PCS-931 Line Differential Relay Instruction Manual
NR Electric Co., Ltd.
Preface
Preface Introduction This guide and the relevant operating or service manual documentation for the equipment provide full information on safe handling, commissioning and testing of this equipment. Documentation for equipment ordered from NR is dispatched separately from manufactured goods and may not be received at the same time. Therefore, this guide is provided to ensure that printed information normally present on equipment is fully understood by the recipient. Before carrying out any work on the equipment, the user should be familiar with the contents of this manual, and read relevant chapter carefully. This chapter describes the safety precautions recommended when using the equipment. Before installing and using the equipment, this chapter must be thoroughly read and understood.
Health and Safety The information in this chapter of the equipment documentation is intended to ensure that equipment is properly installed and handled in order to maintain it in a safe condition. When electrical equipment is in operation, dangerous voltages will be present in certain parts of the equipment. Failure to observe warning notices, incorrect use, or improper use may endanger personnel and equipment and cause personal injury or physical damage. Before working in the terminal strip area, the equipment must be isolated. Proper and safe operation of the equipment depends on appropriate shipping and handling, proper storage, installation and commissioning, and on careful operation, maintenance and servicing. For this reason, only qualified personnel may work on or operate the equipment. Qualified personnel are individuals who:
Are familiar with the installation, commissioning, and operation of the equipment and of the system to which it is being connected;
Are able to safely perform switching operations in accordance with accepted safety engineering practices and are authorized to energize and de-energize equipment and to isolate, ground, and label it;
Are trained in the care and use of safety apparatus in accordance with safety engineering practices;
Are trained in emergency procedures (first aid).
Instructions and Warnings The following indicators and standard definitions are used: PCS-931 Line Differential Relay
i Date: 2014-02-24
Preface
DANGER! It means that death, severe personal injury, or considerable equipment damage will occur if safety precautions are disregarded. WARNING! It means that death, severe personal, or considerable equipment damage could occur if safety precautions are disregarded. CAUTION! It means that light personal injury or equipment damage may occur if safety precautions are disregarded. This particularly applies to damage to the device and to resulting damage of the protected equipment. WARNING! The firmware may be upgraded to add new features or enhance/modify existing features, please make sure that the version of this manual is compatible with the product in your hand. WARNING! During operation of electrical equipment, certain parts of these devices are under high voltage. Severe personal injury or significant equipment damage could result from improper behavior. Only qualified personnel should work on this equipment or in the vicinity of this equipment. These personnel must be familiar with all warnings and service procedures described in this manual, as well as safety regulations. In particular, the general facility and safety regulations for work with high-voltage equipment must be observed. Noncompliance may result in death, injury, or significant equipment damage. DANGER! Never allow the current transformer (CT) secondary circuit connected to this equipment to be opened while the primary system is live. Opening the CT circuit will produce a dangerously high voltage. WARNING!
Exposed terminals
Do not touch the exposed terminals of this equipment while the power is on, as the high voltage generated is dangerous
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PCS-931 Line Differential Relay Date: 2014-02-24
Preface
Residual voltage
Hazardous voltage can be present in the DC circuit just after switching off the DC power supply. It takes a few seconds for the voltage to discharge. CAUTION!
Earth
The earthing terminal of the equipment must be securely earthed
Operating environment
The equipment must only be used within the range of ambient environment detailed in the specification and in an environment free of abnormal vibration.
Ratings
Before applying AC voltage and current or the DC power supply to the equipment, check that they conform to the equipment ratings.
Printed circuit board
Do not attach and remove printed circuit boards when DC power to the equipment is on, as this may cause the equipment to malfunction.
External circuit
When connecting the output contacts of the equipment to an external circuit, carefully check the supply voltage used in order to prevent the connected circuit from overheating.
Connection cable
Carefully handle the connection cable without applying excessive force.
Copyright © 2014 NR. All rights reserved. We reserve all rights to this document and to the information contained herein. Improper use in particular reproduction and dissemination to third parties is strictly forbidden except where expressly authorized. The information in this manual is carefully checked periodically, and necessary corrections will be included in future editio ns. If nevertheless any errors are detected, suggestions for correction or improvement are greatly appreciated. We reserve the rights to make technical improvements without notice.
NR ELECTRIC CO., LTD.
Tel: +86-25-87178888,
Fax: +86-25-87178999
69 Suyuan Avenue. Jiangning, Nanjing 211102, China
Website: www.nrelect.com, www.nari-relays.com
Version: R1.07
PCS-931 Line Differential Relay
iii Date: 2014-02-24
Preface
Documentation Structure The manual provides a functional and technical description of this relay and a comprehensive set of instructions for the relay’s use and application. All contents provided by this manual are summarized as below:
1 Introduction Briefly introduce the application, functions and features about this relay.
2 Technical Data Introduce the technical data about this relay, such as electrical specifications, mechanical specifications, ambient temperature and humidity range, communication port parameters, type tests, setting ranges and accuracy limits and the certifications that our products have passed.
3 Operation Theory Introduce a comprehensive and detailed functional description of all protective elements.
4 Supervision Introduce the automatic self-supervision function of this relay.
5 Management Introduce the management function (measurement, recording and remote control) of this relay.
6 Hardware Introduce the main function carried out by each plug-in module of this relay and providing the definition of pins of each plug-in module.
7 Settings List settings including system settings, communication settings, label settings, logic links and etc., and some notes about the setting application.
8 Human Machine Interface Introduce the hardware of the human machine interface (HMI) module and a detailed guide for the user how to use this relay through HMI. It also lists all the information which can be view through HMI, such as settings, measurements, all kinds of reports etc.
9 Configurable Function Introduce configurable function of the device and all configurable signals are listed.
10 Communication Introduce the communication port and protocol which this relay can support, IEC60970-5-103, IEC61850 and DNP3.0 protocols are introduced in details.
11 Installation iv
PCS-931 Line Differential Relay Date: 2014-02-24
Preface
Introduce the recommendations on unpacking, handling, inspection and storage of this relay. A guide to the mechanical and electrical installation of this relay is also provided, incorporating earthing recommendations. A typical wiring connection to this relay is indicated.
12 Commissioning Introduce how to commission this relay, comprising checks on the calibration and functionality of this relay.
13 Maintenance A general maintenance policy for this relay is outlined.
14 Decommissioning and Disposal A general decommissioning and disposal policy for this relay is outlined.
15 Manual Version History List the instruction manual version and the modification history records.
Typographic and Graphical Conventions 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:
&
AND gate ≥1
OR gate
Comparator BI
SET
EN
Binary signal via opto-coupler I>
Input signal from comparator with setting
Input signal of logic setting for function enabling
PCS-931 Line Differential Relay
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Preface SIG
Input of binary signal except those signals via opto-coupler
XXX
Output signal
Timer t t
Timer (optional definite-time or inverse-time characteristic) 10ms
0ms
Timer [delay pickup (10ms), delay dropoff (0ms), non-settable] [XXX]
0ms
Timer (delay pickup, settable) 0ms
[XXX]
Timer (delay dropoff, settable) [XXX]
[XXX]
Timer (delay pickup, delay dropoff, settable) IDMT
Timer (inverse-time characteristic)
---xxx is the symbol
Symbol Corresponding Relationship Basic
Example
A, B, C
L1, L2, L3
Ia, Ib, Ic, I0
IL1, IL2, IL3, IN
AN, BN, CN
L1N, L2N, L3N
Ua, Ub, Uc
VL1, VL2, VL3
ABC
L123
Uab, Ubc, Uca
VL12, VL23, VL31
U (voltage)
V
U0, U1, U2
VN, V1, V2
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PCS-931 Line Differential Relay Date: 2014-02-24
1 Introduction
1 Introduction Table of Contents 1 Introduction ....................................................................................... 1-a 1.1 Application....................................................................................................... 1-1 1.2 Function ........................................................................................................... 1-3 1.3 Features ........................................................................................................... 1-6
List of Figures Figure 1.1-1 Typical application of PCS-931 ............................................................................. 1-1 Figure 1.1-2 Functional diagram of PCS-931............................................................................ 1-2
PCS-931 Line Differential Relay
1-a Date: 2013-12-27
1 Introduction
PCS-931 Line Differential Relay
1-b Date: 2013-12-27
1 Introduction
1.1 Application PCS-931 is a digital line differential protection with the main and back-up protection functions, which is designed for overhead line or cables and hybrid transmission lines of various voltage levels.
52
52
PCS-931
Optical fibre channel
PCS-931
Communication channel via direct dedicated fibre or MUX
Figure 1.1-1 Typical application of PCS-931
Main protection of PCS-931 comprises current differential protection which can clear any internal fault instantaneously for the whole line. DPFC distance protection can perform extremely high speed operation for close-up faults. There is direct transfer trip (DTT) feature incorporated in the relay. PCS-931 also includes distance protection (3 forward zones and 1 reverse zone distance protection with selectable mho or quadrilateral characteristic), 4 stages directional earth fault protection, 4 stages directional phase overcurrent protection, 2 stages voltage protection (under/over voltage protection), 4 stages frequency protection (under/over frequency protection), broken conductor protection, reverse power protection, pole discrepancy protection, breaker failure protection, thermal overload protection, and dead zone protection etc. Morever, a backup overcurrent and earth fault protection will be automatically enabled when VT circuit fails. In addition, stub overcurrent protection is provided for one and a half breakers arrangement when transmission line is put into maintenance. PCS-931 has selectable mode of single-phase tripping or three-phase tripping and configurable auto-reclosing mode for 1-pole, 3-poles and 1/3-pole operation. PCS-931 with appropriate selection of integrated protection functions can be applied for various voltage levels and primary equipment such as cables, overhead lines, interconnectors and transformer feeder, etc. It also supports configurable binary inputs, binary outputs, LEDs and IEC 61850 protocol.
PCS-931 Line Differential Relay
1-1 Date: 2013-12-27
1 Introduction BUS
52
81 87
21D
21
67G
67P
50G
50P
51G
51P
50GVT
50PVT
50BF
49
46BC
32R
62PD
FR 59 FL
Data Transmitt/Receive
50DZ
27
50STB (Only for one and a half breakers arrangement) SOTF
25
79
LINE
Figure 1.1-2 Functional diagram of PCS-931 No.
Function
ANSI
1
Current differential protection
87
2
DPFC distance protection
21D
3
Distance protection
21
4
Earth fault protection
67G
5
Definite-time earth-fault protection
50G
6
Inverse-time earth-fault protection
51G
8
Phase overcurrent protection
67P
9
Definite-time phase overcurrent protection
50P
10
Inverse-time phase overcurrent protection
51P
11
Overvoltage protection
59
12
Undervoltage protection
27
13
Frequency protection
81
14
Broken conductor protection
46BC
15
Reverse power protection
32R
16
Breaker failure protection
50BF
17
Thermal overload protection
49
18
Stub overcurrent protection
50STB
19
Dead zone protection
50DZ
20
Pole discrepancy protection
62PD
21
Switch onto fault
SOTF
22
Phase overcurrent protection when VT circuit failure
50PVT
23
Earth fault protection when VT circuit failure
50GVT
24
Synchronism check
25
25
Automatic reclosure
79
PCS-931 Line Differential Relay
1-2 Date: 2013-12-27
1 Introduction 26
Fault recorder
FR
27
Fault location
FL
1.2 Function 1.
Protection Function
Current differential protection (87)
Deviation of Power Frequency Component (DPFC) current differential element
Steady-state current differential element
Neutral current differential element
Distance protection
Three zones forward phase-to-ground distance elements (mho or quadrilateral characteristic)
One zone reverse phase-to-ground distance element (mho or quadrilateral characteristic)
Three zones forward phase-to-phase distance elements (mho or quadrilateral characteristic)
One zone reverse phase-to-phase distance element (mho or quadrilateral characteristic)
Load encroachment for mho and quadrilateral characteristic distance element
Power swing blocking releasing, selectable for each of above mentioned zones
Deviation of Power Frequency Component (DPFC) distance protection
Current protection
Four stages phase overcurrent protection, selectable time characteristic (definite-time or inverse-time) and directionality (forward direction, reverse direction or non-directional)
Four stages directional earth fault protection, selectable time characteristic (definite-time or inverse-time) and directionality (forward direction, reverse direction or non-directional)
Breaker failure protection
Optional instantaneously re-tripping
One stage with two delay timers
Thermal overload protection
Stub overcurrent protection
Dead zone protection
Pole discrepancy protection
Broken conductor protection
PCS-931 Line Differential Relay
1-3 Date: 2013-12-27
1 Introduction
Reverse power protection
Switch onto fault (SOTF)
Via distance measurement elements
Via dedicated earth fault element
Backup protection when VT circuit failure
Phase overcurrent protection when VT circuit failure
Earth fault protection when VT circuit failure
Voltage protection
Two stages overvoltage protection
Two stages undervoltage protection
Frequency protection
Four stages overfrequency protection
Four stages underfrequency protection
f/dt block criterion for underfrequency protection
Control function
Synchro-checking
Automatic reclosure (single shot or multi-shot (max. 4) for 1-pole AR and 3-pole AR)
Communication scheme of current differential protection
Direct optical link
Connection to a communication network, support G.703 and C37.94 protocol
Dual-channels redundancy
2.
Measurement and control function
Remote control (open and closing)
Synchronism check for remote and manual closing (only for one circuit breaker)
Energy metering (active and reactive energy are calculated in import respectively export direction)
3.
Logic
User programmable logic
4.
Additional function
Fault location
PCS-931 Line Differential Relay
1-4 Date: 2013-12-27
1 Introduction
Fault phase selection
Parallel line compensation for fault location
VT circuit supervision
CT circuit supervision
Self diagnostic
DC power supply supervision
Event Recorder including 1024 disturbance records, 1024 binary events, 1024 supervision events, 256 control logs and 1024 device logs.
Disturbance recorder including 32 disturbance records with waveforms (The file format of disturbance recorder is compatible with international COMTRADE file.)
Four kinds of clock synchronization methods
Conventional
PPS (RS-485): Pulse per second (PPS) via RS-485 differential level
IRIG-B (RS-485): IRIG-B via RS-485 differential level
PPM (DIN): Pulse per minute (PPM) via the optical coupler
PPS (DIN): Pulse per second (PPS) via the optical coupler
SAS
SNTP (PTP): Unicast (point-to-point) SNTP mode via Ethernet network
SNTP (BC): Broadcast SNTP mode via Ethernet network
Message (IEC103): Clock messages through IEC103 protocol
Advanced
IEEE1588: Clock message via IEEE1588
IRIG-B (Fiber): IRIG-B via optical-fibre interface
PPS (Fiber) PPS: Pulse per second (PPS) via optical-fibre interface
NoTimeSync
5.
Monitoring
Number of circuit breaker operation (single-phase tripping, three-phase tripping and reclosing)
Channel status
Frequency
6.
Communication
PCS-931 Line Differential Relay
1-5 Date: 2013-12-27
1 Introduction
Optional 2 RS-485 communication rear ports conform to IEC 60870-5-103 protocol
1 RS-485 communication rear ports for clock synchronization
Optional 2 or 4 Ethernet ports (depend on the chosen type of MON plug-in module) conform to IEC 61850 protocol, DNP3.0 protocol or IEC 60870-5-103 protocol over TCP/IP
Optional 2 Ethernet ports via optic fiber (ST interface) conform to IEC 61850 protocol, DNP3.0 protocol or IEC 60870-5-103 protocol over TCP/IP
GOOSE and SV communication function (optional NET-DSP plug-in module)
7.
User Interface
Friendly HMI interface with LCD and 9-button keypad on the front panel.
1 front multiplex RJ45 port for testing and setting
1 RS-232 or RS-485 rear ports for printer
Language switchover—English+ selected language
Auxiliary software—PCS-Explorer
1.3 Features
The intelligent device integrated with protection, control and monitor provides powerful protection function, flexible protection configuration, user programmable logic and configurable binary input and binary output, which can meet with various application requirements.
High-performance hardware platform and modularized design, MCU (management control unit)+DSP (digital signal processor). MCU manages general fault detector element and DSP manages protection and metering. Their data acquisition system is completely independent in electronic circuit. DC power supply of output relay is controlled by the operation of fault detector element operates, this prevents maloperation due to error from ADC or damage of any apparatus.
Fast fault clearance for faults within the protected line, the operating time is less than 10 ms for close-up faults, less than 15ms for faults in the middle of protected line and less than 25ms for remote end faults.
The unique DPFC distance element integrated in the protective device provides extremely high speed operation and insensitive to power swing.
Self-adaptive floating threshold which only reflects deviation of power frequency component improves the protection sensitivity and stability under the condition of load fluctuation and system disturbance.
Advanced and reliable power swing blocking releasing feature which ensure distance protection operate correctly for internal fault during power swing and prevent distance protection from maloperation during power swing PCS-931 Line Differential Relay
1-6 Date: 2013-12-27
1 Introduction
Flexible automatic reclosure supports various initiation modes and check modes
Multiple setting groups with password protection and setting value saved permanently before modification
Powerful PC tool software can fulfill protection function configuration, modify setting and waveform analysis.
PCS-931 Line Differential Relay
1-7 Date: 2013-12-27
1 Introduction
PCS-931 Line Differential Relay
1-8 Date: 2013-12-27
2 Technical Data
2 Technical Data Table of Contents 2 Technical Data ................................................................................... 2-a 2.1 Electrical Specifications ................................................................................. 2-1 2.1.1 AC Current Input .................................................................................................................. 2-1 2.1.2 AC Voltage Input .................................................................................................................. 2-1 2.1.3 Power Supply ....................................................................................................................... 2-1 2.1.4 Binary Input .......................................................................................................................... 2-1 2.1.5 Binary Output ....................................................................................................................... 2-2
2.2 Mechanical Specifications.............................................................................. 2-2 2.3 Ambient Temperature and Humidity Range .................................................. 2-3 2.4 Communication Port ....................................................................................... 2-3 2.4.1 EIA-485 Port ........................................................................................................................ 2-3 2.4.2 Ethernet Port ........................................................................................................................ 2-3 2.4.3 Optical Fibre Port ................................................................................................................. 2-3 2.4.4 Print Port .............................................................................................................................. 2-4 2.4.5 Clock Synchronization Port ................................................................................................. 2-4
2.5 Type Tests ........................................................................................................ 2-5 2.5.1 Environmental Tests............................................................................................................. 2-5 2.5.2 Mechanical Tests ................................................................................................................. 2-5 2.5.3 Electrical Tests ..................................................................................................................... 2-5 2.5.4 Electromagnetic Compatibility ............................................................................................. 2-5
2.6 Certifications ................................................................................................... 2-6 2.7 Terminals ......................................................................................................... 2-6 2.8 Measurement Scope and Accuracy ............................................................... 2-6 2.9 Management Function .................................................................................... 2-7 2.9.1 Control Performance............................................................................................................ 2-7
PCS-931 Line Differential Relay
2-a Date: 2014-02-24
2 Technical Data
2.9.2 Clock Performance .............................................................................................................. 2-7 2.9.3 Fault and Disturbance Recording ........................................................................................ 2-7 2.9.4 Binary Input Signal............................................................................................................... 2-7
2.10 Protective Functions..................................................................................... 2-7 2.10.1 Fault Detector .................................................................................................................... 2-7 2.10.2 Current Differential Protection ........................................................................................... 2-8 2.10.3 Distance Protection ............................................................................................................ 2-8 2.10.4 Phase Overcurrent Protection ........................................................................................... 2-8 2.10.5 Earth Fault Protection ........................................................................................................ 2-8 2.10.6 Overvoltage Protection ...................................................................................................... 2-8 2.10.7 Undervoltage Protection .................................................................................................... 2-9 2.10.8 Overfrequency Protection .................................................................................................. 2-9 2.10.9 Underfrequency Protection ................................................................................................ 2-9 2.10.10 Breaker Failure Protection ............................................................................................... 2-9 2.10.11 Thermal Overload Protection ........................................................................................... 2-9 2.10.12 Stub Overcurrent Protection .......................................................................................... 2-10 2.10.13 Dead Zone Protection .................................................................................................... 2-10 2.10.14 Pole Discrepancy Protection ......................................................................................... 2-10 2.10.15 Broken Conductor Protection ........................................................................................ 2-10 2.10.16 Reverse Power Protection ............................................................................................. 2-10 2.10.17 Auto-reclosing .................................................................................................................2-11 2.10.18 Transient Overreach .......................................................................................................2-11 2.10.19 Fault Locator ...................................................................................................................2-11
PCS-931 Line Differential Relay
2-b Date: 2014-02-24
2 Technical Data
2.1 Electrical Specifications 2.1.1 AC Current Input Phase rotation
ABC
Nominal frequency (fn)
50Hz, 60Hz
Rated current (In)
1A
Linear to
5A
0.05In~40In (It should measure current without beyond full scale against 20 times of related current and value of DC offset by 100%.)
