Threshold 0 P.U. THRESHOLD 4 .. 100 V/s 60 V/s Pickup Threshold 0 T TRIP DELAY 0.00 .. 3600.00 sec 1.00 sec Trip Time Delay 0A T PICKUP DELAY 0.00 .. 60.00 sec 0.00 sec Pickup Time Delay 0A T DROPOUT DELAY 0.00 .. 60.00 sec 0.00 sec Dropout Time Delay 0A BLK.by Vol.Loss NO
YES 0A DROPOUT RATIO 0.70 .. 0.99 0.95 Dropout Ratio 0A DROPOUT RATIO 1.01 .. 3.00 1.05 Dropout Ratio 0 DO differential 0.02 .. 1.00 Hz 0.03 Hz Dropout differential
Please select Voltage
Phase-Phase Voltage System
YES Block in case of Meas.-Voltage
Loss
2.6.4
No.
235.2110 >BLOCK $00 SP >BLOCK Function $00
235.2111 >$00 instant. SP >Function $00 instantaneous TRIP
235.2112 >$00 Dir.TRIP SP >Function $00 Direct TRIP
235.2113 >$00 BLK.TDly SP >Function $00 BLOCK TRIP Time Delay
235.2114 >$00 BLK.TRIP SP >Function $00 BLOCK TRIP
235.2115 >$00 BL.TripA SP >Function $00 BLOCK TRIP Phase A
235.2116 >$00 BL.TripB SP >Function $00 BLOCK TRIP Phase B
235.2117 >$00 BL.TripC SP >Function $00 BLOCK TRIP Phase C
235.2118 $00 BLOCKED OUT Function $00 is BLOCKED
235.2119 $00 OFF OUT Function $00 is switched OFF
235.2120 $00 ACTIVE OUT Function $00 is ACTIVE
235.2121 $00 picked up OUT Function $00 picked up
235.2122 $00 pickup A OUT Function $00 Pickup Phase A
235.2123 $00 pickup B OUT Function $00 Pickup Phase B
235.2124 $00 pickup C OUT Function $00 Pickup Phase C

Information List

Information Type of
Informa­tion
Comments
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Functions
2.6 Flexible Protection Functions
No. Information Type of
Comments Informa­tion
235.2125 $00 Time Out OUT Function $00 TRIP Delay Time Out
235.2126 $00 TRIP OUT Function $00 TRIP
235.2128 $00 inval.set OUT Function $00 has invalid settings
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Functions

2.7 Synchrocheck

2.7
2.7.1
Synchrocheck
When connecting two sections of a power system, the synchrocheck function verifies that the switching does not endanger the stability of the power system
Applications
Typical applications are, for example, the synchronization of a feeder and a busbar or the synchronization
of two busbars via tie-breaker.

Allgemeines

Synchronous power systems exhibit small differences regarding frequency and voltage values. Before connec­tion it is to be checked whether the conditions are synchronous or not. If the conditions are synchronous, the system is energized; if they are asynchronous, it is not. The circuit breaker operating time is not taken into consideration. The synchrocheck function is activated via address 161 SYNCHROCHECK.
For comparing the two voltages of the sections of the power system to be synchronized, the synchrocheck function uses the reference voltage V1 and an additional voltage to be connected V2.
If a transformer is connected between the two voltage transformers as shown in the following example, its vector group can be adapted in the 7RW80 relay so that there is no external adjustment required.
[synchro-fkt-einspeis-061115, 1, en_US]
Figure 2-21 Infeed
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Functions
2.7 Synchrocheck
[synchro-fkt-querkuppl-061115, 1, en_US]
Figure 2-22 Cross coupling
The synchrocheck function of the 7RW80 usually coordinates with the control function. Nevertheless, it is also possible to employ an external automatic reclosing system. In such a case, the signal exchange between the devices is to be accomplished via binary inputs and outputs.
The release command for closing under satisfied synchronism conditions can be deactivated via parameter 6113 25 Synchron. For special applications, the deactivated closing release can, however, be activated via a binary input (
>25 synchr.
) (see “De-energized Switching”).
2.7.2
Validity Check of the Configuration
SYNC Error
Release