Thermal withstand -continuously
4In
-for 10s
30In
-for 1s
100In
-for half a cycle
250In
Burden
< 0.15VA/phase @In
Number
Up to 7 current input according to various applications
< 0.25VA/phase @In
2.1.2 AC Voltage Input Phase rotation
ABC
Nominal frequency (fn)
50Hz, 60Hz
Rated voltage (Un)
100V~130V
Linear to
1V~170V
Thermal withstand -continuously
200V
-10s
260V
-1s
300V
Burden at rated
< 0.20VA/phase @Un
Number
Up to 6 voltage input according to various applications
2.1.3 Power Supply Standard
IEC 60255-11:2008
Rated voltage
110Vdc/125Vdc/220Vdc/250Vdc
Permissible voltage range
88~300Vdc
Permissible AC ripple voltage
≤15% of the nominal auxiliary voltage
Burden Quiescent condition
<30W
Operating condition
<35W
2.1.4 Binary Input Rated voltage
24Vdc
48Vdc
Rated current drain
1.2mA
2.4mA
On value
16.8-28.8Vdc
33.6-57.6Vdc
Off value
<12Vdc
<24Vdc
PCS-931 Line Differential Relay
2-1 Date: 2014-02-24
2 Technical Data Maximum permissible voltage
100Vdc
Withstand voltage
2000Vac, 2800Vdc (continuously )
Response time for logic input
≤1ms
Number
Up to 36 binary input according to various hardware configurations
Rated voltage
110Vdc
125Vdc
220Vdc
250Vdc
Rated current drain
1.1mA
1.25mA
2.2mA
2.5mA
On value
77-132Vdc
87.5-150Vdc
154-264Vdc
175-300Vdc
Off value
<55Vdc
<62.5Vdc
<110Vdc
<125Vdc
Maximum permissible voltage
300Vdc
Withstand voltage
2000Vac, 2800Vdc (continuously )
Response time for logic input
≤1ms
Number
Up to 36 binary input according to various hardware configurations
2.1.5 Binary Output Output mode
Potential free contact 8A@380Vac
Continuous carry
8A@250Vdc 8A@125Vdc
Pickup time (Typical)
<8ms (3ms)
Dropoff time
<5ms 0.65A@48Vdc 0.25A@110Vdc
Breaking capacity (L/R=40ms)
0.25A@125Vdc 0.15A@220Vdc 0.15A@250Vdc
Burden Maximal system voltage Test voltage across open contact
300mW 380Vac 250Vdc 1000V RMS for 1min 10A@3s
Short duration current
15A@1s
[email protected] [email protected]
Durability (Loaded contact)
10000 operations
Number
Up to 55 binary output according to various hardware configurations
2.2 Mechanical Specifications Mounting Way
Flush mounted
Chassis color
Silver grey
Weight per device
Approx. 15kg
Chassis material
Aluminum alloy
Location of terminal
Rear panel of the device PCS-931 Line Differential Relay
2-2 Date: 2014-02-24
2 Technical Data Device structure
Plug-in modular type @ rear side, integrated frontplate
Protection class Standard
IEC 60255-1:2009
Front side
IP40
Other sides
IP30
Rear side, connection terminals
IP20
2.3 Ambient Temperature and Humidity Range Standard
IEC 60255-1:2009
Operating temperature
-40°C to +70°C (Readability of display may be impaired below -20°C)
Transport and storage temperature range
-40°C to +70°C
Permissible humidity
5%-95%, without condensation
Pollution degree
Ⅱ
Altitude
<3000m
2.4 Communication Port 2.4.1 EIA-485 Port Baud rate
4.8kbit/s, 9.6kbit/s, 19.2kbit/s, 38.4kbit/s, 57.6kbit/s, 115.2kbit/s
Protocol
IEC 60870-5-103:1997
Maximal capacity
32
Transmission distance
<500m
Safety level
Isolation to ELV level
Twisted pair
Screened twisted pair cable
2.4.2 Ethernet Port Connector type
RJ-45
ST (Multi mode)
Transmission rate
100Mbits/s
Transmission standard
100Base-TX
100Base-FX
Transmission distance
<100m
<2km (1310nm)
Protocol
IEC 60870-5-103:1997, DNP 3.0 or IEC 61850
Safety level
Isolation to ELV level
2.4.3 Optical Fibre Port 2.4.3.1 For Station Level Characteristic
Glass optical fiber
Connector type
ST
Fibre type
Multi mode
Transmission distance
<2km
Wave length
1310nm
Transmission power
Min. -20.0dBm
PCS-931 Line Differential Relay
2-3 Date: 2014-02-24
2 Technical Data Minimum receiving power
Min. -30.0dBm
Margin
Min +3.0dB
2.4.3.2 For Process Level Characteristic
Glass optical fiber
Connector type
LC
Fibre type
Multi mode
Transmission distance
<2km
Wave length
1310nm
Transmission power
Min. -20.0dBm
Minimum receiving power
Min. -30.0dBm
Margin
Min +3.0dB
2.4.3.3 For Pilot Channel Characteristic
Glass optical fiber
Connector type
FC
ST
Fibre type
Single mode
Multi mode
Wave length
1310nm
1550nm
850nm
Transmission distance
Max.40km
Max.100km
Max.2km
Transmission power
-13.0±3.0 dBm
-5.0 dBm±3.0 dBm
-12dBm~-20 dBm
Minimum receiving power
Min.-37 dBm
Min.-36 dBm
Min. -30.0dBm
Optical overload point
Min.-3 dBm
Min.-3 dBm
Min.-8 dBm
2.4.3.4 For Synchronization Port Characteristic
Glass optical fiber
Connector type
ST
Fibre type
Multi mode
Wave length
820nm
Minimum receiving power
Min. -25.0dBm
Margin
Min +3.0dB
2.4.4 Print Port Type
RS-232
Baud Rate
4.8kbit/s, 9.6kbit/s, 19.2kbit/s, 38.4kbit/s, 57.6kbit/s, 115.2kbit/s
Printer type
EPSON 300K printer
Safety level
Isolation to ELV level
®
2.4.5 Clock Synchronization Port Type
RS-485
Transmission distance
<500m
Maximal capacity
32
Timing standard
PPS, IRIG-B
Safety level
Isolation to ELV level PCS-931 Line Differential Relay
2-4 Date: 2014-02-24
2 Technical Data
2.5 Type Tests 2.5.1 Environmental Tests Dry cold test
IEC60068-2-1:2007
Dry heat test
IEC60068-2-2:2007
Damp heat test, cyclic
IEC60068-2-30:2005
2.5.2 Mechanical Tests Vibration
IEC 60255-21-1:1988 Class Ⅰ
Shock and bump
IEC 60255-21-2:1988 Class Ⅰ
2.5.3 Electrical Tests Standard
IEC 60255-27:2005
Dielectric tests
Test voltage 2kV, 50Hz, 1min
Standard
IEC 60255-5:2000
Impulse voltage tests
Test voltage 5kV
Overvoltage category
Ⅲ
Insulation
resistance
measurements
Isolation resistance >100MΩ@500VDC
2.5.4 Electromagnetic Compatibility IEC 60255-22-1:2007 1MHz burst disturbance test
Common mode: class Ⅲ 2.5kV Differential mode: class Ⅲ 1.0kV IEC60255-22-2:2008 class Ⅳ
Electrostatic discharge test
For contact discharge: 8kV For air discharge: 15kV IEC 60255-22-3:2007 class Ⅲ Frequency sweep Radiated amplitude-modulated 10V/m (rms), f=80~1000MHz
Radio frequency interference tests
Spot frequency Radiated amplitude-modulated 10V/m (rms), f=80MHz/160MHz/450MHz/900MHz Radiated pulse-modulated 10V/m (rms), f=900MHz IEC 60255-22-4:2008
Fast transient disturbance tests
Power supply, I/O, Earth: class Ⅳ, 4kV, 2.5kHz, 5/50ns Communication terminals: class Ⅳ, 2kV, 5kHz, 5/50ns IEC 60255-22-5:2008
Surge immunity test
Power supply, AC input, I/O port: class Ⅳ, 1.2/50us Common mode: 4kV Differential mode: 2kV
PCS-931 Line Differential Relay
2-5 Date: 2014-02-24
2 Technical Data Conducted
RF
Electromagnetic
Disturbance
IEC 60255-22-6:2001 Power supply, AC, I/O, Comm. Terminal: Class Ⅲ , 10Vrms, 150 kHz~80MHz
Power Frequency Magnetic Field
IEC 61000-4-8:2001
Immunity
class Ⅴ, 100A/m for 1min, 1000A/m for 3s IEC 61000-4-9:2001
Pulse Magnetic Field Immunity
class Ⅴ, 6.4/16μs, 1000A/m for 3s
Damped oscillatory magnetic field
IEC 61000-4-10:2001
immunity
class Ⅴ, 100kHz & 1MHz–100A/m
Auxiliary power supply performance
IEC60255-11: 2008
- Voltage dips
Up to 200ms for dips to 40% of rated voltage without reset
-Voltage short interruptions
100ms for interruption without rebooting
2.6 Certifications
ISO9001:2008
ISO14001:2004
OHSAS18001:2007
ISO10012:2003
CMMI L5
EMC: 2004/108/EC, EN50263:1999
Products safety(PS): 2006/95/EC, EN61010-1:2001
2.7 Terminals Connection Type
Wire Size 2
2
Crimp terminals, 1.5mm ~4.0mm lead If using 4.0mm2 lead, only dedicated terminal cable lug provided by NR
AC current
can be adopted. 2
2
2
2
AC voltage
Crimp terminals, 1.0mm ~2.5mm lead
Power supply
Crimp terminals, 1.0mm ~2.5mm lead
Contact I/O
Crimp terminals, 1.0mm2~2.5mm2 lead
Grounding (Earthing) Connection
BVR type, 2.5mm²~6.0mm lead
2
2.8 Measurement Scope and Accuracy Item
Range
Accuracy
Phase range
0°~ 360°
≤±3°
Frequency
fn±3 Hz
≤ 0.02Hz
Currents from protection measurement current transformers PCS-931 Line Differential Relay
2-6 Date: 2014-02-24
2 Technical Data Current
0.05~5.00In
Voltage
0.05~1.50Un
Active power (W)
Reactive power (VAr)
Apparent power (VA)
Energy (Wh)
Energy (VAh)
≤ 2.0% of rating (0.05~1.00In) ≤ 2.0% of applied quantities (1.00~5.00In) ≤ 1.0% of rating (0.05~1.00Un) ≤ 1.0% of applied quantities (1.00~1.50Un)
0.05~1.50Un
≤ 3.0% of rating (0.05~1.00In, 0.05~1.00Un)
0.05~5.00In
≤ 3.0% of applied quantities (1.00~5.00In, 1.00~1.50Un)
0.05~1.50Un
≤ 3.0% of rating (0.05~1.00In, 0.05~1.00Un)
0.05~5.00In
≤ 3.0% of applied quantities (1.00~5.00In, 1.00~1.50Un)
0.05~1.50Un
≤ 3.0% of rating (0.05~1.00In, 0.05~1.00Un)
0.05~5.00In
≤ 3.0% of applied quantities (1.00~5.00In, 1.00~1.50Un)
0.05~1.50Un
≤ 3.0% of rating (0.05~1.00In, 0.05~1.00Un)
0.05~5.00In
≤ 3.0% of applied quantities (1.00~5.00In, 1.00~1.50Un)
0.05~1.50Un
≤ 3.0% of rating (0.05~1.00In, 0.05~1.00Un)
0.05~5.00In
≤ 3.0% of applied quantities (1.00~5.00In, 1.00~1.50Un)
2.9 Management Function 2.9.1 Control Performance Control mode
Local or remote
Accuracy of local control
≤ 1s
Accuracy of remote control
≤ 3s
2.9.2 Clock Performance Real time clock accuracy
≤ 3s/day
Accuracy of GPS synchronization
≤ 1ms
External time synchronization
IRIG-B (200-98), PPS, IEEE1588 or SNTP protocol
2.9.3 Fault and Disturbance Recording Maximum duration
10000 sampled points (24 sampled points per cycle)
Recording position
10 cycles before pickup of trigger element
2.9.4 Binary Input Signal Resolution of binary input signal
≤ 1ms
Binary input mode
Potential-free contact
Resolution of SOE
≤ 2ms
2.10 Protective Functions 2.10.1 Fault Detector 2.10.1.1 DPFC Current Element Setting range
0.050In~30.000In (A)
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
PCS-931 Line Differential Relay
2-7 Date: 2014-02-24
2 Technical Data
2.10.1.2 Residual Current Element Setting range
0.050In~30.000In (A)
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
2.10.1.3 Overvoltage Element Setting range
Un~2Unn (V)
Accuracy
≤2.5% of setting or 0.01Un, whichever is greater
2.10.2 Current Differential Protection Current setting accuracy
≤2.5% of setting or 0.01In, whichever is greater
Time delay accuracy
<5ms
Typical operating time
<25ms
2.10.3 Distance Protection Setting range
(0.000~4Unn)/In (ohm)
Accuracy
≤2.5% of setting or 0.1Ω/In, whichever is greater
Resetting ratio
105%
Time delay
0.000~10.000 (s)
Accuracy
≤1%Setting+30ms
2.10.4 Phase Overcurrent Protection Setting range
0.050In~30.000In (A)
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
Resetting ratio
95%
Time delay
0.000~20.000 (s)
Accuracy (definite-time characteristic)
≤1% of Setting+30ms (at 2 times current setting)
Accuracy (inverse-time characteristic)
≤2.5% operating time or 30ms, whichever is greater (for current between 1.2 and 20 multiples of pickup)
2.10.5 Earth Fault Protection Setting range
0.050In~30.000In (A)
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
Resetting ratio
95%
Time delay
0.000~20.000 (s)
Accuracy (definite-time characteristic)
≤1% of Setting+30ms (at 2 times current setting)
Accuracy (inverse-time characteristic)
≤2.5% operating time or 30ms, whichever is greater (for current between 1.2 and 20 multiples of pickup)
2.10.6 Overvoltage Protection Setting range
Un~2Unn (V)
Accuracy
≤2.5% of setting or 0.01Un, whichever is greater
Resetting ratio
95%
PCS-931 Line Differential Relay
2-8 Date: 2014-02-24
2 Technical Data Time delay
0.000~30.000 (s)
Accuracy (definite-time characteristic)
≤1% of Setting+30ms (at 1.2 times voltage setting) ≤2.5% operating time or 30ms, whichever is greater
Accuracy (inverse-time characteristic)
(for voltage between 1.2 and 2 multiples of pickup)
2.10.7 Undervoltage Protection Setting range
0~Unn (V)
Accuracy
≤2.5% of setting or 0.01Un, whichever is greater
Resetting ratio
105%
Time delay
0.000~30.000 (s)
Accuracy (definite-time characteristic)
≤1%Setting+30ms (at 1.2 times voltage setting) ≤2.5% operating time or 30ms, whichever is greater
Accuracy (inverse-time characteristic)
(for voltage between 0.5 and 0.8 multiples of pickup)
2.10.8 Overfrequency Protection Setting range
50.00~65.00 (Hz)
Accuracy
≤ 0.02Hz
Resetting ratio
95%
Time delay
0.000~100.000 (s)
Accuracy
≤1%Setting+30ms (at 1.2 times frequency setting)
2.10.9 Underfrequency Protection Setting range
45.00~ 60.00 (Hz)
Accuracy
≤ 0.02Hz
Resetting ratio
105%
Time delay
0.000s ~ 100.000 (s)
Accuracy
≤1%Setting+30ms (at 0.8 times frequency setting)
df/dt blocking setting range
0.200~20.000 (Hz/s)
Accuracy
≤ 0.02Hz/s
2.10.10 Breaker Failure Protection Pick-up time
<20ms
Drop-off time
<20ms
Setting range of phase current
0.050In~30.000In (A)
Setting range of zero-sequence current
0.050In~30.000In (A)
Setting range of negative-sequence current
0.050In~30.000In (A)
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
Time delay (first)
0.000~10.000 (s)
Time delay (second)
0.000~10.000 (s)
2.10.11 Thermal Overload Protection Base current setting range
0.050In~30.000In (A)
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
PCS-931 Line Differential Relay
2-9 Date: 2014-02-24
2 Technical Data Line thermal time constant
0.100~100.000 (min)
Thermal overload coefficient for trip
1.000~3.000
Thermal overload coefficient for alarm
1.000~3.000
Resetting ratio
95%
Drop-off time
<30ms ≤2.5% operating time or 30ms, whichever is greater
Time accuracy
(for current between 1.2 and 20 multiples of pickup)
2.10.12 Stub Overcurrent Protection Setting range
0.050In~30.000In (A)
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
Resetting ratio
95%
Time delay
0.000~10.000 (s)
Accuracy
≤1% of Setting+30ms (at 2 times current setting)
2.10.13 Dead Zone Protection Setting range
0.050In~30.000In
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
Resetting ratio
95%
Time delay
0.000~10.000s
Accuracy
≤1%Setting+30ms
2.10.14 Pole Discrepancy Protection Setting range (zero-sequence current)
0.050In~30.000In (A)
Setting range (negative-sequence current)
0.050In~30.000In (A)
Accuracy
≤2.5% of setting or 0.02In, whichever is greater
Resetting ratio
95%
Time delay
0.000~600.000 (s)
Accuracy
≤1% of Setting+30ms (at 2 times current setting)
2.10.15 Broken Conductor Protection Setting range (I2/I1)
0.20~1.00
Accuracy
≤2.5% of setting
Resetting ratio
95%
Time delay
0.000~600.000 (s)
Accuracy
≤1% of Setting+30ms
2.10.16 Reverse Power Protection Setting range
0.100In~50.000In
Accuracy
≤2% of setting or 0.5W, whichever is greater
Resetting ratio
95%
Time delay
0.010~300.000 (s)
Accuracy
≤1% of Setting+30ms PCS-931 Line Differential Relay
2-10 Date: 2014-02-24
2 Technical Data
2.10.17 Auto-reclosing Phase difference setting range
0~89 (Deg)
Accuracy
2.0Deg
Voltage difference setting range
0.02Un~0.8Un (V)
Accuracy
Max(0.01Un, 2.5%)
Frequency difference setting range
0.02~1 (Hz)
Accuracy
0.01Hz
Operating time of synchronism check
≤1%Setting+20ms
Operating time of energizing check
≤1%Setting+20ms
Operating time of auto-reclosing
≤1%Setting+20ms
2.10.18 Transient Overreach ≤2%
Tolerance for all high-speed protection
2.10.19 Fault Locator Accuracy for multi-phase faults with single end feed
< ±2.5%
Tolerance will be higher in case of single-phase fault with high ground resistance.
PCS-931 Line Differential Relay
2-11 Date: 2014-02-24
2 Technical Data
PCS-931 Line Differential Relay
2-12 Date: 2014-02-24
3 Operation Theory
3 Operation Theory Table of Contents 3 Operation Theory .............................................................................. 3-a 3.1 System Parameters ......................................................................................... 3-1 3.1.1 General Application.............................................................................................................. 3-1 3.1.2 Function Description ............................................................................................................ 3-1 3.1.3 Settings ................................................................................................................................ 3-1
3.2 Line Parameters .............................................................................................. 3-1 3.2.1 General Application.............................................................................................................. 3-1 3.2.2 Function Description ............................................................................................................ 3-2 3.2.3 Settings ................................................................................................................................ 3-2
3.3 Circuit Breaker Position Supervision ............................................................ 3-2 3.3.1 General Application.............................................................................................................. 3-2 3.3.2 Function Description ............................................................................................................ 3-2 3.3.3 Function Block Diagram ...................................................................................................... 3-3 3.3.4 I/O Signals ........................................................................................................................... 3-4 3.3.5 Logic .................................................................................................................................... 3-4 3.3.6 Settings ................................................................................................................................ 3-5
3.4 Fault Detector (FD) .......................................................................................... 3-5 3.4.1 Application............................................................................................................................ 3-5 3.4.2 Fault Detector in Fault Detector DSP .................................................................................. 3-5 3.4.3 Protection Fault Detector in Protection Calculation DSP .................................................... 3-8 3.4.4 Function Block Diagram ...................................................................................................... 3-9 3.4.5 I/O Signals ........................................................................................................................... 3-9 3.4.6 Logic .................................................................................................................................... 3-9 3.4.7 Settings .............................................................................................................................. 3-10
3.5 Auxiliary Element .......................................................................................... 3-10
3-a
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.5.1 General Application............................................................................................................ 3-10 3.5.2 Function Description .......................................................................................................... 3-10 3.5.3 Function Block Diagram .................................................................................................... 3-13 3.5.4 I/O Signals ......................................................................................................................... 3-14 3.5.5 Logic .................................................................................................................................. 3-16 3.5.6 Settings .............................................................................................................................. 3-19
3.6 Distance Protection....................................................................................... 3-21 3.6.1 General Application............................................................................................................ 3-21 3.6.2 Function Description .......................................................................................................... 3-21 3.6.3 DPFC Distance Protection ................................................................................................. 3-29 3.6.4 Load Encroachment........................................................................................................... 3-33 3.6.5 Mho Distance Protection.................................................................................................... 3-35 3.6.6 Quadrilateral Distance Protection ...................................................................................... 3-50 3.6.7 Power Swing Detection ..................................................................................................... 3-60 3.6.8 Power Swing Blocking Releasing ...................................................................................... 3-62 3.6.9 Distance SOTF Protection ................................................................................................. 3-67
3.7 Optical Pilot Channel .................................................................................... 3-73 3.7.1 General Application............................................................................................................ 3-73 3.7.2 Function Description .......................................................................................................... 3-73 3.7.3 Function Block Diagram .................................................................................................... 3-78 3.7.4 I/O Signals ......................................................................................................................... 3-79 3.7.5 Logic .................................................................................................................................. 3-79 3.7.6 Settings .............................................................................................................................. 3-80
3.8 Current Differential Protection ..................................................................... 3-80 3.8.1 General Application............................................................................................................ 3-80 3.8.2 Function Description .......................................................................................................... 3-80 3.8.3 Function Block Diagram .................................................................................................... 3-91 3.8.4 I/O Signals ......................................................................................................................... 3-91 3.8.5 Logic .................................................................................................................................. 3-92 3.8.6 Settings .............................................................................................................................. 3-98 3-b
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.9 Current Direction......................................................................................... 3-100 3.9.1 General Application.......................................................................................................... 3-100 3.9.2 Function Description ........................................................................................................ 3-100 3.9.3 Function Block Diagram .................................................................................................. 3-105 3.9.4 I/O Signals ....................................................................................................................... 3-105 3.9.5 Settings ............................................................................................................................ 3-106
3.10 Phase Overcurrent Protection ................................................................. 3-106 3.10.1 General Application........................................................................................................ 3-106 3.10.2 Function Description ...................................................................................................... 3-106 3.10.3 Function Block Diagram ................................................................................................ 3-109 3.10.4 I/O Signals ..................................................................................................................... 3-109 3.10.5 Logic ...............................................................................................................................3-110 3.10.6 Settings ...........................................................................................................................3-110
3.11 Earth Fault Protection ................................................................................ 3-114 3.11.1 General Application .........................................................................................................3-114 3.11.2 Function Description .......................................................................................................3-114 3.11.3 Function Block Diagram ..................................................................................................3-116 3.11.4 I/O Signals .......................................................................................................................3-117 3.11.5 Logic ................................................................................................................................3-117 3.11.6 Settings ...........................................................................................................................3-118
3.12 Overcurrent Protection for VT Circuit Failure......................................... 3-122 3.12.1 General Application........................................................................................................ 3-122 3.12.2 Function Block Diagram ................................................................................................ 3-123 3.12.3 I/O Signals ..................................................................................................................... 3-123 3.12.4 Logic .............................................................................................................................. 3-124 3.12.5 Settings .......................................................................................................................... 3-124
3.13 Residual Current SOTF Protection .......................................................... 3-125 3.13.1 General Application........................................................................................................ 3-125 3.13.2 Function Description ...................................................................................................... 3-125 3.13.3 Function Block Diagram ................................................................................................ 3-125 3-c
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.13.4 I/O Signals ..................................................................................................................... 3-125 3.13.5 Logic .............................................................................................................................. 3-126 3.13.6 Settings .......................................................................................................................... 3-126
3.14 Voltage Protection ..................................................................................... 3-126 3.14.1 Overvoltage Protection .................................................................................................. 3-127 3.14.2 Undervoltage Protection ................................................................................................ 3-133
3.15 Frequency Protection ............................................................................... 3-139 3.15.1 Overfrequency Protection .............................................................................................. 3-139 3.15.2 Underfrequency Protection ............................................................................................ 3-143
3.16 Breaker Failure Protection ....................................................................... 3-148 3.16.1 General Application........................................................................................................ 3-148 3.16.2 Function Description ...................................................................................................... 3-148 3.16.3 Function Block Diagram ................................................................................................ 3-149 3.16.4 I/O Signals ..................................................................................................................... 3-150 3.16.5 Logic .............................................................................................................................. 3-151 3.16.6 Settings .......................................................................................................................... 3-152
3.17 Thermal Overload Protection ................................................................... 3-152 3.17.1 General Application........................................................................................................ 3-152 3.17.2 Function Description ...................................................................................................... 3-153 3.17.3 Function Block Diagram ................................................................................................ 3-154 3.17.4 I/O Signals ..................................................................................................................... 3-154 3.17.5 Logic .............................................................................................................................. 3-155 3.17.6 Settings .......................................................................................................................... 3-156
3.18 Stub Overcurrent Protection .................................................................... 3-156 3.18.1 General Application........................................................................................................ 3-156 3.18.2 Function Block Diagram ................................................................................................ 3-157 3.18.3 I/O Signals ..................................................................................................................... 3-157 3.18.4 Logic .............................................................................................................................. 3-158 3.18.5 Settings .......................................................................................................................... 3-158
3.19 Dead Zone Protection ............................................................................... 3-159 3-d
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.19.1 General Application........................................................................................................ 3-159 3.19.2 Function Description ...................................................................................................... 3-159 3.19.3 Function Block Diagram ................................................................................................ 3-159 3.19.4 I/O Signal ....................................................................................................................... 3-159 3.19.5 Logic .............................................................................................................................. 3-160 3.19.6 Settings .......................................................................................................................... 3-160
3.20 Pole Discrepancy Protection .................................................................... 3-160 3.20.1 General Application........................................................................................................ 3-160 3.20.2 Function Description ...................................................................................................... 3-161 3.20.3 Function Block Diagram ................................................................................................ 3-161 3.20.4 I/O Signals ..................................................................................................................... 3-161 3.20.5 Logic .............................................................................................................................. 3-161 3.20.6 Settings .......................................................................................................................... 3-162
3.21 Broken Conductor Protection .................................................................. 3-162 3.21.1 General Application........................................................................................................ 3-162 3.21.2 Function Description ...................................................................................................... 3-163 3.21.3 Function Block Diagram ................................................................................................ 3-163 3.21.4 I/O Signals ..................................................................................................................... 3-163 3.21.5 Logic .............................................................................................................................. 3-164 3.21.6 Settings .......................................................................................................................... 3-164
3.22 Reverse Power Protection ........................................................................ 3-165 3.22.1 General Application........................................................................................................ 3-165 3.22.2 Function Description ...................................................................................................... 3-165 3.22.3 Function Block Diagram ................................................................................................ 3-166 3.22.4 I/O Signals ..................................................................................................................... 3-166 3.22.5 Logic .............................................................................................................................. 3-167 3.22.6 Settings .......................................................................................................................... 3-168
3.23 Synchrocheck............................................................................................ 3-168 3.23.1 General Application........................................................................................................ 3-168 3.23.2 Function Description ...................................................................................................... 3-169 3-e
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.23.3 Function Block Diagram ................................................................................................ 3-172 3.23.4 I/O Signals ..................................................................................................................... 3-172 3.23.5 Logic .............................................................................................................................. 3-173 3.23.6 Settings .......................................................................................................................... 3-175
3.24 Automatic Reclosure ................................................................................ 3-176 3.24.1 General Application........................................................................................................ 3-176 3.24.2 Function Description ...................................................................................................... 3-177 3.24.3 Function Block Diagram ................................................................................................ 3-178 3.24.4 I/O Signals ..................................................................................................................... 3-178 3.24.5 Logic .............................................................................................................................. 3-180 3.24.6 Settings .......................................................................................................................... 3-192
3.25 Transfer Trip .............................................................................................. 3-194 3.25.1 General Application........................................................................................................ 3-194 3.25.2 Function Description ...................................................................................................... 3-194 3.25.3 Function Block Diagram ................................................................................................ 3-194 3.25.4 I/O Signals ..................................................................................................................... 3-194 3.25.5 Logic .............................................................................................................................. 3-195 3.25.6 Settings .......................................................................................................................... 3-195
3.26 Trip Logic ................................................................................................... 3-195 3.26.1 General Application........................................................................................................ 3-195 3.26.2 Function Description ...................................................................................................... 3-195 3.26.3 Function Block Diagram ................................................................................................ 3-196 3.26.4 I/O Signals ..................................................................................................................... 3-196 3.26.5 Logic .............................................................................................................................. 3-197 3.26.6 Settings .......................................................................................................................... 3-201
3.27 VT Circuit Supervision .............................................................................. 3-201 3.27.1 General Application........................................................................................................ 3-201 3.27.2 Function Description ...................................................................................................... 3-202 3.27.3 Function Block Diagram ................................................................................................ 3-202 3.27.4 I/O Signals ..................................................................................................................... 3-202 3-f
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.27.5 Logic .............................................................................................................................. 3-203 3.27.6 Settings .......................................................................................................................... 3-204
3.28 CT Circuit Supervision ............................................................................. 3-204 3.28.1 General Application........................................................................................................ 3-204 3.28.2 Function Description ...................................................................................................... 3-204 3.28.3 Function Block Diagram ................................................................................................ 3-204 3.28.4 I/O Signals ..................................................................................................................... 3-205 3.28.5 Logic .............................................................................................................................. 3-205
3.29 Control and Synchrocheck for Manual Closing ..................................... 3-205 3.29.1 General Application........................................................................................................ 3-205 3.29.2 Function Description ...................................................................................................... 3-205 3.29.3 Function Block Diagram ................................................................................................ 3-212 3.29.4 I/O Signals ..................................................................................................................... 3-212 3.29.5 Settings .......................................................................................................................... 3-213
3.30 Faulty Phase Selection ............................................................................. 3-215 3.30.1 General Application........................................................................................................ 3-215 3.30.2 Function Description ...................................................................................................... 3-216 3.30.3 Function Block Diagram ................................................................................................ 3-217 3.30.4 I/O Signals ..................................................................................................................... 3-217
3.31 Fault Location............................................................................................ 3-218 3.31.1 Application...................................................................................................................... 3-218 3.31.2 Function Description ...................................................................................................... 3-218 3.31.3 Function Block Diagram ................................................................................................ 3-221 3.31.4 I/O Signals ..................................................................................................................... 3-221
List of Figures Figure 3.3-1 Logic diagram of CB position supervision ......................................................... 3-4 Figure 3.3-2 Logic diagram of trip&closing circuit supervision ............................................ 3-5 Figure 3.4-1 Flow chart of protection program ........................................................................ 3-8 Figure 3.4-2 Logic diagram of fault detector ............................................................................ 3-9
3-g
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Figure 3.5-1 Logic diagram of auxiliary element.................................................................... 3-19 Figure 3.6-1 Protected reach of distance protection for each zone .................................... 3-22 Figure 3.6-2 Operating time of single-phase fault (50Hz, SIR=1) ......................................... 3-23 Figure 3.6-3 Operating time of single-phase fault (60Hz, SIR=1) ......................................... 3-24 Figure 3.6-4 Operating time of two-phase fault (50Hz, SIR=1) ............................................. 3-24 Figure 3.6-5 Operating time of two-phase fault (60Hz, SIR=1) ............................................. 3-25 Figure 3.6-6 Operating time of three-phase fault (50Hz, SIR=1) ........................................... 3-25 Figure 3.6-7 Operating time of three-phase fault (60Hz, SIR=1) ........................................... 3-26 Figure 3.6-8 Operating time of single-phase fault (50Hz, SIR=30) ....................................... 3-26 Figure 3.6-9 Operating time of single-phase fault (60Hz, SIR=30) ....................................... 3-27 Figure 3.6-10 Operating time of two-phase fault (50Hz, SIR=30) ......................................... 3-27 Figure 3.6-11 Operating time of two-phase fault (60Hz, SIR=30).......................................... 3-28 Figure 3.6-12 Operating time of three-phase fault (50Hz, SIR=30) ....................................... 3-28 Figure 3.6-13 Operating time of three-phase fault (60Hz, SIR=30) ....................................... 3-29 Figure 3.6-14 Operation characteristic for forward fault....................................................... 3-30 Figure 3.6-15 Operation characteristic for reverse fault ....................................................... 3-31 Figure 3.6-16 Logic diagram of DPFC distance protection................................................... 3-32 Figure 3.6-17 Distance element with load trapezoid.............................................................. 3-33 Figure 3.6-18 Phase-to-ground operation characteristic for forward fault ......................... 3-35 Figure 3.6-19 Phase-to-phase operation characteristic for forward fault ........................... 3-36 Figure 3.6-20 Operation characteristic for reverse fault ....................................................... 3-38 Figure 3.6-21 Steady-state characteristic of three-phase short-circuit fault ...................... 3-38 Figure 3.6-22 Operation characteristic of three-phase close up short-circuit fault........... 3-39 Figure 3.6-23 Shift impedance characteristic of zone 1 and zone 2 .................................... 3-40 Figure 3.6-24 Operation characteristic of reverse Z4 distance protection ......................... 3-41 Figure 3.6-25 Logic diagram of enabling distance protection (Mho)................................... 3-43 Figure 3.6-26 Logic diagram of distance protection (Mho zone 1) ...................................... 3-43 Figure 3.6-27 Logic diagram of distance protection (Mho zone 2) ...................................... 3-44 Figure 3.6-28 Logic diagram of distance protection (Mho zone 3) ...................................... 3-45 Figure 3.6-29 Logic diagram of distance protection (Mho zone 4) ...................................... 3-46 3-h
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Figure 3.6-30 Quadrilateral forward distance element characteristics ............................... 3-50 Figure 3.6-31 Quadrilateral reverse distance element characteristic .................................. 3-51 Figure 3.6-32 Logic diagram of enabling distance protection (Quad) ................................. 3-53 Figure 3.6-33 Logic diagram of distance protection (Quad zone 1) .................................... 3-53 Figure 3.6-34 Logic diagram of distance protection (Quad zone 2) .................................... 3-54 Figure 3.6-35 Logic diagram of distance protection (Quad zone 3) .................................... 3-55 Figure 3.6-36 Logic diagram of distance protection (Quad zone 4) .................................... 3-56 Figure 3.6-37 Logic diagram of power swing detection ........................................................ 3-61 Figure 3.6-38 Logic diagram of PSBR ..................................................................................... 3-66 Figure 3.6-39 Logic diagram of enabling distance SOTF protection ................................... 3-68 Figure 3.6-40 Logic diagram of distance SOTF protection by manual closing signal ...... 3-69 Figure 3.6-41 Logic diagram of distance SOTF protection by 1-pole or 3-pole AR ........... 3-70 Figure 3.6-42 Logic diagram of distance SOTF protection by PD condition ...................... 3-71 Figure 3.7-1 Direct optical link up to 2km with 850nm .......................................................... 3-74 Figure 3.7-2 Direct optical link up to 40km with 1310nm or up to 100km with 1550nm .... 3-74 Figure 3.7-3 Connect to a communication network via communication convertor........... 3-74 Figure 3.7-4 Connect to a communication network via MUX-64 .......................................... 3-75 Figure 3.7-5 Connect to a communication network via MUX-2M ......................................... 3-75 Figure 3.7-6 Schematic diagram of communication channel time ...................................... 3-77 Figure 3.7-7 Logic diagram of receiving signal n .................................................................. 3-79 Figure 3.8-1 Operation characteristic of DPFC current differential element ...................... 3-82 Figure 3.8-2 Operation characteristic of DPFC current differential element ...................... 3-83 Figure 3.8-3 Operation characteristic of steady-state current differential element ........... 3-84 Figure 3.8-4 Operation characteristic of steady-state current differential element ........... 3-85 Figure 3.8-5 Operation characteristic of neutral current differential element .................... 3-86 Figure 3.8-6 ∏ equivalent circuit ........................................................................................... 3-87 Figure 3.8-7 Equivalent circuit of shunt reactor .................................................................... 3-88 Figure 3.8-8 Relation between CT saturation differential current and restraint current ... 3-89 Figure 3.9-1 Line fault description ......................................................................................... 3-100 Figure 3.9-2 Vector diagram of current and voltage ............................................................ 3-101 3-i