Functional Sequence

Already during startup of the device, a validation check of the configuration is performed. If there is a fault, the message sible, the message
Concerning the configuration, it is also checked if the substation parameter 213 is set to Vab, Vbc, VSyn or Vph-g, VSyn. Furthermore, specific thresholds and settings of the function group are checked. If there is a condition which is not plausible, the error message this case that address 6106 (threshold V1, V2 energized) is smaller than address 6103 (lower voltage limit
Vmin). The synchrocheck function cannot be controlled via a binary input.
The synchronization is not started if a voltage transformer failure (m.c.b. tripping) is communicated to the device via the binary input 6509
Error
In case of a protection pickup, the complete synchronization process is reset instantaneously.
The synchrocheck function only operates if it receives a measurement request. This request may be issued by the internal control function, the automatic reclosing function or externally via a binary input, e.g. from an external automatic reclosing system.
Before a release for closing is granted, the following conditions are checked:
Is the reference voltage V1 above the setting value Vmin but below the maximum voltage Vmax?
25 Set-Error
25 Set-Error
is output. In this case, the synchronization can be controlled directly via a binary input.
is output. after a measurement request there is a condition which is not plau-
is output. The measurement is then not started.
25 Set-Error
>FAIL:FEEDER VT
or 6510
is output additionally. Please ensure in
>FAIL: BUS VT
. The message
25 Sync.
Is the voltage V2 to be synchronized above the setting value Vmin, but below the maximum voltage
Vmax?
Is the voltage difference V2 – V1 within the permissible limit dV SYNCHK V2>V1?
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Functions
2.7 Synchrocheck
Is the voltage difference V1 – V2 within the permissible limit dV SYNCHK V2<V1?
Are the two frequencies f1 and f2 within the permissible operating range f
Is the frequency difference f2 – f1 within the permissible limit df SYNCHK f2>f1?
Is the frequency difference f1 – f2 within the permissible limit df SYNCHK f2<f1?
Is the angle difference α2 – α1 within the permissible limit dα SYNCHK α2>α1?
Is the angle difference α1 – α2 within the permissible limit dα SYNCHK α2<α1?
If there is a condition which is not plausible, the message is not started. the conditions are plausible, the measurement is started (message configured release conditions are checked.
Each condition which is met is indicated explicitly (messages Conditions which are not met are also indicated explicitly, e.g. when the voltage difference (messages
,
V2>V1
25 V2<V1
α2>α1, 25 α2<α1
within the operating range of the synchrocheck function (see “Operating Range”). If the conditions are met, the synchrocheck function issues a release signal for closing the relay (
elease
processed by the device's function control as CLOSE command to the circuit breaker (see also margin heading “Interaction with Control”). However, the message tions are met.
The measurement of the the synchronism conditions can be confined to the a maximum monitoring time T- SYN. DURATION. If the conditions are not met within T-SYN. DURATION, the release is cancelled (message
). This release signal is only available for the configured duration of the CLOSE command and is
25 MonTimeExc
), frequency difference (messages „25 f2>f1“, „25 f2<f1“) or angle difference (messages ) is outside the limit values. The precondition for these messages is that both voltages are
). A new synchronization can only be performed if a new measurement request is received.
25 Sync. Error
25 Vdiff ok, 25 fdiff ok, 25 αdiff ok
25 Synchron
is applied as long as the synchronous condi-
± 3 Hz?
Nom
is output and the measurement
25-1 meas.
) and the
25
25
25 CloseR-
).
Operating Range
The operating range of the synchrocheck function is defined by the configured voltage limits Vmin and Vmax as well as the fixed frequency band f
If the measurement is started and one of or both voltages are outside the operating range or one of the voltages leaves the operating range, this is indicated by corresponding messages (
V1>>, 25 V1<<
Measured Values
The measured values of the synchrocheck function are displayed in separate windows for primary, secondary and percentaged measured values. The measured values are displayed and updated only while the synchro­check function is requested.
The following is displayed:
2.7.3

De-energized Switching

Connecting two components of a power system is also possible if at least one of the components is de-ener­gized and if the measured voltage is greater than the threshold 6106 V>. With a multi-phase connection on the side V1, all connected voltages must have a higher value than the threshold V> so that the side V1 is
considered as being energized. With a single-phase connection, of course, only the one voltage has to exceed the threshold value.
± 3 Hz
Nom
).
Value of the reference voltage V
Value of the voltage to be synchronized V
Frequency values f1 and f
Differences of voltage, frequency and angle.
1
2
2
25 f1>>, 25 f1<<, 25
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Functions
2.7 Synchrocheck
Besides the release under synchronous conditions, the following additional release conditions can be selected for the check:
SYNC V1>V2< = Release on the condition that component V1 is energized and component V2 is de-
energized.
SYNC V1<V2> = Release on the condition that component V1 is de-energized and component V2 is
energized.
SYNC V1<V2< = Release on the condition that component V1 and component V2 are de-energized.
Each of these conditions can be enabled or disabled individually via parameters or binary inputs; combinations are thus also possible (e.g. release if SYNC V1>V2<
For that reason synchronization with the use of the additional parameter 6113 25 Synchron (configured to NO) can also be used for the connection of a ground electrode. In such a case, connection is only permissible when there is no voltage on the load side.
The threshold below which a power system component is considered as being de-energized is defined by parameter V<. If the measured voltage exceeds the threshold V>, a power system component is considered as being energized. With a multi-phase connection on the side V1, all connected voltages must have a higher
value than the threshold V> so that the side V1 is considered as being energized. With a single-phase connec­tion, of course, only the one voltage has to exceed the threshold value. Before granting a release for connecting the energized component V1 and the de-energized component V2, the following conditions are checked:
Is the reference voltage V1 above the setting value Vmin and V> but below the maximum voltage Vmax?
or SYNC V1<V2> are fulfilled).
2.7.4
Is the voltage to be synchronized V2 below the setting value V<?
Is the frequency f1 within the permissible operating range f
After successful completion of the checks, the release is granted. For connecting the de-energized component 1 to the energized component 2 or the de-energized component
1 to the de-energized component 2, the conditions to be fulfilled correspond to those stated above. The associated messages indicating the release via the corresponding condition are as follows:
25 V1< V2>
Via the binary inputs externally, provided the synchronization is controlled externally.
The parameter TSUP VOLTAGE (address 6111) can be set to configure a monitoring time which requires the additional release conditions stated above to be present for de-energized connection before connection is allowed.
and
25 V1< V2<
.
>25 V1>V2<, >25 V1<V2>
and
>25 V1<V2<
± 3 Hz?
Nom
25 V1> V2<
, the release conditions can also be issued

Direct Command / Blocking

Parameter 6110 Direct CO can be set to grant a release without performing any checks. In this case, connection is allowed immediately when initiating the synchrocheck function. It is obviously not reasonable to combine Direct CO with other release conditions.
If the synchrocheck function fails, a direct command may be issued or not, depending on the type of failure (also see “Plausibility Check” and “SYNC Error”).
Via the binary input Blocking the entire synchrocheck function is possible via the binary input
this condition is output via function is reset. A new measurement can only be performed with a new measurement request.
Via the binary input
lease
). When the blocking is active, measurement continues. The blocking is indicated by the message
CLOSE BLK
closing is issued.
. When the blocking is reset and the release conditions are still fulfilled, the release signal for
>25direct CO
25-1 BLOCK
>BLK 25 CLOSE
, this release can also be granted externally.
>BLK 25-1
. With the blocking, the measurement is terminated and the entire
it is possible to block only the release signal for closing (
. The message signaling
25 CloseRe-
25
,
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Functions
2.7 Synchrocheck
2.7.5
With Control