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Figure 3.9-3 Vector diagram of zero-sequence power ........................................................ 3-103 Figure 3.10-1 Logic diagram of phase overcurrent protection .......................................... 3-110 Figure 3.11-1 Logic diagram of earth fault protection ......................................................... 3-117 Figure 3.12-1 Logic diagram of overcurrent protection for VT circuit failure................... 3-124 Figure 3.13-1 Logic diagram of residual current SOTF protection .................................... 3-126 Figure 3.14-1 Logic diagram of stage x of overvoltage protection .................................... 3-131 Figure 3.14-2 Blocking logic of undervoltage protection ................................................... 3-137 Figure 3.14-3 Logic diagram of stage x of undervoltage protection ................................. 3-137 Figure 3.15-1 Logic diagram of overfrequency protection (stage 1) ................................. 3-140 Figure 3.15-2 Logic diagram of overfrequency protection (stage 2) ................................. 3-141 Figure 3.15-3 Logic diagram of overfrequency protection (stage 3) ................................. 3-141 Figure 3.15-4 Logic diagram of overfrequency protection (stage 4) ................................. 3-141 Figure 3.15-5 Logic diagram of overfrequency protection (start) ...................................... 3-142 Figure 3.15-6 Logic diagram of underfrequency protection (stag1) .................................. 3-145 Figure 3.15-7 Logic diagram of underfrequency protection (stag2) .................................. 3-145 Figure 3.15-8 Logic diagram of underfrequency protection (stag3) .................................. 3-146 Figure 3.15-9 Logic diagram of underfrequency protection (stag4) .................................. 3-146 Figure 3.15-10 Logic diagram of underfrequency protection (start) ................................. 3-147 Figure 3.16-1 Logic diagram of breaker failure protection ................................................. 3-151 Figure 3.17-1 Characteristic curve of the thermal overload model ................................... 3-154 Figure 3.17-2 Logic diagram of thermal overload protection (stage 1) ............................. 3-155 Figure 3.17-3 Logic diagram of thermal overload protection (stage 2) ............................. 3-155 Figure 3.18-1 3/2 breakers arrangement ............................................................................... 3-157 Figure 3.18-2 Logic diagram of stub overcurrent protection ............................................. 3-158 Figure 3.19-1 Dead zone protection ...................................................................................... 3-160 Figure 3.20-1 Logic diagram of pole discrepancy protection............................................. 3-162 Figure 3.21-1 Logic diagram of broken conductor protection ........................................... 3-164 Figure 3.22-1 Logic diagram of stage 1 of reverse power protection................................ 3-167 Figure 3.22-2 Logic diagram of stage 2 of reverse power protection................................ 3-167 Figure 3.23-1 Relationship between reference voltage and synchronism voltage .......... 3-169 3-j
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Figure 3.23-2 Line voltage circuit failure supervision logic ............................................... 3-170 Figure 3.23-3 Bus Voltage Circuit Failure Supervision logic .............................................. 3-171 Figure 3.23-4 Synchronism check ......................................................................................... 3-174 Figure 3.23-5 Dead charge check logic ................................................................................. 3-174 Figure 3.23-6 Synchrocheck logic ......................................................................................... 3-175 Figure 3.24-1 Logic diagram of AR block ............................................................................. 3-181 Figure 3.24-2 Logic diagram of AR ready ............................................................................. 3-182 Figure 3.24-3 Logic diagram of tripping condition output .................................................. 3-183 Figure 3.24-4 Single-phase tripping initiating AR ................................................................ 3-184 Figure 3.24-5 Three-phase tripping initiating AR ................................................................. 3-184 Figure 3.24-6 1-pole AR initiation .......................................................................................... 3-185 Figure 3.24-7 3-pole AR initiation .......................................................................................... 3-185 Figure 3.24-8 One-shot AR ..................................................................................................... 3-186 Figure 3.24-9 Extra time delay of AR ..................................................................................... 3-186 Figure 3.24-10 Reclosing output logic .................................................................................. 3-187 Figure 3.24-11 Wait toslave signal ......................................................................................... 3-187 Figure 3.24-12 Reclosing failure and success ..................................................................... 3-188 Figure 3.24-13 Single-phase transient fault .......................................................................... 3-191 Figure 3.24-14 Single-phase permanent fault ([79.N_Rcls]=2) ........................................... 3-191 Figure 3.25-1 Logic diagram of transfer trip......................................................................... 3-195 Figure 3.26-1 Tripping logic.................................................................................................... 3-199 Figure 3.26-2 Breaker failure initiation logic ........................................................................ 3-199 Figure 3.26-3 Blocking AR logic ............................................................................................ 3-200 Figure 3.27-1 Logic of VT circuit supervision ...................................................................... 3-203 Figure 3.27-2 Logic of VT neutral point supervision ........................................................... 3-203 Figure 3.28-1 Logic diagram of CT circuit failure ................................................................ 3-205 Figure 3.29-1 Logic diagram of closing primary equipment .............................................. 3-207 Figure 3.29-2 Logic diagram of open primary equipment................................................... 3-208 Figure 3.29-3 Configuration page of control output 01 (default configration) ................. 3-209 Figure 3.29-4 Configuration page of control output 02 (default configration) ................. 3-210 3-k
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Figure 3.30-1 The region of faulty phase selection ............................................................. 3-217 Figure 3.31-1 Equivalent sequence network ........................................................................ 3-219
List of Tables Table 3.1-1 System parameters .................................................................................................. 3-1 Table 3.2-1 Line parameters ....................................................................................................... 3-2 Table 3.3-1 I/O signals of CB position supervision.................................................................. 3-4 Table 3.3-2 Internal settings of CB position supervision ........................................................ 3-5 Table 3.4-1 I/O signals of fault detector .................................................................................... 3-9 Table 3.4-2 Settings of fault detector ...................................................................................... 3-10 Table 3.5-1 I/O signals of auxiliary element ............................................................................ 3-14 Table 3.5-2 Settings of auxiliary element ................................................................................ 3-19 Table 3.6-1 I/O signals of DPFC distance protection ............................................................. 3-32 Table 3.6-2 Settings of DPFC distance protection ................................................................. 3-33 Table 3.6-3 I/O signals of load encroachment ........................................................................ 3-34 Table 3.6-4 Settings of load encroachment ............................................................................ 3-34 Table 3.6-5 I/O signals of distance protection (Mho) ............................................................. 3-42 Table 3.6-6 Settings of distance protection (Mho) ................................................................. 3-47 Table 3.6-7 I/O signals of distance protection (Quad) ........................................................... 3-52 Table 3.6-8 Settings of distance protection (Quad) ............................................................... 3-56 Table 3.6-9 I/O signals of power swing detection .................................................................. 3-61 Table 3.6-10 Settings of power swing detection .................................................................... 3-61 Table 3.6-11 I/O signals of PSBR.............................................................................................. 3-65 Table 3.6-12 Settings of PSBR ................................................................................................. 3-66 Table 3.6-13 I/O signals of distance SOTF protection ........................................................... 3-68 Table 3.6-14 Settings of distance SOTF protection ............................................................... 3-71 Table 3.6-15 Internal settings of distance SOTF protection ................................................. 3-73 Table 3.7-1 I/O signals of pilot channel ................................................................................... 3-79 Table 3.7-2 Settings of pilot channel ....................................................................................... 3-80 Table 3.8-1 I/O signals of current differential protection ...................................................... 3-91
3-l
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Table 3.8-2 Settings of current differential protection .......................................................... 3-98 Table 3.9-1 Direction description ........................................................................................... 3-102 Table 3.9-2 I/O signals of current direction........................................................................... 3-105 Table 3.9-3 Settings of current direction............................................................................... 3-106 Table 3.10-1 Inverse-time curve parameters......................................................................... 3-108 Table 3.10-2 I/O signals of phase overcurrent protection ................................................... 3-109 Table 3.10-3 Settings of phase overcurrent protection ....................................................... 3-110 Table 3.11-1 Inverse-time curve parameters ......................................................................... 3-116 Table 3.11-2 I/O signals of earth fault protection ................................................................. 3-117 Table 3.11-3 Settings of earth fault protection ..................................................................... 3-118 Table 3.12-1 I/O signals of overcurrent protection for VT circuit failure ........................... 3-123 Table 3.12-2 Settings of overcurrent protection for VT circuit failure ............................... 3-124 Table 3.13-1 I/O signals of residual SOTF protection .......................................................... 3-125 Table 3.13-2 Settings of residual current SOTF protection ................................................ 3-126 Table 3.14-1 Inverse-time curve parameters......................................................................... 3-129 Table 3.14-2 I/O signals of overvoltage protection .............................................................. 3-130 Table 3.14-3 Settings of overvoltage protection .................................................................. 3-131 Table 3.14-4 Inverse-time curve parameters of phase undervoltage protection .............. 3-135 Table 3.14-5 I/O signals of undervoltage protection ............................................................ 3-136 Table 3.14-6 Settings of undervoltage protection ................................................................ 3-138 Table 3.15-1 I/O signals of overfrequency protection.......................................................... 3-140 Table 3.15-2 Settings of overfrequency protection.............................................................. 3-142 Table 3.15-3 I/O signals of underfrequency protection ....................................................... 3-144 Table 3.15-4 Settings of underfrequency protection ........................................................... 3-147 Table 3.16-1 I/O signals of breaker failure protection.......................................................... 3-150 Table 3.16-2 Settings of breaker failure protection.............................................................. 3-152 Table 3.17-1 I/O signals of thermal overload protection ..................................................... 3-154 Table 3.17-2 Settings of thermal overload protection ......................................................... 3-156 Table 3.18-1 I/O signals of stub overcurrent protection ...................................................... 3-157 Table 3.18-2 Settings of stub overcurrent protection .......................................................... 3-158 3-m
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Table 3.19-1 I/O signals of dead zone protection ................................................................. 3-159 Table 3.19-2 Settings of dead zone protection ..................................................................... 3-160 Table 3.20-1 I/O signals of pole discrepancy protection ..................................................... 3-161 Table 3.20-2 Settings of pole discrepancy protection ......................................................... 3-162 Table 3.21-1 I/O signals of broken conductor protection .................................................... 3-163 Table 3.21-2 Settings of broken conductor protection ........................................................ 3-164 Table 3.22-1 I/O signals of reverse power protection .......................................................... 3-166 Table 3.22-2 Settings of broken conductor protection ........................................................ 3-168 Table 3.23-1 I/O signals of synchrocheck ............................................................................. 3-172 Table 3.23-2 Settings of synchrocheck ................................................................................. 3-175 Table 3.24-1 I/O signals of auto-reclosing ............................................................................ 3-178 Table 3.24-2 Reclosing number.............................................................................................. 3-190 Table 3.24-3 Settings of auto-reclosing ................................................................................ 3-192 Table 3.25-1 I/O signals of transfer trip ................................................................................. 3-194 Table 3.25-2 Settings of Transfer trip .................................................................................... 3-195 Table 3.26-1 I/O signals of trip logic ...................................................................................... 3-196 Table 3.26-2 Settings of trip logic .......................................................................................... 3-201 Table 3.27-1 I/O signals of VT circuit supervision ............................................................... 3-202 Table 3.27-2 VTS Settings ....................................................................................................... 3-204 Table 3.28-1 I/O signals of CT circuit supervision ............................................................... 3-205 Table 3.29-1 I/O signals of control ......................................................................................... 3-212 Table 3.29-2 Control Settings ................................................................................................. 3-213 Table 3.29-3 Synchrocheck Settings ..................................................................................... 3-214 Table 3.30-1 Relation between ΔUOΦMAX and faulty phase.............................................. 3-216 Table 3.30-2 I/O signals of faulty phase selection ............................................................... 3-217 Table 3.31-1 I/O signals of fault location ............................................................................... 3-221
3-n
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.1 System Parameters 3.1.1 General Application The device performs various protection functions by respective algorithms with the information (currents and voltages) acquired from primary system through current transformer and voltage transformer, so it is important to configure analog input channels correctly. Further to correct configuration of analog input channels, other protected system information, such as the parameters of voltage transformer and current transformer are also required.
3.1.2 Function Description The device generally considers transmission line as its protected object, current flows from busbar to line is considered as the forward direction.
3.1.3 Settings Table 3.1-1 System parameters No.
Name
Range
Step
Unit
1
Remark
1
Active_Grp
1~10
Active setting group
2
Opt_SysFreq
50 or 60
3
PrimaryEquip_Name
4
U1n
33.00~65500.00
0.01
kV
5
U2n
80.00~220.00
0.01
V
6
I1n
100~65500
1
A
Primary rated value of CT
7
I2n
1 or 5
A
Secondary rated value of CT
Hz
System frequency The name of primary equipment Primary rated value of VT (phase to phase) Secondary rated value of VT (phase to phase)
Frequency upper limit setting 8
f_High_FreqAlm
50~65
1
Hz
The
device
will
issue
an
alarm
[Alm_Freq], when system frequency is higher than the setting. Frequency lower limit setting
9
f_Low_FreqAlm
45~60
1
Hz
The
device
will
issue
an
alarm
[Alm_Freq], when system frequency is lower than the setting.
3.2 Line Parameters 3.2.1 General Application When the device equips with line protection functions, line parameters of protected line are required, especially for fault location, precise line parameters are the basic criterion for accurate fault location.
3-1
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.2.2 Function Description Line parameters mainly include positive-sequence reactance, positive-sequence resistance, zero-sequence reactance, zero-sequence resistance, mutual zero-sequence reactance, mutual zero-sequence resistance and line length. The positive-sequence reactance, zero-sequence reactance, positive-sequence resistance and zero-sequence resistance are the reactance and resistance value of the whole line. In general, the device locates the fault through calculating the impedance value from the location of the device to fault point.
3.2.3 Settings Table 3.2-1 Line parameters No.
Name
Range
Step
Unit
Remark Positive-sequence reactance of the whole line (secondary value) Positive-sequence resistance of the whole line (secondary value) Zero-sequence reactance of the whole line (secondary value) Zero-sequence resistance of the whole line (secondary value) Zero-sequence mutual reactance (secondary value)
1
X1L
(0.000~4Unn)/In
0.001
ohm
2
R1L
(0.000~4Unn)/In
0.001
ohm
3
X0L
(0.000~4Unn)/In
0.001
ohm
4
R0L
(0.000~4Unn)/In
0.010
ohm
5
X0M
(0.000~4Unn)/In
0.001
ohm
6
R0M
(0.000~4Unn)/In
0.01
ohm
7
LineLength
0.00~655.35
0.01
km
Total length of the whole line
8
phi1_Reach
30.00~89.00
0.01
Deg
Phase angle of line positive-sequence impedance
9
Real_K0
-4.000~4.000
0.001
10
Imag_K0
-4.000~4.000
0.001
Zero-sequence mutual resistance of the whole line (secondary value)
Real
component
of
zero-sequence
compensation coefficient Imaginary component of zero-sequence compensation coefficient
3.3 Circuit Breaker Position Supervision 3.3.1 General Application The status of circuit breaker (CB) position is applied for protection and control functions in this device, such as, SOTF protection, auto-reclose and VT circuit supervision, etc. The status of CB position can be applied as input signals for other features configured by user.
3.3.2 Function Description The signal reflecting CB position is acquired via opto-coupler with settable delay pickup and dropoff, and forms digital signal used by protection functions. CB position can reflect the status of each phase by means of phase-segregated inputs. In order to prevent that wrong status of CB position is input into the device via binary input, 3-2
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
appropriate monitor method is used to check the rationality of the binary input. When the binary input of CB open position is detected, the status of CB position will be thought as incorrect and an alarm [Alm_52b] will be issued if there is current detected in the line. Together with the status of circuit breaker and the information of external circuit, this function can be used to supervise control circuit of circuit breaker. External manual closing binary input (ManCls) is only used for SOTF logic application, the control of circuit breaker (CB) closing or opening should refer to section 3.29 (Control and Synchrocheck for Manual Closing).
3.3.3 Function Block Diagram 1.
For phase-segregated circuit breaker CB Position Supervision 52b_PhA
Alm_52b
52b_PhB 52b_PhC ManCls
2.
For non-phase segregated circuit breaker CB Position Supervision 52b
Alm_52b
ManCls
3.
Trip&closing circuit supervision (TCCS) TCCS 52a
TCCS.Alm
52b TCCS.Input ManCls
TCCS will be disabled automatically when it is used for phase-segregated circuit breaker. 3-3
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.3.4 I/O Signals Table 3.3-1 I/O signals of CB position supervision No.
Input Signal
Description
1
52b_PhA
Normally closed contact of A-phase of circuit breaker
2
52b_PhB
Normally closed contact of B-phase of circuit breaker
3
52b_PhC
Normally closed contact of C-phase of circuit breaker
4
ManCls
External manual closing binary input, it is only applied to SOTF logic
5
52b
Normally closed contact of three-phase of circuit breaker
6
52a
Normally open contact of three-phase of circuit breaker
7
TCCS.Input
Control circuit failure (normally closed contact and normally open contact of three-phase circuit breaker are all de-energized due to DC power loss of control circuit) No.
Output Signal
Description
1
Alm_52b
CB position is abnormal
2
TCCS.Alm
Control circuit of circuit breaker is abnormal
Note!
The signal [52a] only take effect in the tripping/closing circuit supervision and not affect any protection function. Only if tripping/closing circuit supervision is configured, this signal needs to be connected to the device.
3.3.5 Logic BI
[52b_PhA]
>=1 & &
BI
[52b_PhB]
>=1 &
BI
[52b_PhC]
>=1
& >=1
& BI
[52b]
& SIG
Ia>I_Line
>=1 &
SIG
>=1
10s
10s
Alm_52b
Ib>I_Line
& SIG
Ic>I_Line
Figure 3.3-1 Logic diagram of CB position supervision
3-4
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory >=1
BI
[52a]
BI
[52b]
BI
[TCCS.Input]
>=1 [TCCS.t_DPU]
[TCCS.t_DDO]
TCCS.Alm
Figure 3.3-2 Logic diagram of trip&closing circuit supervision
I_Line is threshold value used to determine whether line is on-load or no-load. Default value 0.06In.
3.3.6 Settings Table 3.3-2 Internal settings of CB position supervision No.
Name
Default Value
Unit
Remark
1
TCCS.t_DPU
0.5
s
Pickup delay time of control circuit failure alarm
2
TCCS.t_DDO
0.5
s
Dropoff delay time of control circuit failure alarm
3.4 Fault Detector (FD) 3.4.1 Application The device has one DSP module with fault detector DSP and protection DSP for fault detector and protection calculation respectively. Protection DSP with protection fault detector element is responsible for calculation of protection elements, and fault detector DSP is responsible to determine fault appearance on the protected power system. Fault detector in fault detector DSP picks up to provide positive supply to output relays. The output relays can only operate when both the fault detector in fault detector DSP and a protection element operate simultaneously. Otherwise, the output relays would not operate. An alarm message will be issued with blocking outputs if a protection element operates while the fault detector does not operate.
3.4.2 Fault Detector in Fault Detector DSP Main part of FD is DPFC current detector element that detects the change of phase-to-phase power frequency current, and residual current fault detector element that calculates the vector sum of 3 phase currents as supplementary. They are continuously calculating the analog input signals. The FD pickup condition in this device includes: 1.
Pickup condition 1: DPFC current is greater than the setting value
2.
Pickup condition 2: Residual current is greater than the setting value
3.
Pickup condition 3: Phase voltage or phase-to-phase voltage is greater than the voltage setting of overvoltage protection
4.
Pickup condition 4: Circuit breaker position discrepancy
3-5
PCS-931 Line Differential Relay Date: 2014-03-05
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Pickup condition 3 and 4 are only available when respective protection elements are enabled. If any of the above conditions is complied, the FD will operate to activate the output circuit providing DC power supply to the output relays. DPFC current fault detector element (pickup condition 1) and residual current fault detector element (pickup condition 2) are always enabled, and all protection functions are permitted to operate when they operate. 3.4.2.1 Fault Detector Based on DPFC Current (pickup condition 1) DPFC phase-to-phase current is obtained by subtracting the phase-to-phase current from that of a cycle before.
I(k) is the sampling value at a point. I(k-24) is the value of a sampling point before a cycle, 24 is the sampling points in one cycle. 200 100 0 -100 -200
0
20
40
60 Original Current
80
100
120
0
20
40
60 DPFC current
80
100
120
100 50 0 -50 -100
From above figures, it is concluded that DPFC can reflect the sudden change of current at the initial stage of a fault and has a perfect performance of fault detection. It is used to determine whether this pickup condition is met according to Equation 3.4-1. For multi-phase short-circuit fault, the DPFC phase-to-phase current has high sensitivity to ensure the pickup of protection device. For usual single phase to earth fault, it also has sufficient sensitivity to pick up except the earth fault with very large fault resistance. Under this condition the DPFC current is relative small, however, residual current is also used to judge pickup condition (pickup condition 2). This element adopts adaptive floating threshold varied with the change of load current continuously. The change of load current is small and steadily under normal or power swing 3-6
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
condition, the adaptive floating threshold with the ΔI Set is higher than the change of current under these conditions and hence maintains the element stability. The criterion is: ΔIΦΦMAX>1.25ΔITh+ΔISet
Equation 3.4-1
Where: ΔIΦΦMAX: The maximum half-wave integration value of phase-to-phase current (ΦΦ=AB, BC, CA) ΔISet: The fixed threshold value (i.e. the setting [FD.DPFC.I_Set]) ΔITh: The floating threshold value The coefficient, 1.25, is an empirical value which ensures the threshold always higher than the unbalance output value of the system. If operating condition is met, DPFC current element will pickup and trigger FD to provide DC power supply for output relays, the FD operation signal will maintain 7 seconds after DPFC current element drops off. 3.4.2.2 Fault Detector Based on Residual Current (pickup condition 2) This pickup condition will be met when 3I0 is greater than the setting [FD.ROC.3I0_Set]. Where: 3I0: residual current calculates from the vector sum of Ia, Ib and Ic When residual current FD element operates and lasts for longer than 10 seconds, an alarm [Alm_Pkp_I0] will be issued. If operating condition is met, the residual current FD element will pickup and trigger FD to provide DC power supply for output relay, and pickup signal will be kept for 7 seconds after the residual current FD element drops off. 3.4.2.3 Fault Detector Based on Overvoltage (pickup condition 3) Overvoltage fault detector will be automatically effective when overvoltage protection is enabled. If the logic setting [59Px.Opt_1P/3P] is set as “1” (x=1 or 2), i.e. the protective device adopts 1-out-of-3 mode, when any phase voltage is greater than the setting [59Px.U_Set] (x=1 or 2), the overvoltage fault detector element will pickup and trigger FD to provide DC power supply for output relays, the FD operation signal will maintain 7 seconds after overvoltage fault detector element drops off. If the logic setting [59Px.Opt_1P/3P] is set as “0” (x=1 or 2), i.e. the protective device adopts 3-out-of-3 mode, when all three phase voltages are greater than the setting [59Px.U_Set] (x=1 or 2), the overvoltage fault detector element will pickup and trigger FD to provide DC power supply for output relays, the FD operation signal will maintain 7 seconds after overvoltage fault detector element drops off.
3-7
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3.4.2.4 Fault Detector Based on Circuit Breaker Position Discrepancy (pickup condition 4) When pole discrepancy protection is enabled, i.e. the logic setting [62PD.En] is set as “1”, and if three phases of circuit breaker are not in the same status, pole discrepancy FD element will operate to provide DC power supply for output relays, and pickup signal will maintain 7 seconds after pole discrepancy FD element drops out.
3.4.3 Protection Fault Detector in Protection Calculation DSP The protection device is running either of the two programs: one is “Regular program” for normal state, and the other is “Fault calculation program” after protection fault detector picks up. Under the normal state, the protection device will perform the following tasks: 1.
Calculate analog quantity
2.
Read binary input
3.
Hardware self-check
4.
Circuit breaker position supervision
5.
Analog quantity input supervision
6.
Channel supervision
Once the protection fault detector element in protection calculation DSP picks up, the protection device will switch to fault calculation program, for example the calculation of distance protection, and to determine logic. If the fault is within the protected zone, the protection device will send tripping command. The protection program flow chart is shown as Figure 3.4-1.
Main program
Sampling program
No
Regular program
Yes
Pickup?
Fault calculation program
Figure 3.4-1 Flow chart of protection program
The protection FD pickup conditions are the same as the FD in fault detector DSP as shown below. The operation criteria for the conditions are also the same as that in fault detector DSP. Please 3-8
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
refer to section 3.4.2 for details. 1.
Pickup condition 1: DPFC current is greater than the setting value
2.
Pickup condition 2: Residual current is greater than the setting value
3.
Pickup condition 3: Phase voltage or phase-to-phase voltage is greater than the setting value
4.
Pickup condition 4: Circuit breaker position discrepancy
When any pickup condition mentioned above is met, the protection device will go to fault calculation state. Pickup condition 3 and 4 are not common fault detector elements, only used for respective protection element. Please refer to section 3.14.1 and section 3.19 for details.
3.4.4 Function Block Diagram FD FD.Pkp FD.DPFC.Pkp FD.ROC.Pkp
3.4.5 I/O Signals Table 3.4-1 I/O signals of fault detector No.
Output Signal
Description
1
FD.Pkp
The device picks up
2
FD.DPFC.Pkp
DPFC current fault detector element operates.
3
FD.ROC.Pkp
Residual current fault detector element operates.
3.4.6 Logic SIG
Ia
SIG
Ib
SIG
Ic
Calculate DPFC phase-to-phase current:
ΔIab=Δ(Ia-Ib) ΔIbc=Δ(Ib-Ic) ΔIca=Δ(Ic-Ia)
ΔIab>[FD.DPFC.I_Set]
>=1 ΔIbc>[FD.DPFC.I_Set] ΔIca>[FD.DPFC.I_Set]
FD.DPFC.Pkp
>=1 0s
7s
FD.Pkp
Calculate residual current:
3I0=Ia+Ib+Ic
3I0>[FD.ROC.3I0_Set]
FD.ROC.Pkp
Figure 3.4-2 Logic diagram of fault detector
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3 Operation Theory
3.4.7 Settings Table 3.4-2 Settings of fault detector No.
Name
Range
Step
Unit
1
FD.DPFC.I_Set
(0.050~30.000)×In
0.001
A
2
FD.ROC.3I0_Set
(0.050~30.000)×In
0.001
A
Remark Current setting of DPFC current fault detector element Current setting of residual current fault detector element
3.5 Auxiliary Element 3.5.1 General Application Auxiliary element (AuxE) is mainly used to program logics to meet users’ applications or further improve operating reliability of protection elements. Reliability of protective elements (such as distance element or current differential element) is assured, auxiliary element is usually not required to configure. Auxiliary elements including current change auxiliary element (AuxE.OCD), residual current auxiliary element (AuxE.ROC), phase current auxiliary element (AuxE.OC), voltage change auxiliary element (AuxE.UVD), phase under voltage auxiliary element (AuxE.UVG), phase-to-phase under voltage auxiliary element (AuxE.UVS) and residual voltage auxiliary element (AuxE.ROV), and they can be enabled or disabled by corresponding logic setting or binary inputs. Users can configure them according to applications via PCS-Explorer software.
3.5.2 Function Description 1.
Current change auxiliary element AuxE.OCD
It shares DPFC current element of DPFC fault detector. If DPFC fault detector operates (FD.DPFC.Pkp=1) and current change auxiliary element is enabled, current change auxiliary element operates. 2.
Residual current auxiliary element AuxE.ROC
There are 3 stages for residual current auxiliary element (AuxE.ROC1, AuxE.ROC2 and AuxE.ROC3). Each residual current auxiliary element will operate instantly if calculated residual current amplitude is larger than corresponding current setting The criteria are: AuxE.ROC1: 3I0>[AuxE.ROC1.3I0_Set] AuxE.ROC2: 3I0>[AuxE.ROC2.3I0_Set] AuxE.ROC3: 3I0>[AuxE.ROC3.3I0_Set] Where: 3I0: The calculated residual current 3.
Phase current auxiliary element AuxE.OC
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3 Operation Theory
There are 3 stages for phase current auxiliary element (AuxE.OC1, AuxE.OC2 and AuxE.OC3). Each phase current auxiliary element will operate instantly if phase current amplitude is larger than corresponding current setting. The criteria are: AuxE.OC1: IΦMAX>[AuxE.OC1.I_Set] AuxE.OC2: IΦMAX>[AuxE.OC2.I_Set] AuxE.OC3: IΦMAX>[AuxE.OC3.I_Set] Where: IΦMAX: The maximum phase current among three phases 4.
Voltage change auxiliary element AuxE.UVD
AuxE.UVD is based on phase-to-ground voltage change measured in all three phases. The criterion is: ΔUΦMAX>[AuxE.UVD.U_Set] Where: ΔUΦMAX: The maximum phase-to-ground voltage change among three phases 5.
Phase under voltage auxiliary element AuxE.UVG
AuxE.UVG will operate instantly if any phase-to-ground voltage is lower than corresponding voltage setting. The criterion is: UΦMIN<[ AuxE.UVG.U_Set] Where: UΦMIN: The minimum value among three phase-to-ground voltages 6.
Phase-to-phase under voltage auxiliary element AuxE.UVS
AuxE.UVS will operate instantly if any phase-to-phase voltage is lower than corresponding voltage setting. The criterion is: UΦΦMIN<[ AuxE.UVS.U_Set] Where: UΦΦMIN: The minimum value among three phase-to-phase voltages 7.
Residual voltage auxiliary element AuxE.ROV
AuxE.ROV will operate instantly if calculated residual voltage is larger than corresponding voltage
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setting. The criterion is: 3U0>[ AuxE.ROV.3U0_Set] Where: 3U0: The calculated residual voltage
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3.5.3 Function Block Diagram AuxE AuxE.OCD.En
AuxE.St
AuxE.OCD.Blk
AuxE.OCD.St_Ext
AuxE.ROCx.En
AuxE.OCD.On
AuxE.ROCx.Blk
AuxE.ROCx.St
AuxE.OCx.En
AuxE.ROCx.On
AuxE.OCx.Blk
AuxE.OCx.St
AuxE.UVD.En
AuxE.OCx.StA
AuxE.UVD.Blk
AuxE.OCx.StB
AuxE.UVG.En
AuxE.OCx.StC
AuxE.UVG.Blk
AuxE.OCx.On
AuxE.UVS.En
AuxE.UVD.St
AuxE.UVS.Blk
AuxE.UVD.St_Ext
AuxE.ROV.En
AuxE.UVD.On
AuxE.ROV.Blk
AuxE.UVG.St AuxE.UVG.StA AuxE.UVG.StB AuxE.UVG.StC AuxE.UVG.On AuxE.UVS.St AuxE.UVS.StAB AuxE.UVS.StBC AuxE.UVS.StCA AuxE.UVS.On AuxE.ROV.St AuxE.ROV.On
Where: x can be 1, 2 or 3
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3.5.4 I/O Signals Table 3.5-1 I/O signals of auxiliary element No.
Input Signal
1
AuxE.OCD.En
2
AuxE.OCD.Blk
3
AuxE.ROC1.En
4
AuxE.ROC1.Blk
5
AuxE.ROC2.En
6
AuxE.ROC2.Blk
7
AuxE.ROC3.En
8
AuxE.ROC3.Blk
9
AuxE.OC1.En
10
AuxE.OC1.Blk
11
AuxE.OC2.En
12
AuxE.OC2.Blk
13
AuxE.OC3.En
14
AuxE.OC3.Blk
15
AuxE.UVD.En
16
AuxE.UVD.Blk
17
AuxE.UVG.En
18
AuxE.UVG.Blk
19
AuxE.UVS.En
20
AuxE.UVS.Blk
Description Current change auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Current change auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 1 of residual current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 1 of residual current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 2 of residual current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 2 of residual current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 3 of residual current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 3 of residual current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 1 of phase current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 1 of phase current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 2 of phase current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 2 of phase current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 3 of phase current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 3 of phase current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Voltage change auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Voltage change auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Phase-to-ground under voltage auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Phase-to-ground under voltage auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Phase-to-phase under voltage auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Phase-to-phase under voltage auxiliary element blocking input, it is triggered from
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AuxE.ROV.En
22
AuxE.ROV.Blk
No.
Residual voltage auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Residual voltage auxiliary element blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
AuxE.St
Any auxiliary element of the device operates
2
AuxE.OCD.St_Ext
Current change auxiliary element operates (7s delayed drop off).
3
AuxE.OCD.On
Current change auxiliary element is enabled
4
AuxE.ROC1.St
Stage 1 of residual current auxiliary element operates.
5
AuxE.ROC1.On
Stage 1 of residual current auxiliary element is enabled
6
AuxE.ROC2.St
Stage 2 of residual current auxiliary element operates.
7
AuxE.ROC2.On
Stage 2 of residual current auxiliary element is enabled
8
AuxE.ROC3.St
Stage 3 of residual current auxiliary element operates.
9
AuxE.ROC3.On
Stage 3 of residual current auxiliary element is enabled
10
AuxE.OC1.St
Stage 1 of phase current auxiliary element operates.
11
AuxE.OC1.StA
Stage 1 of phase current auxiliary element operates (phase A).
12
AuxE.OC1.StB
Stage 1 of phase current auxiliary element operates (phase B).
13
AuxE.OC1.StC
Stage 1 of phase current auxiliary element operates (phase C).
14
AuxE.OC1.On
Stage 1 of phase current auxiliary element is enabled
15
AuxE.OC2.St
Stage 2 of phase current auxiliary element operates.
16
AuxE.OC2.StA
Stage 2 of phase current auxiliary element operates (phase A).
17
AuxE.OC2.StB
Stage 2 of phase current auxiliary element operates (phase B).
18
AuxE.OC2.StC
Stage 2 of phase current auxiliary element operates (phase C).
19
AuxE.OC2.On
Stage 2 of phase current auxiliary element is enabled
20
AuxE.OC3.St
Stage 3 of phase current auxiliary element operates.
21
AuxE.OC3.StA
Stage 1 of phase current auxiliary element operates (phase A).
22
AuxE.OC3.StB
Stage 1 of phase current auxiliary element operates (phase B).
23
AuxE.OC3.StC
Stage 1 of phase current auxiliary element operates (phase C).
24
AuxE.OC3.On
Stage 3 of phase current auxiliary element is enabled
25
AuxE.UVD.St
Voltage change auxiliary element operates.
26
AuxE.UVD.St_Ext
Voltage change auxiliary element operates (7s delayed drop off).
27
AuxE.UVD.On
Voltage change auxiliary element is enabled
28
AuxE.UVG.St
Phase-to-ground under voltage auxiliary element operates.
29
AuxE.UVG.StA
Phase-to-ground under voltage auxiliary element operates (phase A).
30
AuxE.UVG.StB
Phase-to-ground under voltage auxiliary element operates (phase B).
31
AuxE.UVG.StC
Phase-to-ground under voltage auxiliary element operates (phase C).
32
AuxE.UVG.On
Phase-to-ground under voltage auxiliary element is enabled
33
AuxE.UVS.St
Phase-to-phase under voltage auxiliary element operates.
34
AuxE.UVS.StAB
Phase-to-phase under voltage auxiliary element operates (phase AB).
35
AuxE.UVS.StBC
Phase-to-phase under voltage auxiliary element operates (phase BC).
36
AuxE.UVS.StCA
Phase-to-phase under voltage auxiliary element operates (phase CA).
37
AuxE.UVS.On
Phase-to-phase under voltage auxiliary element is enabled
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3 Operation Theory 38
AuxE.ROV.St
Residual voltage auxiliary element operates.
39
AuxE.ROV.On
Residual voltage auxiliary element is enabled
3.5.5 Logic SIG
FD.DPFC.Pkp
SIG
AuxE.OCD.En
SIG
AuxE.OCD.Blk
En
AuxE.OCD.En
SIG
Ia
SIG
Ib
SIG
Ic
SIG
& &
0s
[AuxE.OCD.t_DDO]
AuxE.OCD.St_Ext
AuxE.OCD.On
Calculate residual current: 3I0=Ia+Ib+Ic 3I0>[AuxE.ROC1.3I0_Set]
AuxE.ROC1.En
& AuxE.ROC1.St
& SIG
AuxE.ROC1.Blk
En
AuxE.ROC1.En
SIG
AuxE.ROC2.En
AuxE.ROC1.On 3I0>[AuxE.ROC2.3I0_Set]
& AuxE.ROC2.St
& SIG
AuxE.ROC2.Blk
En
AuxE.ROC2.En
SIG
AuxE.ROC3.En
AuxE.ROC2.On 3I0>[AuxE.ROC3.3I0_Set]
SIG
AuxE.ROC3.Blk
En
AuxE.ROC3.En
& AuxE.ROC3.St
&
AuxE.ROC3.On
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3 Operation Theory SIG
Ia
Ia>[AuxE.OC1.I_Set]
& AuxE.OC1.StA
SIG
Ib
Ib>[AuxE.OC1.I_Set]
& AuxE.OC1.StB
SIG
Ic
Ic>[AuxE.OC1.I_Set]
& AuxE.OC1.StC
>=1 SIG
&
AuxE.OC1.En
AuxE.OC1.St
& SIG
AuxE.OC1.Blk
En
AuxE.OC1.En
SIG
Ia
AuxE.OC1.On Ia>[AuxE.OC2.I_Set]
& AuxE.OC2.StA
SIG
Ib
Ib>[AuxE.OC2.I_Set]
& AuxE.OC2.StB
SIG
Ic
Ic>[AuxE.OC2.I_Set]
& AuxE.OC2.StC
>=1 SIG
&
AuxE.OC2.En
AuxE.OC2.St
& SIG
AuxE.OC2.Blk
En
AuxE.OC2.En
SIG
Ia
AuxE.OC2.On Ia>[AuxE.OC3.I_Set]
& AuxE.OC3.StA
SIG
Ib
Ib>[AuxE.OC3.I_Set]
& AuxE.OC3.StB
SIG
Ic
Ic>[AuxE.OC3.I_Set]
& AuxE.OC3.StC
>=1 SIG
&
AuxE.OC3.En
AuxE.OC3.St
& SIG
AuxE.OC3.Blk
En
AuxE.OC4.En
AuxE.OC3.On
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3 Operation Theory SIG
Ua
SIG
Ub
SIG
Uc
ΔUa>[AuxE.UVD.U_Set]
Calculate DPFC phase voltage △Ua=△(Ua-Ufa) △Ub=△(Ub-Ufb) △Uc=△(Uc-Ufc)
>=1 ΔUb>[AuxE.UVD.U_Set]
& AuxE.UVD.St
ΔUc>[AuxE.UVD.U_Set] 0s
SIG
[AuxE.UVD.t_Ext]
AuxE.UVD.En
AuxE.UVD.St_Ext
& SIG
AuxE.UVD.Blk
En
AuxE.UVD.En
SET
AuxE.UVD.On
UA<[AuxE.UVG.U_Set]
& AuxE.UVG.StA
SET
UB<[AuxE.UVG.U_Set]
& AuxE.UVG.StB
SET
UC<[AuxE.UVG.U_Set]
& AuxE.UVG.StC >=1
SIG
AuxE.UVG.En
SIG
AuxE.UVG.Blk
En
AuxE.UVG.En
& AuxE.UVG.St
&
AuxE.UVG.On
SET
UAB<[AuxE.UVS.U_Set]
& AuxE.UVS.StAB
SET
UBC<[AuxE.UVS.U_Set]
& AuxE.UVS.StBC
SET
UCA<[AuxE.UVS.U_Set]
& AuxE.UVS.StCA >=1
SIG
&
AuxE.UVS.En
AuxE.UVS.St
& SIG
AuxE.UVS.Blk
En
AuxE.UVS.En AuxE.UVS.On
SIG
Ua
SIG
Ub
SIG
Uc
SIG
AuxE.ROV.En
SIG
AuxE.ROV.Blk
En
AuxE.ROV.En
3U0>[AuxE.ROV.3U0_Set]
& AuxE.ROV.St
Calculate residual voltage 3U0=Ua+Ub+Uc
& AuxE.ROV.On
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3 Operation Theory SIG
AuxE.OCD.St_Ext
SIG
AuxE.ROC1.St
SIG
AuxE.ROC2.St
SIG
AuxE.ROC3.St
SIG
AuxE.OC1.St
>=1
>=1 AuxE.St
>=1 SIG
AuxE.OC2.St
SIG
AuxE.OC3.St
SIG
AuxE.UVD.St_Ext
SIG
AuxE.UVG.St
SIG
AuxE.UVS.St
SIG
AuxE.ROV.St
>=1 >=1
>=1
Figure 3.5-1 Logic diagram of auxiliary element
3.5.6 Settings Table 3.5-2 Settings of auxiliary element No. 1
Name AuxE.OCD.t_DDO
Range 0.000~10.000
Step 0.001
Unit s
Remark Drop-off time delay of current change auxiliary element Enabling/disabling current change
2
AuxE.OCD.En
auxiliary element
0 or 1
0: disable 1: enable
3
AuxE.ROC1.3I0_Set
(0.050~30.000)×In
0.001
A
Current setting of stage 1 residual current auxiliary element Enabling/disabling stage 1 residual
4
AuxE.ROC1.En
current auxiliary element
0 or 1
0: disable 1: enable
5
AuxE.ROC2.3I0_Set
(0.050~30.000)×In
0.001
A
Current setting of stage 2 residual current auxiliary element Enabling/disabling stage 2 residual
6
AuxE.ROC2.En
current auxiliary element
0 or 1
0: disable 1: enable
7
AuxE.ROC3.3I0_Set
(0.050~30.000)×In
0.001
A
Current setting of stage 3 residual current auxiliary element Enabling/disabling stage 3 residual
8
AuxE.ROC3.En
current auxiliary element
0 or 1
0: disable 1: enable
9
AuxE.OC1.I_Set
(0.050~30.000)×In
Current setting of stage 1 phase current 3-19
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory auxiliary element Enabling/disabling stage 1 phase 10
AuxE.OC1.En
current auxiliary element
0 or 1
0: disable 1: enable
11
AuxE.OC2.I_Set
Current setting of stage 2 phase current
(0.050~30.000)×In
auxiliary element Enabling/disabling stage 2 phase
12
AuxE.OC2.En
current auxiliary element
0 or 1
0: disable 1: enable
13
AuxE.OC3.I_Set
Current setting of stage 3 phase current
(0.050~30.000)×In
auxiliary element Enabling/disabling stage 3 phase
14
AuxE.OC3.En
current auxiliary element
0 or 1
0: disable 1: enable
15
AuxE.UVD.U_Set
0~Un
0.001
V
16
AuxE.UVD.t_DDO
0.000~10.000
0.001
s
Voltage setting for voltage change auxiliary element Drop-off time delay of voltage change auxiliary element Enabling/disabling voltage change
17
AuxE.UVD.En
auxiliary element
0 or 1
0: disable 1: enable
18
AuxE.UVG.U_Set
0~Un
0.001
V
Voltage setting for phase-to-ground under voltage auxiliary element Enabling/disabling phase-to-ground
19
AuxE.UVG.En
under voltage auxiliary element
0 or 1
0: disable 1: enable
20
AuxE.UVS.U_Set
0~Unn
0.001
V
Voltage setting for phase-to-phase under voltage auxiliary element Enabling/disabling phase-to-phase
21
AuxE.UVS.En
under voltage auxiliary element
0 or 1
0: disable 1: enable
22
AuxE.ROV.3U0_Set
0~Un
0.001
V
Voltage setting for residual voltage auxiliary element Enabling/disabling residual voltage
23
AuxE.ROV.En
auxiliary element
0 or 1
0: disable 1: enable
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PCS-931 Line Differential Relay Date: 2014-03-05
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3.6 Distance Protection 3.6.1 General Application When a fault happens on a power system, distance protection will trip circuit breaker to isolate the fault from power system with its specific time delay if the fault is within the protected zone of distance protection.
3.6.2 Function Description The device comprises 3 forward zones and 1 reverse zone. For each independent distance element zone, full scheme design provides continuous measurement of impedance separately in three independent phase-to-phase measuring loops as well as in three independent phase-to-ground measuring loops. Selection of zone characteristic between mho and quadrilateral is available. Distance protection includes: 1.
DPFC distance protection It is independent fast protection providing extremely fast speed to clear close up fault especially on long line and thus improves system stability.
2.
Mho phase-to-phase distance protection Zone1~3: forward direction Zone 4: reverse direction including origin
3.
Mho phase-to-ground distance protection Zone1~3: forward direction Zone 4: reverse direction including origin
4.
Quadrilateral phase-to-phase distance protection Zone1~3: forward direction Zone 4: reverse direction
5.
Quadrilateral phase-to-ground distance protection Zone1~3: forward direction Zone 4: reverse direction
6.
Load encroachment It is used to prevent all distance elements from undesired trip due to load encroachment under heavy load condition especially for long lines.
7.
Power swing detection (PSD)
8.
Power swing blocking releasing (PSBR) For power swing with external fault, distance protection is always blocked, but for power 3-21
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
swing with internal fault, PSBR will operate to release the blocking for distance protection. 9.
SOTF distance protection For manual closing or automatic closing on to a fault, zone 2 or 3 of distance protection will accelerate to trip.
When VT circuit fails, VT circuit supervision logic will output a blocking signal to block all distance protection except DPFC distance protection. The operating threshold will be increased to 1.5U N to enhance stability. Distance protection can select line VT or bus VT for protection algorithm by a setting [VTS.En_LineVT]. When no VT is provided, logic setting [VTS.En_Out_VT] should be set as “1”, all distance protection will be blocked automatically. The coordination among zones of distance protection is shown in the following figure.