Interaction with Control and External Control

Basically, the synchrocheck function interacts with the device control. The switchgear component to be synchronized is selected via a parameter. If a CLOSE command is issued, the control takes into account that the switchgear component requires synchronization. The control sends a measurement request (
req.
) to the synchrocheck function which is then started. Having completed the check, the synchrocheck function issues the release message ( switching operation either positively or negatively.
[dw_zusam-wirk-steuer-synchro-fkt, 1, en_US]
Figure 2-23 Interaction of control and synchrocheck function
25 CloseRelease
) to which the control responds by terminating the
25 Measu.
With External Control
As another option, the synchrocheck function can be activated via external measurement requests via binary inputs. If the start is effected via the pulse start signal must always be generated, too. Having completed the check, the synchrocheck function issues the release message (see the following figure). Measurement is terminated as soon as the measurement request is reset via the binary input. In this case, there is no need to configure a control device to be synchronized.
[dw_zusam-wirk-synchro-fkt-mit-ext-anst, 1, en_US]
Figure 2-24 Interaction of synchrocheck function and external control
2.7.6
General

Setting Notes

The synchronization function can only operate if 25 Function 1 with SYNCHROCHECK was enabled at address 161 during configuration of the functional scope (see Section 2.1.1.2 Setting Notes). If this function is not required, then Disabled is set.
While setting the Power System Data 1 (see Section Voltage Connection (Power System), Page 29) the device was already provided with data relevant for the measured values and the operating principle of the synchroni­zation function. This concerns the following parameters:
>25 Start
, the corresponding stop signal
>25 Stop
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Functions
2.7 Synchrocheck
202 Vnom PRIMARY primary nominal voltage of the voltage transformers V1 (phase-to-phase) in kV; 203 Vnom SECONDARY secondary nominal voltage of the voltage transformers V1 phase-to-phase) in V; 213 VT Connect. 3ph specifies how the voltage transformers are connected.
When using the synchronization function the setting Vab, Vbc, VSyn is used if two phase-to-phase voltages are open delta-connected to the device. You can use any phase-to-phase voltage as the reference voltage V
SYN
Use the setting Vph-g, VSyn if only phase-to-ground voltages are available. One of these voltages is connected to the first voltage transformer; the reference voltage V
is connected to the third voltage trans-
SYN
former. V1 at the first voltage transformer and V2 at the third voltage transformer must belong to the same voltage type (VAN or VBN or VCN). Connection examples are given under side heading “Voltage Connections” and in the Appendix C Connection
Examples).
If you have set Vab, Vbc, VSyn or Vph-g, VSyn, the zero sequence voltage can not be determined.
Table 2-1 in Section Voltage Connection (Power System), Page 29 provides information about the conse-
quences of the different voltage connection types. The operating range of the synchronization function (f
± 3 Hz) refers to the nominal frequency of the
Nom
power system, address 214 Rated Frequency. The corresponding messages of the SYNC function group are pre-allocated for IEC 60870–5–103 (VDEW). Selecting the SYNC function group in DIGSI opens a dialog box with tabs in which the individual parameters
for synchronization can be set.
General Settings
The general thresholds for the synchronizing function are set at addresses 6101 to 6112. Address 6101 Synchronizing allows you to switch the entire SYNC function group ON or OFF. If switched
off, the synchrocheck does not verify the synchronization conditions and release is not granted. Parameter 6102 SyncCB is used to select the switchgear component to which the synchronization settings are
applied. Select the option none to use the function as external synchronizing feature. It will then be triggered via binary input messages.
Addresses 6103 Vmin and 6104 Vmax set the upper and lower limits for the operating voltage range for V1 or V2 and thus determine the operating range for the synchronization function. Values outside this range will be signaled. Address 6105 V< indicates the voltage threshold below which the feeder or the busbar can safely be consid-
ered switched off (for checking a de-energized feeder or busbar). Address 6106 V> indicates the voltage threshold above which the feeder or busbar can safely be considered
energized (for checking an energized feeder or busbar). It must be set below the anticipated operational undervoltage.
The setting for the mentioned voltage values is made in secondary volts. When using DIGSI for configuration, these values can also be entered as primary values. Depending on the connection of the voltages these are phase-to-earth voltages or phase-to-phase voltages.
Addresses 6107 to 6110 are set to specify the release conditions for the voltage check: Where 6107 SYNC V1<V2> = component V1 must be de-energized, component V2 must be energized (connection when reference is de-energized, dead line); 6108 SYNC V1>V2< = component V1 must be energized, component V2 must be de-energized (connection when feeder is de-energized, dead bus); 6109 SYNC V1<V2< = component V1 and component V2 must both be de-energized (connection when refer­ence and feeder are de-energized, dead bus / dead line); 6110 Direct CO = connection released without checks. The possible release conditions are independent of each other and can be combined. It is not recommended to
combine Direct CO with other release conditions.
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Functions
2.7 Synchrocheck
Parameter TSUP VOLTAGE (address 6111) can be set to configure a monitoring time which requires above stated release conditions to be present for at least de-energized switching before connection is allowed. The preset value of 0.1 s accounts for transient responses and can be applied without modification.
Release via synchrocheck can be limited to a configurable synchronous monitoring time SYN. DURATION (address 6112). The configured conditions must be fulfilled within this time period. Otherwise release is not granted and the synchronizing function is terminated. If this time is set to ∞, the conditions will be checked until they are fulfilled.
For special applications (e.g. connecting a ground switch) parameter 6113 25 Synchron allows enabling/ disabling the connection release when the conditions for synchronism are satisfied.
Power System Data
The system related data for the synchronization function are set at addresses 6121 to 6125. The parameter Balancing V1/V2 (address 6121) can be set to account for different VT ratios of the two
parts of the power system (see example in Figure 2-25). If a transformer is located between the system parts to be synchronized, its vector group can be accounted for
by angle adjustment so that no external adjusting measures are required. Parameter ANGLE ADJUSTM. (address 6122) is used to this end.
The phase angle from V1 to V2 is evaluated positively. Example:
Busbar 400 kV primary; 100 V secondary Feeder 220 kV primary; 110 V secondary Transformer 400 kV/220 kV; vector group Dy(n)5
The transformer vector group is defined from the high side to the low side. In the example, the reference voltage transformers (V1) are the ones of the transformer high side, i.e. the setting angle is 5 x 30° (according
to vector group), that is 150°: Address 6122 ANGLE ADJUSTM. = 150°. The reference voltage transformers supply 100 V secondary for primary operation at nominal value while the
feeder transformer supplies 110 V secondary. Therefore, this difference must be balanced: Address 6121 Balancing V1/V2 = 100 V/110 V = 0.91.
[ss-spg-ueber-trafo-gemess-061115, 1, en_US]
Figure 2-25 Busbar voltage measured across the transformer
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Voltage Connections
The 7RW80 provides two voltage inputs for connecting the voltage V1 and one voltage input for connecting the voltage V2 (see the following examples).
If two phase-to-phase voltages are open delta-connected to side V1 as reference voltage, a phase-to-phase voltage
must be connected and configured for the additional voltage V2 to be synchronized.
To correctly compare the phase-to-phase reference voltage V1 with the additional voltage V2, the device needs to know the connection type of voltage V2. That is the task of parameter CONNECTIONof V2 (parameter
6123). For the device to perform the internal conversion to primary values, the primary rated transformer voltage of
the measured quantity V2 must be entered via parameter 6125 VT Vn2, primary, primary if a transformer is located between the system parts to be synchronized.
Functions
2.7 Synchrocheck
[sync-mehrphasig-anschl-061116, 1, en_US]
Figure 2-26
Phase-to-phase voltage connection (open-delta connection)
If only phase-to-ground voltages are available, the reference voltage V1 is connected to the first voltage trans­former and the additional voltage V2 to the third voltage transformer.
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Functions
2.7 Synchrocheck
[sync-1phasig-anschl-le-061116, 1, en_US]
Figure 2-27
Phase-to-ground voltage connection
Voltage Difference
The parameters 6150 dV SYNCHK V2>V1 and 6151 dV SYNCHK V2<V1 can be set to adjust the permissible voltage differences asymmetrically. The availability of two parameters enables an asymmetrical release to be set.
Frequency Difference
The parameters 6152 df SYNCHK f2>f1 and 6153 df SYNCHK f2<f1 determine the permissible frequency differences. The availability of two parameters enables an asymmetrical release to be set.
Operating Range
The parameters 6154 dα SYNCHK α2>α1 and 6155 dα SYNCHK α2<α1 delimit the operating range for switching under synchronous system conditions. The availability of two parameters enables an asymmetrical release range to be set.
2.7.7

Settings

Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
Addr.
6101 Synchronizing ON
Parameter Setting Options Default Setting Comments
OFF Synchronizing Function
OFF
6102 SyncCB (Einstellmöglichkeiten
none Synchronizable circuit breaker
anwendungsabhängig) 6103 Vmin 20 .. 125 V 90 V Minimum voltage limit: Vmin 6104 Vmax 20 .. 140 V 110 V Maximum voltage limit: Vmax 6105 V< 1 .. 60 V 5 V Threshold V1, V2 without voltage 6106 V> 20 .. 140 V 80 V Threshold V1, V2 with voltage
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Functions
2.7 Synchrocheck
Addr. Parameter Setting Options Default Setting Comments
6107 SYNC V1<V2> YES
NO
6108 SYNC V1>V2< YES
NO
6109 SYNC V1<V2< YES
NO
6110A Direct CO YES
NO
6111A TSUP VOLTAGE 0.00 .. 60.00 sec 0.10 sec Supervision time of V1>;V2> or
6112 SYN. DURATION 0.01 .. 1200.00 sec 30.00 sec Maximum duration of
6113A 25 Synchron YES
NO 6121 Balancing V1/V2 0.50 .. 2.00 1.00 Balancing factor V1/V2 6122A ANGLE ADJUSTM. 0 .. 360 ° 0 ° Angle adjustment (transformer) 6123 CONNECTIONof V2 A-B
B-C
C-A 6125 VT Vn2, primary 0.10 .. 800.00 kV 20.00 kV VT nominal voltage V2, primary 6150 dV SYNCHK V2>V1 0.5 .. 50.0 V 5.0 V Maximum voltage difference
6151 dV SYNCHK V2<V1 0.5 .. 50.0 V 5.0 V Maximum voltage difference
6152 df SYNCHK f2>f1 0.01 .. 2.00 Hz 0.10 Hz Maximum frequency difference
6153 df SYNCHK f2<f1 0.01 .. 2.00 Hz 0.10 Hz Maximum frequency difference
6154 dα SYNCHK α2>α1 2 .. 80 ° 10 ° Maximum angle difference
6155 dα SYNCHK α2<α1 2 .. 80 ° 10 ° Maximum angle difference
NO ON-Command at V1< and V2>
NO ON-Command at V1> and V2<
NO ON-Command at V1< and V2<
NO Direct ON-Command
V1<;V2<
synchronism-check
YES Switching at synchronous condi-
tion
A-B Connection of V2
V2>V1
V2<V1
f2>f1
f2<f1
alpha2>alpha1
alpha2<alpha1
2.7.8
No.
170.0001 >25-1 act SP >25-group 1 activate
170.0043 >25 Sync requ. SP >25 Synchronization request
170.0049 25 CloseRelease OUT 25 Sync. Release of CLOSE Command
170.0050 25 Sync. Error OUT 25 Synchronization Error
170.0051 25-1 BLOCK OUT 25-group 1 is BLOCKED
170.2007 25 Measu. req. SP 25 Sync. Measuring request of Control
170.2008 >BLK 25-1 SP >BLOCK 25-group 1
170.2009 >25direct CO SP >25 Direct Command output
170.2011 >25 Start SP >25 Start of synchronization
170.2012 >25 Stop SP >25 Stop of synchronization
170.2013 >25 V1>V2< SP >25 Switch to V1> and V2<
SIPROTEC 4, 7RW80, Manual 89 C53000-G1140-C233-4, Edition 07.2018