Z4
EM
M
A
B
P
C
D
N
EN
Z1、DZ Z2
Z3
Figure 3.6-1 Protected reach of distance protection for each zone
Where: Z1: forward direction zone 1 Z2: forward direction zone 2 Z3: forward direction zone 3 Z4: reverse direction zone 4 DZ: DPFC distance protection The choice of impedance reach is as follow. (only for reference) The zone 1 impedance reach setting should be set to cover as much the protected line as possible but not to respond faults beyond the protected line. The accuracy of the relay distance elements is ±2.5% in general applications, however, the error could be much larger due to errors of current transformer, voltage transformer and inaccuracies of line parameter from which the relay settings are calculated. It is recommended the zone 1 reach is set to 80%~85% of the protected line in consideration the aforesaid errors and safety margin to prevent instantaneously tripping for faults on adjacent lines. The remaining 20% of the protected line relies on the zone 2 distance elements. The general rule for zone 2 impedance reach setting is set to cover the protected line plus 20% of 3-22
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
the adjacent line. However, the coverage of adjacent line should be extended in the presence of additional infeed at the remote end of the protected line to ensure 20% coverage of adjacent line. This assures the fast operation of zone 2 distance element for faults at the remote end of the protected line since the fault is well within zone 2 reach. In a parallel line situation, a fault cleared sequentially on a line may cause current reversal in the healthy line. The Z3 distance element acts as backup protection for protected line and adjacent line but not to over the zone 2 setting of adjacent line. The zone 3 impedance reach is generally 2 times zone 1 reach, i.e. 160% of protected line. For different system impedance ratio (SIR), the operating time of distance protection for different fault location are shown as the following figures.
35 30 25 Operating Time (ms)
20 15 10 5 0 0
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-2 Operating time of single-phase fault (50Hz, SIR=1)
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30 25 Operating Time (ms)
20 15 10 5 0 0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-3 Operating time of single-phase fault (60Hz, SIR=1)
35 30 25 Operating Time (ms)
20 15 10 5 0 0
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-4 Operating time of two-phase fault (50Hz, SIR=1)
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30 25 Operating Time (ms)
20 15 10 5 0 0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-5 Operating time of two-phase fault (60Hz, SIR=1)
35 30 25 Operating Time (ms)
20 15 10 5 0 0
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-6 Operating time of three-phase fault (50Hz, SIR=1)
3-25
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30 25 Operating Time (ms)
20 15 10 5 0 0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-7 Operating time of three-phase fault (60Hz, SIR=1)
33 32.5 32 Operating Time (ms)
31.5
31 30.5
30 29.5
29 0%
10%
20%
30%
40%
50%
60%
70%
80%
90% 100%
Fault Location (% of relay setting)
Figure 3.6-8 Operating time of single-phase fault (50Hz, SIR=30)
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27.5 27 Operating Time (ms)
26.5 26 25.5 25 24.5 24 0%
10%
20%
30%
40%
50%
60%
70%
80%
90% 100%
Fault Location (% of relay setting)
Figure 3.6-9 Operating time of single-phase fault (60Hz, SIR=30)
45 40 35 Operating Time (ms)
30 25 20 15 10 5 0 0
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-10 Operating time of two-phase fault (50Hz, SIR=30)
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35 30 Operating Time (ms)
25 20 15 10 5 0 0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-11 Operating time of two-phase fault (60Hz, SIR=30)
33 32 Operating Time (ms)
31 30 29 28 27 0
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Fault Location (% of relay setting)
Figure 3.6-12 Operating time of three-phase fault (50Hz, SIR=30)
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27.5 27 Operating Time (ms)
26.5 26
25.5 25
24.5 24
23.5 0%
10%
20%
30%
40%
50%
60%
70%
80%
90% 100%
Fault Location (% of relay setting)
Figure 3.6-13 Operating time of three-phase fault (60Hz, SIR=30)
3.6.3 DPFC Distance Protection The power system is normally treated as a balanced symmetrical three-phase network. When a fault occurs in the power system, by applying the principle of superposition, the load current and voltage can be calculated in the system prior to the fault and the pure fault component can be calculated by fault current or voltage subtracted by pre-fault load current or voltage. DPFC distance protection concerns change of current and voltage at power frequency, therefore, DPFC distance protection is not influenced by load current. As an independent fast protection, DPFC distance protection is mainly used to clear close up fault of long line quickly, its protected range can set as 80%~85% of the whole line. Since DPFC distance protection only reflects fault component and is not influenced by current change due to load variation and power swing, power swing blocking (PSB) is this not required. Moreover, there is no transient overreaching due to infeed current from the remote power supply because it is not influenced by load current. DPFC distance protection may not overreach, and its protected zone will be inverse-proportion reduced with system impedance behind it, i.e. the protected zone will be less than setting if the system impedance is greater. The protected zone will be close to setting value if the system impedance is smaller. Therefore, DPFC distance protection is usually used for long transmission line with large power source and it is recommended to disable DPFC distance protection for short line or the line with weak power source.
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3.6.3.1 Impedance Characteristic ZZD M
EM
F
Z
N
EN
∆I ZS
ZK
jX
Zzd Zk
Φ
Zs+Zk
R
-Zs
Figure 3.6-14 Operation characteristic for forward fault
Where: ZZD: the setting of DPFC distance protection ZS: total impedance between local system and device location ZK: measurement impedance Φ: positive-sequence sensitive angle, i.e. [phi1_Reach] Figure 3.6-14 shows the operation characteristic of DPFC distance protection on R-X plane when a fault occurs in forward direction, which is the circle with the –Zs as the center and the│Zs+Zzd│ as the radius. When measured impedance Z k is in the circle, DPFC distance protection will operate. DPFC distance protection has a larger capability of enduring fault resistance than distance protection using positive-sequence as polarized voltage.
3-30
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3 Operation Theory ZZD F
M
EM
N
Z
EN
∆I ZK Z′S
jX
Z's
Zzd
Φ
R
-Zk
Figure 3.6-15 Operation characteristic for reverse fault
Z'S:total impedance between remote system and protective device location Figure 3.6-15 shows the operation characteristic of the DPFC distance element on R-X plane when a fault occurs in reverse direction, which is the circle with the Z′S as the center and the│Z′S-Zzd│as the radius. The region of operation is in the quadrant 1 but the measured impedance -Zk is always in the quadrant 3, the DPFC distance protection will not operate. The DPFC distance protection can be enabled or disabled by logic setting and binary input. 3.6.3.2 Function Block Diagram
21D 21D.En
21D.Op
21D.Blk
21D.On
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3.6.3.3 I/O Signals Table 3.6-1 I/O signals of DPFC distance protection No.
Input Signal
1
21D.En
2
21D.Blk
No.
Description DPFC distance protection enabling input, it is triggered from binary input or programmable logic etc. DPFC distance protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
21D.Op_Set
DPFC distance protection operates.
2
21D.On
DPFC distance protection is enabled.
3.6.3.4 Logic EN
[21D.En]
21D.On
&
SIG
21D.En
SIG
21D.Blk
SIG
FD.Pkp
EN
[VTS.En_Out_VT]
SIG
Manual closing signal
SIG
3-pole reclosing signal
SET
[21D.Z_Set]<0.05Ω/In
SET
ZΦ<[21D.Z_Set]
SIG
UP<0.85Un
SET
ZΦΦ<[21D.Z_Set]
SIG
UPP<0.85Unn
SIG
PD signal
&
>=1
& >=1
& 21D.Op
& &
Figure 3.6-16 Logic diagram of DPFC distance protection
Note!
PD signal only blocks DPFC distance element of corresponding phase (i.e. broken phase), and healthy phases (operation phases) are not affected.
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3.6.3.5 Settings Table 3.6-2 Settings of DPFC distance protection No. 1
Name 21D.Z_Set
Range
Step
Unit
(0.000~4Unn)/In
0.001
ohm
Remark Impedance setting of DPFC distance protection Enabling/disabling
2
21D.En
DPFC
distance
protection
0 or 1
0: disable 1: enable
3.6.4 Load Encroachment 3.6.4.1 Impedance Characteristic When distance protection is used to protect long, heavily loaded lines, the risk of encroachment of the load impedance into the tripping characteristic of the distance protection may exist. A load trapezoid characteristic for all zones is used to exclude the risk of unwanted fault detection by the distance protection during heavy load flow. As shown below, if the measured impedance into the load area, distance elements need to be blocked.
jX
φLoad
φLoad
Load Area
Load Area
R RLoad
RLoad
Figure 3.6-17 Distance element with load trapezoid
Two settings are equipped to exclude the encroachment of the load impedance: RLoad: the minimum load resistance φLoad: the load area angle These values are common for all zones.
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3.6.4.2 Function Block Diagram
LoadEnch LoadEnch.En
LoadEnch.St
LoadEnch.Blk
LoadEnch.On
3.6.4.3 I/O Signals Table 3.6-3 I/O signals of load encroachment No.
Input Signal
1
LoadEnch.En
2
LoadEnch.Blk
No.
Description Load trapezoid characteristic enabling input, it is triggered from binary input or programmable logic etc. Load trapezoid characteristic blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description Measured impedance into the load area. If load trapezoid characteristic is enabled and measured impedance into the load
1
LoadEnch.St
area, LoadEnch.St=1, If measured impedance is out of the load area or load trapezoid characteristic is disabled, LoadEnch.St=0
2
LoadEnch.On
Load trapezoid characteristic is enabled.
3.6.4.4 Settings Table 3.6-4 Settings of load encroachment No.
Name
Range
Step
Unit
Remark Angle
setting
characteristic, 1
LoadEnch.phi_Blinder
0~45
1
Deg
of it
load should
trapezoid be
set
according to the maximum load area angle
(φLoad_Max),
φLoad_Max+5° is
recommended. Resistance setting of load trapezoid 2
LoadEnch.R_Blinder
(0.05~200)/In
0.01
ohm
characteristic,
it
according
the
to
should
be
minimum
set load
resistance, 70%~90% minimum load resistance is recommended. Enabling/disabling 3
LoadEnch.En
load
trapezoid
characteristic
0,1
0: disable 1: enable
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3.6.5 Mho Distance Protection 3.6.5.1 Impedance Characteristic 1.
Zone 1, 2 and 3 of phase-to-ground distance element ZZD M
EM
F
Z
N
IN
EN
I ZS
ZK
jX
ZZD
ZK Φ
R
-2ZS/3
Figure 3.6-18 Phase-to-ground operation characteristic for forward fault
Where: ZZD: the setting of distance protection ZS: total impedance between local system and protective device location ZK: measurement impedance Φ: positive-sequence sensitive angle, i.e. [phi1_Reach] Phase-to-neutral positive sequence voltage is used as polarized signal for phase-to-ground distance protection. For zone 1 and zone 2: Operation voltage:
Polarized voltage: 3-35
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In short line, phase shift θ1 could be applied to the polarized voltage to improve the performance against high resistance fault. The device provides an angle-shift setting, [ZG.phi_Shift], to set value of θ1 among 0°, 15°and 30°. Their impedance shift characteristics towards quadrant 1 are respectively shown as the impedance circle A, B and C in Figure 3.6-23. For zone 3: Operation voltage:
Polarized voltage: UPΦ uses phase positive-sequence voltage as polarized voltage. For earth fault, positive-sequence voltage is mainly formed from healthy phases, basically retaining the phase of the positive-sequence voltage before fault. Phase comparison equation is:
The operation characteristic is shown in Figure 3.6-18. Operation characteristic of ZK on R-X plane is a circle with line connecting ends of ZZD and -2ZS/3 as the diameter. The origin is enclosed in the circle. 2.
Zone 1, 2 and 3 of phase-to-phase distance element jX
ZZD
ZK Φ
R
-ZS/2
Figure 3.6-19 Phase-to-phase operation characteristic for forward fault
Phase-to-phase positive sequence voltage is used as polarized signal for phase-to-phase distance protection. For zone 1 and zone 2: 3-36
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3 Operation Theory
Operation voltage:
Polarized voltage: Phase shift θ2 could be applied to polarized voltage of zones 1 and 2 just like θ1 in phase-to-ground distance element. It is also used for improving performance against high resistance fault in short line. The device provides an angle-shift setting, [21M.ZP.phi_Shift], to set value of θ2 among 0°, 15°and 30°. Their impedance shift characteristics towards quadrant 1 are respectively shown as the impedance circle A, B and C in Figure 3.6-23. For zone 3: Operation voltage:
Polarized voltage: Phase-to-phase positive-sequence voltage is applied as the polarized voltage of this element. Phase comparison equation is:
The operation characteristic of phase-to-phase distance element is shown in Figure 3.6-19. Operation characteristic of ZK on R-X plane is a circle with line connecting ends of Z ZD and -ZS/2 as the diameter. The origin is enclosed in the circle. Figure 3.6-20 shows operation characteristic of measured impedance -ZK on R-X plane when an asymmetric reverse fault occurs. This characteristic is a circle with line connecting ends of Z ZD and Z'S as the diameter. It will operate only when -ZK is in the circle. Therefore, directionality of the distanced protection is achieved. ZZD F EM
M
N
Z
EN
IΦ ZK Z′S
3-37
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ZZD
Φ R -ZK
Figure 3.6-20 Operation characteristic for reverse fault
Z'S: total impedance between remote system and protective device location jX
ZZD
ZK Φ
R
Figure 3.6-21 Steady-state characteristic of three-phase short-circuit fault
Phase-to-phase distance protection is also used for three-phase short-circuit fault. The operation characteristic is shown in Figure 3.6-21. Operation characteristic of ZK on R-X plane is a circle with setting impedance ZZD as the diameter.
3-38
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ZZD
ZK Φ
R Circle C -ZS
Circle B Circle A
Figure 3.6-22 Operation characteristic of three-phase close up short-circuit fault
Where: ZZD: the setting of distance protection (zone x) ZS: total impedance between local system and protective device location ZK: measured impedance Φ: positive-sequence characteristic angle, i.e. [phi1_Reach] Circle A: transient characteristic Circle B: steady-state characteristic shifting towards quadrant Ⅲ Circle C: steady-state characteristic shifting towards quadrant Ⅰ As shown in Figure 3.6-22, the characteristic of the distance protection for a three-phase fault on a system is an impedance circle cross the origin, and there is a voltage dead zone around the origin. In order to eliminate the dead zone of the distance protection for a close up three-phase fault memorized positive-sequence voltage is adopted as polarized voltage when the positive-sequence voltage drops down to 15%Un or below. The transient (during process of memory) operation characteristic is shown as the impedance circle A in the above figure. The circle takes Z ZD and -ZZS as diameter and thus the origin is within the impedance circle. When three-phase fault happens in reverse direction, its transient characteristic is shown in Figure 3.6-20, i.e. the distance protection has a clearly defined directionality and no dead zone during the process of memory. For zone 1, zone 2 and zone 3 of the phase-to-phase distance protection, if distance protection operates with memorized polarizing voltage, this means a close up forward fault. When the memory fades out, the operation characteristic will be reverse offset a little to enclose the origin as impedance circle B shown in Figure 3.6-22 to ensure keeping operating of distance protection until the fault being cleared. If distance protection does not operate with memorized polarizing voltage, 3-39
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3 Operation Theory
it will be a close up reverse fault. When the memory fades out, the operation characteristic will be forward offset not to enclose the origin as impedance circle C shown in Figure 3.6-22, and the distance protection will not mal-operate even if voltage is zero. The distance protection with such design thoroughly eliminates the dead zone when three-phase close up fault occurs. It also has favorable directivity and will not operate for a reverse three-phase fault at busbar. When receiving manual closing signal or 3-pole reclosing signal, the operation characteristic of phase to phase distance protection will always enclose the origin of impedance, with no dead zone, i.e. the reverse offset impedance circle B shown in Figure 3.6-22. jX B: 15° C: 30° ZZD
A: 0° D
R
-ZS
Figure 3.6-23 Shift impedance characteristic of zone 1 and zone 2
The impedance characteristic of phase-to-ground distance protection is the circle with line connecting ends of ZZD and -2ZS/3 as the diameter and that of phase-to-phase distance is the circle with line connecting ends of ZZD and -ZS/2 as the diameter. In order to prevent the transient overreach caused by the infeed power supply from the remote end, the zero-sequence reactance line D is added. These measures have enhanced the capacity against fault resistance when using distance protection in short lines. 3.
Zone 4 ZZDR F
ZZDF M
I
Z
EM
N
EN ZK
3-40
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ZZDF
Φ
R
ZK
ZZDR
Figure 3.6-24 Operation characteristic of reverse Z4 distance protection
Where: ZZDF: impedance setting of zone 4 in forward direction, i.e. [21M.Z4.Z_Fwd] ZZDR: impedance setting of zone 4 in reverse direction, i.e. [21M.Z4.Z_Rev] Φ: positive-sequence characteristic angle, i.e. [phi1_Reach] ZK: measurement impedance When a fault occurs on the rear busbar, reverse distance element is provided to clear it with definite time delay and is taken as backup protection for reverse busbar fault. Its operation characteristic is shown in Figure 3.6-24.
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3.6.5.2 Function Block Diagram 21M 21M.En
21M.Z1.On
21M.Blk
21M.Z2.On
21M.ZGx.En
21M.Z3.On
21M.ZPx.En
21M.Z4.On
21M.ZGx.Blk
21M.Z1.Op
21M.ZPx.Blk
21M.Z2.Op
21M.Zx.En_ShortDly
21M.Z3.Op
21M.Zx.Blk_ShortDly
21M.Z4.Op
21M.Z1.En_Instant
3.6.5.3 I/O Signals Table 3.6-5 I/O signals of distance protection (Mho) No.
Input Signal
Description Distance protection enabling input, it is triggered from binary input or
1
21M.En
2
21M.Blk
3
21M.ZGx.En
4
21M.ZGx.Blk
5
21M.ZPx.En
6
21M.ZPx.Blk
7
21M.Zx.En_ShortDly
Enable accelerating zone x of distance protection (x=2, 3)
8
21M.Zx.Blk_ShortDly
Accelerating zone x of distance protection is disabled (x=2, 3)
9
21M.Z1.En_Instant
Enable zone 1 of distance protection operates without time delay
No.