Information List

Information Type of
Informa­tion
Comments
Functions
2.7 Synchrocheck
No. Information Type of
Comments Informa­tion
170.2014 >25 V1<V2> SP >25 Switch to V1< and V2>
170.2015 >25 V1<V2< SP >25 Switch to V1< and V2<
170.2016 >25 synchr. SP >25 Switch to Sync
170.2022 25-1 meas. OUT 25-group 1: measurement in progress
170.2025 25 MonTimeExc OUT 25 Monitoring time exceeded
170.2026 25 Synchron OUT 25 Synchronization conditions okay
170.2027 25 V1> V2< OUT 25 Condition V1>V2< fulfilled
170.2028 25 V1< V2> OUT 25 Condition V1<V2> fulfilled
170.2029 25 V1< V2< OUT 25 Condition V1<V2< fulfilled
170.2030 25 Vdiff ok OUT 25 Voltage difference (Vdiff) okay
170.2031 25 fdiff ok OUT 25 Frequency difference (fdiff) okay
170.2032 25 αdiff ok OUT 25 Angle difference (alphadiff) okay
170.2033 25 f1>> OUT 25 Frequency f1 > fmax permissible
170.2034 25 f1<< OUT 25 Frequency f1 < fmin permissible
170.2035 25 f2>> OUT 25 Frequency f2 > fmax permissible
170.2036 25 f2<< OUT 25 Frequency f2 < fmin permissible
170.2037 25 V1>> OUT 25 Voltage V1 > Vmax permissible
170.2038 25 V1<< OUT 25 Voltage V1 < Vmin permissible
170.2039 25 V2>> OUT 25 Voltage V2 > Vmax permissible
170.2040 25 V2<< OUT 25 Voltage V2 < Vmin permissible
170.2050 V1 = MV V1 =
170.2051 f1 = MV f1 =
170.2052 V2 = MV V2 =
170.2053 f2 = MV f2 =
170.2054 dV = MV dV =
170.2055 df = MV df =
170.2056 dα = MV dalpha =
170.2090 25 V2>V1 OUT 25 Vdiff too large (V2>V1)
170.2091 25 V2<V1 OUT 25 Vdiff too large (V2<V1)
170.2092 25 f2>f1 OUT 25 fdiff too large (f2>f1)
170.2093 25 f2<f1 OUT 25 fdiff too large (f2<f1)
170.2094 25 α2>α1 OUT 25 alphadiff too large (a2>a1)
170.2095 25 α2<α1 OUT 25 alphadiff too large (a2<a1)
170.2096 25 FG-Error OUT 25 Multiple selection of func-groups
170.2097 25 Set-Error OUT 25 Setting error
170.2101 25-1 OFF OUT Sync-group 1 is switched OFF
170.2102 >BLK 25 CLOSE SP >BLOCK 25 CLOSE command
170.2103 25 CLOSE BLK OUT 25 CLOSE command is BLOCKED
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C53000-G1140-C233-4, Edition 07.2018
Functions

2.8 24 Overexcit. Protection (Volt/Hertz)

2.8
2.8.1
Measurement Method
24 Overexcit. Protection (Volt/Hertz)
Overexcitation protection is used to detect inadmissibly high induction in generators and transformers, espe­cially in power station unit transformers. The protection must intervene when the limit value for the protected object (e.g. unit transformer) is exceeded. The transformer is endangered, for example, if the power station block is disconnected from the system from full-load, and if the voltage regulator either does not operate or does not operate sufficiently fast to control the associated voltage rise. Similarly a decrease in frequency (speed), e.g. in island systems, can lead to an inadmissible increase in induction.
An increase in induction above the rated value quickly saturates the iron core and causes large eddy current losses.

Functional Description

The overexcitation protection feature servers to measure the voltage V/frequency f, ratio f, which is propor­tional to the B induction and puts it in relation to the BN nominal induction. In this context, both voltage and
frequency are related to nominal values of the object to be protected (generator, transformer).
[uebereregungsschutz-020827-ho, 1, en_US]
[uebereregungsschutz2-020827-ho, 1, en_US]
The calculation is based on the maximum of the three phase-to-phase voltages. The frequency range moni­tored extends from 25 Hz to 70 Hz.
Voltage Transformer Adaptation
Any deviation between the primary nominal voltage of the voltage transformers and of the protected object is compensated by an internal correction factor (V
istic do not need to be converted to secondary values. However the system primary nominal transformer voltage and the nominal voltage of the object to be protected must be entered correctly (see Sections
2.1.3 Power System Data 1 and 2.1.6 Power System Data 2).
Characteristics
Overexcitation protection includes two time graded characteristics and one thermal characteristic for approxi­mate modeling of the heating of the protection object due to overexcitation. As soon as a first pickup threshold (warning element 4302 24-1 PICKUP) has been exceeded, a 4303 24-1 DELAY time element is started. On its expiry a warning message is transmitted. At the same time a counter switching is activated when the pickup threshold is exceeded. This weighted counter is incremented in accordance with the current V/f value resulting in the trip time for the parametrized characteristic. A trip signal is transmitted as soon as the trip counter state has been reached.
The trip signal is retracted as soon as the value falls below the pickup threshold and the counter is decre­mented in accordance with a parametrizable cool-down time.
The thermal characteristic is specified by 8 value pairs for overexcitation V/f (related to nominal values) and trip time t. In most cases, the specified characteristic for standard transformers provides sufficient protection. If this characteristic does not correspond to the actual thermal behavior of the object to be protected, any desired characteristic can be implemented by entering customer-specific trip times for the specified V/f overex­citation values. Intermediate values are determined by a linear interpolation within the device.
Nom prim/VNom Mach
). For this reason pickup values and character-
SIPROTEC 4, 7RW80, Manual 91 C53000-G1140-C233-4, Edition 07.2018
Functions
2.8 24 Overexcit. Protection (Volt/Hertz)
[ausloesebereich-des-uebereregungsschutz-020827-ho, 1, en_US]
Figure 2-28
Tripping Range of the Overexcitation Protection
The characteristic resulting from the device default settings is shown in the Technical Data Section Overexcita­tion Protection. Figure 2-28 illustrates the behaviour of the protection on the assumption that within the framework of configuration the setting for the pickup threshold (parameter 4302 24-1 PICKUP) was chosen higher or lower than the first setting value of the thermal characteristic.
The following figure shows the logic diagram for overexcitation protection. The counter can be reset to zero by means of a blocking input or a reset input.
92 SIPROTEC 4, 7RW80, Manual
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Functions
2.8 24 Overexcit. Protection (Volt/Hertz)
[logikdiagramm-des-uebereregungsschutzes-020827-ho, 1, en_US]
Figure 2-29
2.8.2

Setting Notes

General
Overecxitation Protection is only in effect and accessible if address 143 24 V/f is set to Enabled during configuration of protective functions. If the function is not required Disabled is set. Under address 4301 FCT 24 V/f the function can be turned ON or OFF.
Overexcitation protection measures the voltage/frequency quotient which is proportional to the induction B. The protection must intervene when the limit value for the protected object (e.g. unit transformer) is exceeded. The transformer is for example endangered if the power station block is switched off at full-load operation and the voltage regulator does not respond fast enough or not at all to avoid related voltage increase.
Similarly a decrease in frequency (speed), e.g. in island systems, can lead to an inadmissible increase in induc­tion.
In this way the V/f protection monitors the correct functioning both of the voltage regulator and of the speed regulation, in all operating states.
Independent Elements
The limit-value setting at address 4302 24-1 PICKUP is based on the induction limit value relation to the nominal induction (B/BN) as specified by the manufacturer of the object to be protected.
A pickup message is transmitted as soon as the induction limit value V/f at address 4302 is exceeded. A warning message is transmitted after expiry of the corresponding 4303 24-1 DELAY time delay.
The 4304 24-2 PICKUP, 4305 24-2 DELAY trip element characteristic serves to rapidly switch off particu­larly strong overexcitations.
The time set for this purpose is an additional time delay which does not include the operating time (measuring time, drop-out time).
Logic diagram of the Overecxitation protection
SIPROTEC 4, 7RW80, Manual 93 C53000-G1140-C233-4, Edition 07.2018
Functions
2.8 24 Overexcit. Protection (Volt/Hertz)
Thermal Characteristic
A thermal characteristic is superimposed on the trip element characteristic. For this purpose, the temperature rise created by the overexcitation is approximately modeled. Not only the already mentioned pickup signal is generated on transgression of the V/f induction limit set at address 4302, but in addition a counter is activated additionally which causes the tripping after a length of time corresponding to the set characteristic.
[thermische-ausloesekennlinie-020827-ho, 1, en_US]
Figure 2-30
Thermal tripping time characteristic (with presettings)
The characteristic of a Siemens standard transformer was selected as a default setting for the parameters 4306 to 4313. If the protection object manufacturer did not provide any information, the preset standard characteristic should be used. Otherwise, any trip characteristic can be specified entering parameters point­bypoint over a maximum of 7 straight lengths. To do this, the trip times t of the overexcitation values V/f =
1.05; 1.10; 1.15; 1.20; 1.25; 1.30; 1.35 and 1.40 are read out from predefined characteristic and entered at the addresses 4306 24-t(V/f=1.05) to 4313 24-t(V/f=1.40) 24-t(V/f=1.40). The protection device interpolates linearly between the points.
Limitation
The heating model of the object to be protected is limited to a 150 % overshoot of the trip temperature.
Cooling time
Tripping by the thermal image drops out by the time of the pickup threshold dropout. However, the counter content is counted down to zero with the cooldown time parametrized at address 4314 24 T COOL DOWN. In this context this parameter is defined as the time required by the thermal image to cool down from 100 % to 0 %.
Voltage Transformer Adaptation
Any deviation between primary nominal voltage of the voltage transformers and of the object to be protected is compensated by an internal correction factor (V
parameters 202 Vnom PRIMARY and 1101 FullScaleVolt. have been entered correctly in accordance with Section 2.1.3.2 Setting Notes and 2.1.6.2 Setting Notes.
Nom prim/VNom Mach
). For this it is necessary that the relevant
94 SIPROTEC 4, 7RW80, Manual
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Functions
2.8 24 Overexcit. Protection (Volt/Hertz)
2.8.3
Addr. Parameter Setting Options Default Setting Comments
4301 FCT 24 V/f OFF
4302 24-1 PICKUP 1.00 .. 1.20 1.10 24-1 V/f Pickup 4303 24-1 DELAY 0.00 .. 60.00 sec 10.00 sec 24-1 V/f Time Delay 4304 24-2 PICKUP 1.00 .. 1.40 1.40 24-2 V/f Pickup 4305 24-2 DELAY 0.00 .. 60.00 sec 1.00 sec 24-2 V/f Time Delay 4306 24-t(V/f=1.05) 0 .. 20000 sec 20000 sec 24 V/f = 1.05 Time Delay 4307 24-t(V/f=1.10) 0 .. 20000 sec 6000 sec 24 V/f = 1.10 Time Delay 4308 24-t(V/f=1.15) 0 .. 20000 sec 240 sec 24 V/f = 1.15 Time Delay 4309 24-t(V/f=1.20) 0 .. 20000 sec 60 sec 24 V/f = 1.20 Time Delay 4310 24-t(V/f=1.25) 0 .. 20000 sec 30 sec 24 V/f = 1.25 Time Delay 4311 24-t(V/f=1.30) 0 .. 20000 sec 19 sec 24 V/f = 1.30 Time Delay 4312 24-t(V/f=1.35) 0 .. 20000 sec 13 sec 24 V/f = 1.35 Time Delay 4313 24-t(V/f=1.40) 0 .. 20000 sec 10 sec 24 V/f = 1.40 Time Delay 4314 24 T COOL DOWN 0 .. 20000 sec 3600 sec 24 Time for Cooling Down
2.8.4