programmable logic etc. Distance protection blocking input, it is triggered from binary input or programmable logic etc. Zone x of phase-to-ground distance protection enabling input, default value is “1” (x=1, 2, 3, 4) Zone x of phase-to-ground distance protection blocking input, default value is “0” (x=1, 2, 3, 4) Zone x of phase-to-phase distance protection enabling input, default value is “1” (x=1, 2, 3, 4) Zone x of phase-to-phase distance protection blocking input, default value is
Output Signal
“0” (x=1, 2, 3, 4)
Description
1
21M.Z1.On
Zone 1 of distance protection is enabled
2
21M.Z2.On
Zone 2 of distance protection is enabled
3
21M.Z3.On
Zone 3 of distance protection is enabled
4
21M.Z4.On
zone 4 of distance protection is enabled
5
21M.Z1.Op
Zone 1 of distance protection operates
6
21M.Z2.Op
Zone 2 of distance protection operates
3-42
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21M.Z3.Op
Zone 3 of distance protection operates
8
21M.Z4.Op
zone 4 of distance protection operates
3.6.5.4 Logic SIG
21M.En
SIG
VTS.Alm
SIG
21M.Blk
EN
[VTS.En_Out_VT]
& 21M.Enable
>=1
Figure 3.6-25 Logic diagram of enabling distance protection (Mho)
SIG
21M.Enable
SIG
21M.ZG1.En
EN
[21M.ZG1.En]
SIG
21M.ZG1.Blk
SIG
21M.ZP1.En
& 21M.ZG1.Enable
& &
21M.ZP1.Enable
&
EN
[21M.ZP1.En]
SIG
21M.ZP1.Blk
SIG
21M.Z1.Rls_PSBR
SIG
FD.Pkp
SIG
21M.ZG1.Enable
SIG
Flag.21M.ZG1
SIG
LoadEnch.St (PG)
SET
3I0>[FD.ROC.3I0_Set]
SIG
Flag.21M.ZP1
SIG
LoadEnch.St (PP)
SIG
21M.ZP1.Enable
SIG
FD.Pkp
SIG
21M.Z1.En_Instant
SIG
21M.ZG1.Op
SIG
21M.ZP1.Op
>=1 21M.Z1.On
& & [21M.ZG1.t_Op]
&
0
>=1 21M.ZG1.Op
&
& >=1 21M.Z1.Flg_PSBR
& &
[21M.ZP1.t_Op]
&
0
&
>=1 21M.ZP1.Op
>=1 21M.Z1.Op
Figure 3.6-26 Logic diagram of distance protection (Mho zone 1)
3-43
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Where: 21M.Z1.Rls_PSBR: Please refer to Figure 3.6-38. Flag.21M.ZG1 means that measured impedance by zone 1 of phase-to-ground distance protection is within the range determined by the setting [21M.ZG1.Z_Set]. Flag.21M.ZP1 means that measured impedance by zone 1 of phase-to-phase distance protection is within the range determined by the setting [21M.ZP1.Z_Set]. LoadEnch.St (PG) means that load trapezoid characteristic for distance element is enabled and measured phase-to-ground impedance into the load area. LoadEnch.St (PP) means that load trapezoid characteristic for distance element is enabled and measured phase-to-phase impedance into the load area. SIG
21M.Enable
SIG
21M.ZG2.En
EN
[21M.ZG2.En]
SIG
21M.ZG2.Blk
SIG
21M.ZP2.En
& 21M.ZG2.Enable
&
& 21M.ZP2.Enable
&
EN
[21M.ZP2.En]
SIG
21M.ZP2.Blk
SIG
21M.Z2.En_ShortDly
SIG
21M.Z2.Blk_ShortDly
EN
[21M.Z2.En_ShortDly]
SIG
21M.Z2.Enable_ShortDly
SIG
21M.Z2.Rls_PSBR
SIG
FD.Pkp
>=1
21M.Z2.On
& & 21M.Z2.Enable_ShortDly
& [21M.ZG2.t_ShortDly]
0
&
>=1 21M.ZG2.Op
& SIG
21M.ZG2.Enable
SIG
Flag.21M.ZG2
SIG
LoadEnch.St (PG)
[21M.ZG2.t_Op]
0
& >=1
&
SET
3I0>[FD.ROC.3I0_Set]
SIG
Flag.21M.ZP2
SIG
LoadEnch.St (PP)
SIG
21M.ZP2.Enable
21M.Z2.Flg_PSBR
& & [21M.ZP2.t_Op]
0
>=1
&
21M.ZP2.Op
& [21M.ZP2.t_ShortDly]
SIG
FD.Pkp
SIG
21M.Z2.Enable_ShortDly
SIG
21M.ZG2.Op
SIG
21M.ZP2.Op
0
>=1 21M.Z2.Op
Figure 3.6-27 Logic diagram of distance protection (Mho zone 2) 3-44
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3 Operation Theory
Where: 21M.Z2.Rls_PSBR: Please refer to Figure 3.6-38. Flag.21M.ZG2 means that measured impedance by zone 2 of phase-to-ground distance protection is within the range determined by the setting [21M.ZG2.Z_Set]. Flag.21M.ZP2 means that measured impedance by zone 2 of phase-to-phase distance protection is within the range determined by the setting [21M.ZP2.Z_Set]. SIG
21M.Enable
SIG
21M.ZG3.En
EN
[21M.ZG3.En]
SIG
21M.ZG3.Blk
SIG
21M.ZP3.En
& 21M.ZG3.Enable
&
& 21M.ZP3.Enable
&
EN
[21M.ZP3.En]
SIG
21M.ZP3.Blk
SIG
21M.Z3.En_ShortDly
SIG
21M.Z3.Blk_ShortDly
EN
[21M.Z3.En_ShortDly]
SIG
21M.Z3.Enable_ShortDly
SIG
21M.Z3.Rls_PSBR
SIG
FD.Pkp
SIG
21M.ZG3.Enable
SIG
Flag.21M.ZG3
SET
3I0>[FD.ROC.3I0_Set]
SIG
LoadEnch.St (PG)
SIG
Flag.21M.ZP3
SIG
LoadEnch.St (PP)
SIG
21M.ZP3.Enable
>=1 21M.Z3.On
& & 21M.Z3.Enable_ShortDly
& [21M.ZG3.t_ShortDly]
0
>=1 21M.ZG3.Op
& & [21M.ZG3.t_Op]
0
& >=1 21M.Z3.Flg_PSBR
& & [21M.ZP3.t_Op]
0
>=1 &
21M.ZP3.Op
& [21M.ZP3.t_ShortDly] 0
SIG
FD.Pkp
SIG
21M.Z3.Enable_ShortDly
SIG
21M.ZG3.Op
SIG
21M.ZP3.Op
>=1 21M.Z3.Op
Figure 3.6-28 Logic diagram of distance protection (Mho zone 3)
Where: 21M.Z3.Rls_PSBR: Please refer to Figure 3.6-38. 3-45
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3 Operation Theory
Flag.21M.ZG3 means that measured impedance by zone 3 of phase-to-ground distance protection is within the range determined by the setting [21M.ZG3.Z_Set]. Flag.21M.ZP3 means that measured impedance by zone 3 of phase-to-phase distance protection is within the range determined by the setting [21M.ZP3.Z_Set]. SIG
21M.Enable
SIG
21M.ZG4.En
EN
[21M.ZG4.En]
SIG
21M.ZP4.Blk
SIG
21M.ZP4.En
EN
[21M.ZP4.En]
SIG
21M.ZP4.Blk
SIG
FD.Pkp
SIG
21M.ZG4.Enable
SET
3I0>[FD.ROC.3I0_Set]
SIG
LoadEnch.St (PG)
SIG
Flag.21M.ZG4
SIG
Flag.21M.ZP4
SIG
LoadEnch.St (PP)
SIG
21M.ZP4.Enable
SIG
FD.Pkp
SIG
21M.ZG4.Op
SIG
21M.ZP4.Op
& 21M.ZG4.Enable
& &
21M.ZP4.Enable
& >=1 21M.Z4.On
& & [21M.ZG4.t_Op]
0
21M.ZG4.Op
& >=1 21M.Z4.Flg_PSBR
& & [21M.ZP4.t_Op]
0
21M.ZP4.Op
&
>=1 21M.Z4.Op
Figure 3.6-29 Logic diagram of distance protection (Mho zone 4)
Where: Flag.21M.ZG4 means that measured impedance by zone 4 of phase-to-ground distance protection is within the range determined by the settings [21M.Z4.Z_Fwd] and [21M.Z4.Z_Rev]. Flag.21M.ZP4 means that measured impedance by zone 4 of phase-to-phase distance protection is within the range determined by the settings [21M.Z4.Z_Fwd] and [21M.Z4.Z_Rev].
3-46
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.6.5.5 Settings Table 3.6-6 Settings of distance protection (Mho) No.
Name
Range
Step
Unit
1
21M.ZG.phi_Shift
0, 15 or 30
Deg
2
21M.ZP.phi_Shift
0, 15 or 30
Deg
3
21M.ZG1.Z_Set
(0.000~4Unn)/In
0.001
ohm
4
21M.ZG1.t_Op
0.000~10.000
0.001
s
Remark Phase
shift
of
21M.ZG1.En
1,
2
of
phase-to-ground distance protection Phase
shift
of
zone
1,
2
of
phase-to-phase distance protection Impedance setting of zone 1 of phase-to-ground distance protection Time
delay
of
zone
1
of
phase-to-ground distance protection Enabling/disabling
5
zone
zone
1
of
phase-to-ground distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-ground
zone 1 of distance protection operation 6
21M.ZG1.En_BlkAR
0 or 1
to block AR 0: disable 1: enable
7
21M.ZP1.Z_Set
(0.000~4Unn)/In
0.001
ohm
8
21M.ZP1.t_Op
0.000~10.000
0.001
s
Impedance setting of zone 1 of phase-to-phase distance protection Time
delay
of
21M.ZP1.En
1
of
phase-to-phase distance protection Enabling/disabling
9
zone
zone
1
of
phase-to-phase distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-phase
zone 1 of distance protection operation 10
21M.ZP1.En_BlkAR
0 or 1
to block AR 0: disable 1: enable
11
21M.ZG2.Z_Set
(0.000~4Unn)/In
0.001
ohm
12
21M.ZG2.t_Op
0.000~10.000
0.001
s
13
21M.ZG2.t_ShortDly
0.000~10.000
0.001
s
Impedance setting of zone 2 of phase-to-ground distance protection Time
delay
of
21M.ZG2.En
2
of
phase-to-ground distance protection Short
time delay of
zone 2
of
phase-to-ground distance protection Enabling/disabling
14
zone
zone
2
of
phase-to-ground distance protection
0 or 1
0: disable 1: enable 3-47
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory Enabling/disabling
phase-to-ground
zone 2 of distance protection operation 15
21M.ZG2.En_BlkAR
0 or 1
to block AR 0: disable 1: enable
16
21M.ZP2.Z_Set
(0.000~4Unn)/In
0.001
ohm
17
21M.ZP2.t_Op
0.000~10.000
0.001
s
18
21M.ZP2.t_ShortDly
0.000~10.000
0.001
s
Impedance setting of zone 2 of phase-to-phase distance protection Time
delay
of
21M.ZP2.En
2
of
phase-to-phase distance protection Short
time delay of
zone 2
of
phase-to-phase distance protection Enabling/disabling
19
zone
zone
2
of
phase-to-phase distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-phase
zone 2 of distance protection operation 20
21M.ZP2.En_BlkAR
0 or 1
to block AR 0: disable 1: enable Fixed accelerate zone 2 of distance
21
21M.Z2.En_ShortDly
protection
0 or 1
0: disable 1: enable
22
21M.ZG3.Z_Set
(0.000~4Unn)/In
0.001
ohm
23
21M.ZG3.t_Op
0.000~10.000
0.001
s
24
21M.ZG3.t_ShortDly
0.000~10.000
0.001
s
Impedance setting of zone 3 of phase-to-ground distance protection Time
delay
of
21M.ZG3.En
3
of
phase-to-ground distance protection Short
time delay of
zone
3
of
phase-to-ground distance protection Enabling/disabling
25
zone
zone
3
of
phase-to-ground distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-ground
zone 3 of distance protection operation 26
21M.ZG3.En_BlkAR
0 or 1
to block AR 0: disable 1: enable
27
21M.ZP3.Z_Set
(0.000~4Unn)/In
0.001
ohm
28
21M.ZP3.t_Op
0.000~10.000
0.001
s
29
21M.ZP3.t_ShortDly
0.000~10.000
0.001
s
3-48
Impedance setting of zone 3 of phase-to-phase distance protection Time
delay
of
zone
3
of
phase-to-phase distance protection Short
time delay of
zone
3
of
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory phase-to-phase distance protection Enabling/disabling 30
21M.ZP3.En
zone
3
of
phase-to-phase distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-phase
zone 3 of distance protection operation 31
21M.ZP3.En_BlkAR
0 or 1
to block AR 0: disable 1: enable Fixed accelerate zone 3 of distance
32
21M.Z3.En_ShortDly
protection
0 or 1
0: disable 1: enable
33
21M.Z4.Z_Fwd
(0.000~4Unn)/In
0.001
ohm
34
21M.Z4.Z_Rev
(0.000~4Unn)/In
0.001
ohm
35
21M.Z4.t_Op
0.000~10.000
0.001
s
Impedance setting of zone 4 of distance protection in forward direction Impedance setting of zone 4 of distance protection in reverse direction Time delay of zone 4 of distance protection Enabling/disabling
36
21M.ZG4.En
zone
4
of
phase-to-ground distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-ground
zone 4 of distance protection operation 37
21M.ZG4.En_BlkAR
to block AR (Internal setting, its default
0 or 1
value is “1”) 0: disable 1: enable Enabling/disabling
38
21M.ZP4.En
zone
4
of
phase-to-phase distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-phase
zone 4 of distance protection operation 39
21M.ZP4.En_BlkAR
to block AR (Internal setting, its default
0 or 1
value is “1”) 0: disable 1: enable
3-49
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.6.6 Quadrilateral Distance Protection 3.6.6.1 Impedance Characteristic Features available with quadrilateral distance protection include 3 forward zones (zone 1~3) phase-to-ground or phase-to-phase distance elements and 1 reverse zone (zone 4) phase-to-ground or phase-to-phase distance element. Each zone can respectively enable or disable power swing blocking releasing. Quadrilateral distance protection will be disabled when VT circuit fails. 1.
Zone 1, 2 and 3
Quadrilateral forward distance element characteristic for zone 1, 2 and 3 is shown as follows:
jX A
ZZD θ
B α
φ φ
O
β
RZD C
R
Figure 3.6-30 Quadrilateral forward distance element characteristics
Where: ZZD: impedance setting in forward direction RZD: resistance setting in forward direction φ: line positive-sequence characteristic angle α: the angle of directional line in the second quadrant, fixed at 15 ° β: the angle of directional line in the fourth quadrant, fixed at 15 ° θ: downward offset angle of the reactance line AB, fixed at 12° 2.
Zone 4
When a fault occurs on the busbar at the back, reverse distance element zone 4 is provided to clear it with definite time delay and is used as backup protection for reverse busbar fault.
3-50
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
jX C RZD
O
β
φ
R
φ α
B
θ
ZZD
A
Figure 3.6-31 Quadrilateral reverse distance element characteristic
Where: ZZD: impedance setting in reverse direction RZD: resistance setting in reverse direction φ: positive-sequence characteristic angle, α: the angle of directional line, fixed at 15° β: the angle of directional line, fixed at 15° θ: downward offset angle of the reactance line AB, fixed at 12° For quadrilateral distance protection, the reactance line should consider downward offset angle θ as shown in Figure 3.6-30 and Figure 3.6-31. According to system status, the downward offset angle can be independently set for phase-to-ground distance element and phase-to-phase distance element. The downward offset angle of all zones can be settable by the corresponding settings [21Q.ZGx.RCA] and [21Q.ZPx.RCA]. (x=1, 2, 3, 4)
3-51
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
3.6.6.2 Function Block Diagram 21Q 21Q.En
21Q.Z1.On
21Q.Blk
21Q.Z2.On
21Q.ZGx.En
21Q.Z3.On
21Q.ZPx.En
21Q.Z4.On
21Q.ZGx.Blk
21Q.Z1.Op
21Q.ZPx.Blk
21Q.Z2.Op
21Q.Zx.En_ShortDly
21Q.Z3.Op
21Q.Zx.Blk_ShortDly
21Q.Z4.Op
21Q.Z1.En_Instant
3.6.6.3 I/O Signals Table 3.6-7 I/O signals of distance protection (Quad) No.
Input Signal
Description Distance protection enabling input, it is triggered from binary input or
1
21Q.En
2
21Q.Blk
3
21Q.ZGx.En
4
21Q.ZGx.Blk
5
21Q.ZPx.En
6
21Q.ZPx.Blk
7
21Q.Zx.En_ShortDly
Enable accelerating zone x of distance protection (x=2, 3)
8
21Q.Zx.Blk_ShortDly
Accelerating zone x of distance protection is disabled (x=2, 3)
9
21Q.Z1.En_Instant
Enable zone 1 of distance protection operates without time delay
No.
programmable logic etc. Distance protection blocking input, it is triggered from binary input or programmable logic etc. Zone x of phase-to-ground distance protection enabling input, default value is “1” (x=1, 2, 3, 4) Zone x of phase-to-ground distance protection blocking input, default value is “0” (x=1, 2, 3, 4) Zone x of phase-to-phase distance protection enabling input, default value is “1” (x=1, 2, 3, 4) Zone x of phase-to-phase distance protection blocking input, default value is “0”
Output Signal
(x=1, 2, 3, 4)
Description
1
21Q.Z1.On
Zone 1 of distance protection is enabled
2
21Q.Z2.On
Zone 2 of distance protection is enabled
3
21Q.Z3.On
Zone 3 of distance protection is enabled
4
21Q.Z4.On
zone 4 of distance protection is enabled
5
21Q.Z1.Op
Zone 1 of distance protection operates
6
21Q.Z2.Op
Zone 2 of distance protection operates
3-52
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 7
21Q.Z3.Op
Zone 3 of distance protection operates
8
21Q.Z4.Op
zone 4 of distance protection operates
3.6.6.4 Logic SIG
21Q.En
SIG
21Q.Blk
SIG
VTS.Alm
EN
[VTS.En_Out_VT]
& 21Q.Enable
>=1
Figure 3.6-32 Logic diagram of enabling distance protection (Quad) SIG
21Q.Enable
EN
[21Q.ZG1.En]
SIG
21Q.ZG1.En
SIG
21Q.ZG1.Blk
EN
[21Q.ZP1.En]
&
>=1 21Q.ZG1.Enable
&
21Q.Z1.On
& 21Q.ZP1.Enable
&
SIG
21Q.ZP1.En
SIG
21Q.ZP1.Blk
SIG
FD.Pkp
SIG
21Q.ZG1.Enable
SIG
LoadEnch.St (PG)
SET
3I0>[FD.ROC.3I0_Set]
SIG
Flag.21Q.ZG1
SIG
21Q.Z1.Rls_PSBR
SIG
FD.Pkp
& &
&
& [21Q.ZG1.t_Op]
0
>=1 21Q.ZG1.Op
& >=1
&
SIG
21Q.ZP1.Enable
SIG
LoadEnch.St (PP)
SIG
Flag.21Q.ZP1
21Q.Z1.Flg_PSBR
& & [21Q.ZP1.t_Op]
0
>=1
&
SIG
21Q.Z1.En_Instant
SIG
21Q.ZG1.Op
SIG
21Q.ZP1.Op
21Q.ZP1.Op
>=1 21Q.Z1.Op
Figure 3.6-33 Logic diagram of distance protection (Quad zone 1)
Where: 21Q.Z1.Rls_PSBR: Please refer to Figure 3.6-38.
3-53
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Flag.21Q.ZG1 means that measured impedance by zone 1 of phase-to-ground distance protection is within the range determined by the settings [21Q.ZG1.Z_Set] and [21Q.ZG1.R_Set]. Flag.21Q.ZP1 means that measured impedance by zone 1 of phase-to-phase distance protection is within the range determined by the settings [21Q.ZP1.Z_Set] and [21Q.ZP1.R_Set]. LoadEnch.St (PG) means that load trapezoid characteristic for distance element is enabled and measured phase-to-ground impedance into the load area. LoadEnch.St (PP) means that load trapezoid characteristic for distance element is enabled and measured phase-to-phase impedance into the load area. SIG
21Q.Enable
EN
[21Q.ZG2.En]
SIG
21Q.ZG2.En
SIG
21Q.ZG2.Blk
EN
[21Q.ZP2.En]
&
>=1 21Q.ZG2.Enable
&
21Q.Z2.On
& 21Q.ZP2.Enable
&
SIG
21Q.ZP2.En
SIG
21Q.ZP2.Blk
SIG
21Q.Z2.En_ShortDly
SIG
21Q.Z2.Blk_ShortDly
EN
[21Q.Z2.En_ShortDly]
SIG
21Q.Z2.Enable_ShortDly
SIG
FD.Pkp
SIG
21Q.ZG2.Enable
& & 21Q.Z2.Enable_ShortDly
& &
SET
&
3I0>[FD.ROC.3I0_Set]
SIG
LoadEnch.St (PG)
SIG
Flag.21Q.ZG2
SIG
21Q.Z2.Rls_PSBR
SIG
21Q.ZP2.Enable
SIG
LoadEnch.St (PP)
SIG
Flag.21Q.ZP2
SIG
21Q.ZG2.Op
SIG
21Q.ZP2.Op
[21Q.ZG2.t_ShortDly] 0
&
>=1 21Q.ZG2.Op
& [21Q.ZG2.t_Op]
0
>=1 21Q.Z2.Flg_PSBR
&
& [21Q.ZP2.t_ShortDly] 0
&
>=1 21Q.ZP2.Op
[21Q.ZP2.t_Op]
0
>=1 21Q.Z2.Op
Figure 3.6-34 Logic diagram of distance protection (Quad zone 2)
Where: 21Q.Z2.Rls_PSBR: Please refer to Figure 3.6-38. Flag.21Q.ZG2 means that measured impedance by zone 2 of phase-to-ground distance protection is within the range determined by the settings [21Q.ZG2.Z_Set] and [21Q.ZG2.R_Set]. 3-54
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
Flag.21Q.ZP2 means that measured impedance by zone 2 of phase-to-phase distance protection is within the range determined by the settings [21Q.ZP2.Z_Set] and [21Q.ZP2.R_Set]. SIG
21Q.Enable
EN
[21Q.ZG3.En]
SIG
21Q.ZG3.En
SIG
21Q.ZG3.Blk
EN
[21Q.ZP3.En]
&
>=1 21Q.ZG3.Enable
&
21Q.Z3.On
& 21Q.ZP3.Enable
&
SIG
21Q.ZP3.En
SIG
21Q.ZP3.Blk
SIG
21Q.Z3.En_ShortDly
SIG
21Q.Z3.Blk_ShortDly
EN
[21Q.Z3.En_ShortDly]
SIG
21Q.Z3.Enable_ShortDly
SIG
FD.Pkp
SIG
21Q.ZG3.Enable
SET
3I0>[FD.ROC.3I0_Set]
SIG
LoadEnch.St (PG)
SIG
Flag.21Q.ZG3
SIG
21Q.Z3.Rls_PSBR
SIG
FD.Pkp
& & 21Q.Z3.Enable_ShortDly
& & &
& [21Q.ZG3.t_ShortDly] 0
&
>=1 21Q.ZG3.Op
[21Q.ZG3.t_Op]
SIG
21Q.ZP3.Enable
SIG
LoadEnch.St (PP)
SIG
Flag.21Q.ZP3
SIG
21Q.ZG3.Op
SIG
21Q.ZP3.Op
0
>=1
&
21Q.Z3.Flg_PSBR
&
& [21Q.ZP3.t_ShortDly] 0
&
>=1 21Q.ZP3.Op
[21Q.ZP3.t_Op]
0
>=1 21Q.Z3.Op
Figure 3.6-35 Logic diagram of distance protection (Quad zone 3)
Where: 21Q.Z3.Rls_PSBR: Please refer to Figure 3.6-38. Flag.21Q.ZG3 means that measured impedance by zone 3 of phase-to-ground distance protection is within the range determined by the settings [21Q.ZG3.Z_Set] and [21Q.ZG3.R_Set]. Flag.21Q.ZP3 means that measured impedance by zone 3 of phase-to-phase distance protection is within the range determined by the settings [21Q.ZP3.Z_Set] and [21Q.ZP3.R_Set].