Settings

Information List

ON
OFF 24 Overexcit. Protection (Volt/
Hertz)
No.
5353 >BLOCK 24 SP >BLOCK 24 5357 >24 RM th.repl. SP >24 Reset memory of thermal replica V/f 5361 24 OFF OUT 24 is swiched OFF 5362 24 BLOCKED OUT 24 is BLOCKED 5363 24 ACTIVE OUT 24 is ACTIVE 5367 24 warn OUT 24 V/f warning element 5369 24 RM th. repl. OUT 24 Reset memory of thermal replica V/f 5370 24-1 picked up OUT 24-1 V/f> picked up 5371 24-2 TRIP OUT 24-2 TRIP of V/f>> element 5372 24 th.TRIP OUT 24 TRIP of th. element 5373 24-2 picked up OUT 24-2 V/f>> picked up
Information Type of
Informa­tion
Comments
SIPROTEC 4, 7RW80, Manual 95 C53000-G1140-C233-4, Edition 07.2018
Functions

2.9 Jump of Voltage Vector

2.9
2.9.1
Frequency Behaviour on Load Shedding
Jump of Voltage Vector
Consumers with their own generating plant, for example, feed power directly into a network. The incoming feeder line is usually the technical and legal ownership boundary between the network operator and these consumers/ producers. A failure of the input feeder line, for example, due to a three-pole automatic reclosure, can result in a deviation of the voltage or frequency at the feeding generator which is a function of the overall power balance. When the incoming feeder line is switched on again after the dead time, asynchronous condi­tions may prevail that cause damage to the generator or the gear train between generator and drive.
One way to identify an interruption of the incoming feeder is to monitor the phase angle in the voltage. If the incoming feeder fails, the abrupt current interruption causes a phase angle jump in the voltage. This jump is detected by means of a delta process. As soon as a preset threshold is exceeded, an opening command for the generator or bus-tie coupler circuit-breaker is issued.
This means that the vector jump function is mainly used for network decoupling.

Functional Description

The following figure shows the evolution of the frequency when a load is disconnected from a generator. Opening of the generator circuit breaker causes a phase angle jump that can be observed in the frequency measurement as a frequency jump. The generator is accelerated in accordance with the power system condi­tions.
[veraenderung-der-frequenz-nach-lastabschaltg-020904-ho, 1, en_US]
Figure 2-31
Measuring principle
For a three phase voltage connection, the vector of the positive sequence system voltage is calculated . For a single-phase connection, the connected single-phase voltage is evaluated. The phase angle change of the voltage vector is determined over a delta interval of 2 cycles. The presence of a phase angle jump indicates an abrupt change of current flow. The basic principle is shown in Figure 2-32. The diagram on the left shows the
96 SIPROTEC 4, 7RW80, Manual
Change of the Frequency after Disconnection of a Load (Fault recording with the SIPROTEC 4 device – the figure shows the deviation from the nominal frequency)
C53000-G1140-C233-4, Edition 07.2018
Functions
2.9 Jump of Voltage Vector
steady state, and the diagram on the right the vector change following a load shedding. The vector jump is clearly visible.
[spannungszeiger-nach-entlastung-020904-ho, 1, en_US]
Figure 2-32 Voltage Vector Following Load Shedding
The function features a number of additional measures to avoid spurious tripping, such as:
Correction of steady-state deviations from rated frequency
Frequency operating range limited to f
Detection of internal scanning frequency changeover (Scanning frequency adjustment)
Minimum voltage for enabling
Blocking on voltage connection or disconnection
Nom
± 3 Hz
Logic
The logic is shown in Figure 2-33. The phase angle comparison determines the angle difference, and compares it with the set value. If this value is exceeded, the vector jump is stored in a RS flip-flop. Trippings can be delayed by the associated time delay.
The stored pickup can be reset via a binary input, or automatically by a timer (address 4604 T RESET). The vector jump function becomes ineffective on exiting the admissible frequency band. The same applies for
the voltage. In such a case the limiting parameters are V MIN and V MAX. If the frequency or voltage range is not maintained, the logic generates a logical 1, and the reset input is
continuously active. The result of the vector jump measurement is suppressed. If, for instance, the voltage is connected, and the frequency range is correct, the logical 1 changes to 0. The timer T BLOCK with reset delay keeps the reset input active for a certain time, thus preventing a pickup caused by the vector jump function.
If a short-circuit causes the voltage to drop abruptly to a low value, the reset input is immediately activated to block the function. The vector jump function is thus prevented from causing a trip.
SIPROTEC 4, 7RW80, Manual 97 C53000-G1140-C233-4, Edition 07.2018
Functions
2.9 Jump of Voltage Vector
[logikdiagramm-der-vektorsprungerfassung-020827-ho, 1, en_US]
Figure 2-33
2.9.2

Setting Notes

General
The vector jump protection is only effective and available if address 146 VECTOR JUMP is set to Enabled during configuration.
Under address 4601 VECTOR JUMP the function can be turned ON or OFF.
Pickup Values
The value to be set for the vector jump (address 4602 DELTA PHI) depends on the feed and load conditions. Abrupt active power changes cause a jump of the voltage vector. The value to be set must be established in accordance with the particular power system. This can be done on the basis of the simplified equivalent circuit of the diagram “Voltage Vector Following Load Shedding” in the Functional Description section, or using network calculation software.
If a setting is too sensitive, the protection function is likely to perform a network decoupling every time loads are connected or disconnected. Therefore the default setting is 10°.
The admissible voltage operating range can be set at addresses 4605 for V MIN and 4606 for V MAX. The setting values for V MIN and V MAX always refer to phase-phase voltages. With a single-phase connection they refer to the phase-to-ground voltage of the selected connection. Setting range limits are to some extent a matter of the utility's policy. The value for V MIN should be below the admissible level of short voltage dips for which network decoupling is desired. The default setting is 80 % of the nominal voltage. For V MAX the maximum admissible voltage must be selected. This will be in most cases 130 % of the nominal voltage.
Logic diagram of the vector jump detection
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Time Delays
Functions
2.9 Jump of Voltage Vector
The time delay T DELTA PHI (address 4603) should be left at zero, unless you wish to transmit the trip indi­cation with a delay to a logic (CFC), or to leave enough time for an external blocking to take effect.
After expiry of the timer T RESET (address 4604), the protection function is automatically reset. The reset time depends on the decoupling policy. It must have expired before the circuit breaker is reclosed. Where the automatic reset function is not used, the timer is set to ∞. The reset signal must come in this case from the binary input (circuit breaker auxiliary contact).
The timer T BLOCK with reset delay (address 4607) helps to avoid overfunctioning when voltages are connected or disconnected. Normally the default setting need not be changed. Any change can be performed with the DIGSI communication software (advanced parameters). It must be kept in mind that T BLOCK should not be set less than the measuring window for vector jump measurement (150 ms).
2.9.3
Addr. Parameter Setting Options Default Setting Comments
4601 VECTOR JUMP OFF
4602 DELTA PHI 2 .. 30 ° 10 ° Jump of Phasor DELTA PHI 4603 T DELTA PHI 0.00 .. 60.00 sec 0.00 sec T DELTA PHI Time Delay 4604 T RESET 0.10 .. 60.00 sec 5.00 sec Reset Time after Trip 4605A V MIN 10.0 .. 125.0 V 80.0 V Minimal Operation Voltage V MIN 4606A V MAX 10.0 .. 170.0 V 130.0 V Maximal Operation Voltage V MAX 4607A T BLOCK 0.00 .. 60.00 sec 0.15 sec Time Delay of Blocking
2.9.4
No.
5581 >VEC JUMP block SP >BLOCK Vector Jump 5582 VEC JUMP OFF OUT Vector Jump is switched OFF 5583 VEC JMP BLOCKED OUT Vector Jump is BLOCKED 5584 VEC JUMP ACTIVE OUT Vector Jump is ACTIVE 5585 VEC JUMP Range OUT Vector Jump not in measurement range 5586 VEC JUMP pickup OUT Vector Jump picked up 5587 VEC JUMP TRIP OUT Vector Jump TRIP

Settings

Addresses which have an appended “A” can only be changed with DIGSI, under “Additional Settings”.
OFF Jump of Voltage Vector
ON

Information List

Information Type of
Informa­tion
Comments
SIPROTEC 4, 7RW80, Manual 99 C53000-G1140-C233-4, Edition 07.2018
Functions

2.10 Phase Rotation

2.10
2.10.1
General
Logic
Phase Rotation
A phase rotation function via binary input and parameter is implemented in 7RW80 devices.
Applications
Phase rotation ensures that all protective and monitoring functions operate correctly even with anti-
clockwise rotation, without the need for two phases to be reversed.

Functional Description

Various functions of the 7RW80 only operate correctly if the phase rotation of the voltages is known. Among these functions are undervoltage protection (based only on positive sequence voltages) and measured value monitors.
If an "acb" phase rotation is normal, the appropriate setting is made during configuration of the Power System Data.
If the phase rotation can change during operation (e.g. the direction of a motor must be routinely changed), then a changeover signal at the routed binary input for this purpose is sufficient to inform the protective relay of the phase rotation reversal.
Phase rotation is permanently established at address 209 PHASE SEQ. (Power System Data). Via the exclu­sive- OR gate the binary input
>Reverse Rot.
inverts the sense of the phase rotation applied with setting.
[dw_meldelogikdrehfeldumschaltung, 1, en_US]
Figure 2-34 Message logic of the phase rotation reversal
Influence on Protective and Monitoring Functions
The swapping of phases directly impacts the calculation of positive and negative sequence quantities, as well as phase-to-phase voltages via the subtraction of one phase-to-ground voltage from another and vice versa. Therefore, this function is vital so that phase detection messages, fault values, and operating measurement values are not correct. As stated before, this function influences the voltage protection, flexible protection functions and some of the monitoring functions that issue messages if the defined and calculated phase rota­tions do not match.
2.10.2
Setting the Function Parameter
100 SIPROTEC 4, 7RW80, Manual

Setting Notes

The normal phase sequence is set at 209 (see Section 2.1.3 Power System Data 1). If, on the system side, phase rotation is reversed temporarily, then this is communicated to the protection device using the binary
>Reverse Rot.
input
(5145).
C53000-G1140-C233-4, Edition 07.2018
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