3-55
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory SIG
21Q.Enable
EN
[21Q.ZG4.En]
SIG
21Q.ZG4.En
SIG
21Q.ZG4.Blk
EN
[21Q.ZP4.En]
&
>=1 21Q.ZG4.Enable
&
21Q.Z4.On
& 21Q.ZP4.Enable
&
SIG
21Q.ZP4.En
SIG
21Q.ZP4.Blk
SIG
FD.Pkp
SIG
21Q.ZG4.Enable
SET
3I0>[FD.ROC.3I0_Set]
SIG
LoadEnch.St (PG)
SIG
Flag.21Q.ZG4
SIG
FD.Pkp
SIG
21Q.ZP4.Enable
SIG
LoadEnch.St (PP)
SIG
Flag.21Q.ZP4
SIG
21Q.ZG4.Op
SIG
21Q.ZP4.Op
& & [21Q.ZG4.t_Op]
0
21Q.ZG4.Op
& >=1 21Q.Z4.Flg_PSBR
& [21Q.ZP4.t_Op]
0
21Q.ZP4.Op
&
>=1 21Q.Z4.Op
Figure 3.6-36 Logic diagram of distance protection (Quad zone 4)
Where: Flag.21Q.ZG4 means that measured impedance by zone 4 of phase-to-ground distance protection is within the range determined by the settings [21Q.ZG4.Z_Set] and [21Q.ZG4.R_Set]. Flag.21Q.ZP4 means that measured impedance by zone 4 of phase-to-phase distance protection is within the range determined by the settings [21Q.ZP4.Z_Set] and [21Q.ZP4.R_Set]. 3.6.6.5 Settings Table 3.6-8 Settings of distance protection (Quad) No.
Name
Range
Step
Unit
Remark Downward
1
21Q.ZG1.RCA
0~45
1
Deg
reactance
offset line
angle for
zone
of
the 1
of
phase-to-ground distance protection 2
21Q.ZG1.Z_Set
(0.000~4Unn)/In
0.001
ohm
3-56
Impedance setting of zone 1 of phase-to-ground distance protection
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 3
21Q.ZG1.R_Set
(0.000~4Unn)/In
0.001
ohm
4
21Q.ZG1.t_Op
0.000~10.000
0.001
s
Resistance setting of zone 1 of phase-to-ground distance protection Time
delay
of
21Q.ZG1.En
1
of
phase-to-ground distance protection Enabling/disabling
5
zone
zone
1
of
phase-to-ground distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-ground
zone 1 of distance protection operation 6
21Q.ZG1.En_BlkAR
0 or 1
to block AR 0: disable 1: enable Downward
7
21Q.ZP1. RCA
0~45
1
Deg
reactance
offset line
angle for
of
zone
the 1
of
phase-to-phase distance protection 8
21Q.ZP1.Z_Set
(0.000~4Unn)/In
0.001
ohm
9
21Q.ZP1.R_Set
(0.000~4Unn)/In
0.001
ohm
10
21Q.ZP1.t_Op
0.000~10.000
0.001
s
Impedance setting of zone 1 of phase-to-phase distance protection Resistance setting of zone 1 of phase-to-phase distance protection Time
delay
of
21Q.ZP1.En
1
of
phase-to-phase distance protection Enabling/disabling
11
zone
zone
1
of
phase-to-phase distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-phase
zone 1 of distance protection operation 12
21Q.ZP1.En_BlkAR
0 or 1
to block AR 0: disable 1: enable Downward
13
21Q.ZG2.RCA
0~45
1
Deg
reactance
offset line
angle for
zone
of
the 2
of
phase-to-ground distance protection 14
21Q.ZG2.Z_Set
(0.000~4Unn)/In
0.001
ohm
15
21Q.ZG2.R_Set
(0.000~4Unn)/In
0.001
ohm
16
21Q.ZG2.t_Op
0.000~10.000
0.001
s
17
21Q.ZG2.t_ShortDly
0.000~10.000
0.001
s
18
21Q.ZG2.En
0 or 1
Impedance setting of zone 2 of phase-to-ground distance protection Resistance setting of zone 2 of phase-to-ground distance protection Time
delay
of
zone
2
of
phase-to-ground distance protection Short
time delay of
zone 2
of
phase-to-ground distance protection Enabling/disabling
zone
2
of
phase-to-ground distance protection 3-57
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 0: disable 1: enable Enabling/disabling
phase-to-ground
zone 2 of distance protection operation 19
21Q.ZG2.En_BlkAR
0 or 1
to block AR 0: disable 1: enable Downward
20
21Q.ZP2. RCA
0~45
1
Deg
reactance
offset line
angle for
of
zone
the 2
of
phase-to-phase distance protection 21
21Q.ZP2.Z_Set
(0.000~4Unn)/In
0.001
ohm
22
21Q.ZP2.R_Set
(0.000~4Unn)/In
0.001
ohm
23
21Q.ZP2.t_Op
0.000~10.000
0.001
s
24
21Q.ZP2.t_ShortDly
0.000~10.000
0.001
s
Impedance setting of zone 2 of phase-to-phase distance protection Resistance setting of zone 2 of phase-to-phase distance protection Time
delay
of
21Q.ZP2.En
2
of
Short time delay of zone 2 of phase-tophase distance protection Enabling/disabling
25
zone
phase-to-phase distance protection
zone
2
of
phase-to-phase distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-phase
zone 2 of distance protection operation 26
21Q.ZP2.En_BlkAR
0 or 1
to block AR 0: disable 1: enable Fixed accelerate zone 2 of distance
27
21Q.Z2. En_ShortDly
protection
0 or 1
0: disable 1: enable Downward
28
21Q.ZG3.RCA
0~45
1
Deg
reactance
offset line
angle for
of
zone
the 3
of
phase-to-ground distance protection 29
21Q.ZG3.Z_Set
(0.000~4Unn)/In
0.001
ohm
30
21Q.ZG3.R_Set
(0.000~4Unn)/In
0.001
ohm
31
21Q.ZG3.t_Op
0.000~10.000
0.001
s
32
21Q.ZG3.t_ShortDly
0.000~10.000
0.001
s
33
21Q.ZG3.En
0 or 1
Impedance setting of zone 3 of phase-to-ground distance protection Resistance setting of zone 3 of phase-to-ground distance protection Time
delay
of
zone
3
of
phase-to-ground distance protection Short
time delay of
zone
3
of
phase-to-ground distance protection Enabling/disabling
zone
3
of
phase-to-ground distance protection
3-58
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 0: disable 1: enable Enabling/disabling
phase-to-ground
zone 3 of distance protection operation 34
21Q.ZG3.En_BlkAR
0 or 1
to block AR 0: disable 1: enable Downward
35
21Q.ZP3. RCA
0~45
1
Deg
reactance
offset line
angle for
of
zone
the 3
of
phase-to-phase distance protection 36
21Q.ZP3.Z_Set
(0.000~4Unn)/In
0.001
ohm
37
21Q.ZP3.R_Set
(0.000~4Unn)/In
0.001
ohm
38
21Q.ZP3.t_Op
0.000~10.000
0.001
s
39
21Q.ZP3.t_ShortDly
0.000~10.000
0.001
s
Impedance setting of zone 3 of phase-to-phase distance protection Resistance setting of zone 3 of phase-to-phase distance protection Time
delay
of
Short
21Q.ZP3.En
3
of
time delay of
zone
3
of
phase-to-phase distance protection Enabling/disabling
40
zone
phase-to-phase distance protection
zone
3
of
phase-to-phase distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-phase
zone 3 of distance protection operation 41
21Q.ZP3.En_BlkAR
0 or 1
to block AR 0: disable 1: enable Fixed accelerate zone 3 of distance
42
21Q.Z3. En_ShortDly
protection
0 or 1
0: disable 1: enable Downward
43
21Q.ZG4.RCA
0~45
1
Deg
reactance
offset line
angle for
zone
of
the 4
of
phase-to-ground distance protection 44
21Q.ZG4.Z_Set
(0.000~4Unn)/In
0.001
ohm
45
21Q.ZG4.R_Set
(0.000~4Unn)/In
0.001
ohm
46
21Q.ZG4.t_Op
0.000~10.000
0.001
s
Impedance setting of zone 3 of phase-to-ground distance protection Resistance setting of zone 3 of phase-to-ground distance protection Time
delay
of
21Q.ZG4.En
4
of
phase-to-ground distance protection Enabling/disabling
47
zone
zone
4
of
phase-to-ground distance protection
0 or 1
0: disable 1: enable 3-59
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phase-to-ground
zone 4 of distance protection operation 48
21Q.ZG4.En_BlkAR
to block AR (Internal setting, its default
0 or 1
value is “1”) 0: disable 1: enable Downward
49
21Q.ZP4. RCA
0~45
1
Deg
reactance
offset line
angle for
zone
of
the 4
of
phase-to-phase distance protection 50
21Q.ZP4.Z_Set
(0.000~4Unn)/In
0.001
ohm
51
21Q.ZP4.R_Set
(0.000~4Unn)/In
0.001
ohm
52
21Q.ZP4.t_Op
0.000~10.000
0.001
s
Impedance setting of zone 3 of phase-to-phase distance protection Resistance setting of zone 3 of phase-to-phase distance protection Time
delay
of
Enabling/disabling 53
21Q.ZP4.En
zone
4
of
phase-to-phase distance protection zone
4
of
phase-to-phase distance protection
0 or 1
0: disable 1: enable Enabling/disabling
phase-to-phase
zone 4 of distance protection operation 54
21Q.ZP4.En_BlkAR
to block AR (Internal setting, its default
0 or 1
value is “1”) 0: disable 1: enable
3.6.7 Power Swing Detection Power swing is generally a dynamic process when power system is disturbed. When power swing occurs, the angle between the generators in parallel operation, the frequency of the system, the voltage on the bus, the current and power of the branch lines are all fluctuating. Power swing may destroy the normal operation of power systems and even damage electrical equipment, causing the system to collapse. 3.6.7.1 Function Block Diagram 68 68.En
68.St
68.Blk
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3.6.7.2 I/O Signals Table 3.6-9 I/O signals of power swing detection No.
Input Signal
Description Power swing detection enabling input, it is triggered from binary input or
1
68.En
2
68.Blk
3
21.St
Any element of distance protection picks up.
4
FD.ROC.Pkp
Residual current FD element operates.
5
52b
Circuit breaker is in closed position.
6
52a
Circuit breaker is in open position.
No. 1
programmable logic etc. Power swing detection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
68.St
Power swing detection takes into effect.
3.6.7.3 Logic EN
[68.En]
SIG
68.En
SIG
68.Blk
SIG
I1>[Y.I_PSBR]
SIG
21.St
SIG
FD.ROC.Pkp
SIG
3 CB Closed
SIG
3 CB open
SIG
Unblocking for SF
SIG
Unblocking for UF
& & &
& & t1
t2
& 68.St
& >=1
>=1
Figure 3.6-37 Logic diagram of power swing detection
Y: 21M or 21Q 3.6.7.4 Settings Table 3.6-10 Settings of power swing detection No.
Name
Range
Step
Unit
Remark Enabling/disabling power swing detection
1
68.En
0 or 1
0: disable 1: enable
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3.6.8 Power Swing Blocking Releasing When power swing occurs on the power system, the impedance measured by the distance measuring element may vary from the load impedance area into the operating zone of the distance element. The distance measuring element may operate due to the power swing occurs in many points of interconnected power systems. To keep the stability of whole power system, tripping due to operation of the distance measuring element during a power swing is generally not allowed. Our distance protection adopts power swing blocking releasing to avoid maloperation resulting from power swing. In another word, distance protection is blocked all along under the normal condition and power swing when the respective logic settings are enabled. Only when fault (internal fault or power swing with internal fault) is detected, power swing blocking for distance protection is released by PSBR element. Power swing blocking for distance element will be released if any of the following PSBR elements operates. Each distance zone elements has respective setting for selection this function.
Fault detector PSBR element (FD PSBR)
Unsymmetrical fault PSBR element (UF PSBR)
Symmetrical fault PSBR element (SF PSBR)
1.
Fault detector PSBR element
If any of the following condition is matched, FD PSBR will operate for 160ms. Positive sequence current is lower than the setting [I_PSBR] before general fault detector element operates. As shown in figure below, assume normal load impedance locates at position 1, and the impedance under current “I_PSBR” locates at position 2, if the condition for FD PSBR mentioned above operates, it means FD operates between point 1, point 2 and point 3 as example, then FD PSBR will operate for 160ms.
[I_PSBR] FD Normal load impedance
Point 1
Point 3
Point 2
2.
Unsymmetrical fault PSBR element
The operation criterion: I0+I2>m×I1 The “m”, an empirical value, is internal fixed coefficient which can ensure UF PSBR operation 3-62
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during power swing with internal unsymmetrical fault, while no operation during power swing or power swing with external fault. This decision mainly utilizes the "discrepancy" that there is no negative-sequence or zero-sequence current during power swing, and there are negative-sequence and zero-sequence currents in case of asymmetric fault. In addition, value of m is used to differentiate internal asymmetric fault and external asymmetric fault in case of power swing. In case of power swing or both power swing and external fault, asymmetric fault discriminating element will not operate and distance protection will be blocked: In case of power swing but no fault, I0 and I2 are near zero, but I1 is very large. Asymmetric fault discriminating element will not operate. In case of both power swing and external fault, if center of power swing is in scope of protection, both phase-to-phase and grounding impedance relays may operate. At this time, selection of value of m is used to ensure no operation of asymmetric fault discriminating element, blocking of distance protection, and no incorrect operation without selectivity. If power swing center is not on this line, distance protection will not operate incorrectly without selectivity due to power swing. In case of internal asymmetric fault, asymmetric fault discriminating element operates and distance protection will be release to clear internal fault: In case of both power swing and internal fault, if at the instant of short circuit, system electric potential angle is not laid out, asymmetric fault discriminating element will operate at once. If at the instant of short circuit, system electric potential angle is laid out, asymmetric fault discriminating element will operate when system angle gradually decreases, or local side tripping may be activated after immediate operation of opposite side asymmetric fault discriminating element and releasing of distance protection tripping. In case of normal internal asymmetric phase-to-phase or grounding fault in the system, relatively large zero-sequence or negative-sequence component will exist. At this time, the above equation is true and distance protection will be released. 3.
Symmetrical fault PSBR element
If a three-phase fault occurs and FD PSBR is invalid (160ms after FD operates), neither FD PSBR nor UF PSBR will be able to release the distance protection. Thus, SF PSBR is provided for this case specially. This detection is based on measuring the voltage at power swing center, during power swing, U1cosΦ will constantly change periodically. UOS=U1×COSΦ Where: Φ: the angle between positive sequence voltage and current U1: the positive sequence voltage As shown in the figure below, assume system connection impedance angle of 90°, current vector will be perpendicular to the line connecting E M and EN, and have the same phase as power swing center voltage. During normal operation of system or power swing, U1cosΦ just reflects
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positive-sequence voltage of power swing center. In case of 3-phase short circuit, U1cosΦ is voltage drop on arc resistor, transition resistance is arc resistance, and voltage drop on arc resistor is less than 5%UN. In actual system, line impedance angle is not 90°. Through compensation of angle Φ, power swing center voltage can be measured accurately. After compensation, power swing center voltage is U1cos(Φ+90o-ΦL), where ΦL is line impedance angle. EM
I
U
EN
UOS
Φ
During power swing, power swing center voltage U 1cosΦ has the following characteristics: When electric potential phase angle difference between power supplies at two sides is 180o, U1cosΦ=0 and change rate dU1cosΦ/dt is the maximum. When this phase angle difference is near 0 o, power swing center voltage change rate dU 1cosΦ/dt is the minimum. During short circuit, U 1cosΦ remains unchanged and dU1cosΦ/dt=0. However, in early stage of short circuit when normal state enters short circuit state, dU1cosΦ/dt is very large. Therefore, use of dU 1cosΦ/dt solely to differentiate power swing and short circuit is not complete. For these reasons, the method to release distance protection on condition that power swing center voltage U1cosΦ is less than a setting and after a short delay can be used as symmetric fault discriminating element. This element can accurately differentiate power swing and 3-phase short circuit fault, and constitute a complete power swing blocking scheme with other elements. The element to open distance protection if U 1cosΦ is less than a certain setting and after a delay is easy to realize and has short delay, and can trip fault more quickly and accurately trip 3-phase short circuit fault during power swing. The criterion of SF PSBR element comprises the following two parts:
when -0.03UN
when -0.1UN
The second criterion is a backup of the first criterion allowing longer monitoring period of voltage variation. To reduce the time delay for SF PSBR element during power swing, the change rate of voltage at power swing center is also used which can release SF PSBR element quickly for the fault occurred during power swing. The typical release time is less than 60ms.
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3.6.8.1 Function Block Diagram
21M
21M.En_PSBR
21M.Z1.Rls_PSBR
21M.Blk_PSBR
21M.Z2.Rls_PSBR 21M.Z3.Rls_PSBR
21Q
21Q.En_PSBR
21Q.Z1.Rls_PSBR
21Q.Blk_PSBR
21Q.Z2.Rls_PSBR 21Q.Z3.Rls_PSBR
3.6.8.2 I/O Signals Table 3.6-11 I/O signals of PSBR No.
Input Signal
Description
1
21M.En_PSBR
Enabling power swing blocking releasing (Mho characteristic)
2
21Q.En_PSBR
Enabling power swing blocking releasing (Quad characteristic)
3
21M.Blk_PSBR
Blocking power swing blocking releasing (Mho characteristic)
4
21Q.Blk_PSBR
Blocking power swing blocking releasing (Quad characteristic)
No.
Output Signal
Description
1
21M.Z1.Rls_PSBR
PSBR operates to release zone 1 (Mho characteristic)
2
21Q.Z1.Rls_PSBR
PSBR operates to release zone 1 (Quad characteristic)
3
21M.Z2.Rls_PSBR
PSBR operates to release zone 2 (Mho characteristic)
4
21Q.Z2.Rls_PSBR
PSBR operates to release zone 2 (Quad characteristic)
5
21M.Z3.Rls_PSBR
PSBR operates to release zone 3 (Mho characteristic)
6
21Q.Z3.Rls_PSBR
PSBR operates to release zone 3 (Quad characteristic)
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3.6.8.3 Logic SIG
Y.En_PSBR
SIG
Y.Blk_PSBR
SIG
FD.Pkp
SIG
Y.Enable_PSBR
EN
[Y.Zx .En_PSBR]
SIG
symmetrical |U1cosΦ|<
& Y.Enable_PSBR
& >=1 t
0ms Unblocking for SF
>=1
& Y.Zx.Rls_PSBR
Unblocking for UF
>=1 SIG
Unsymmetrical |I0|+|I2|>
SIG
Y.Zx.Flg_PSBR
SET
I1>[Y.I_PSBR]
&
&
& 0
SIG
FD.Pkp
SIG
Y.Zx.Flg_PSBR
160ms
>=1
Figure 3.6-38 Logic diagram of PSBR
Y: 21M or 21Q x: 1, 2 or 3 Y.Zx.Flg_PSBR: Please refer to Figure 3.6-26~Figure 3.6-29, Figure 3.6-33~Figure 3.6-36. 3.6.8.4 Settings Table 3.6-12 Settings of PSBR No.
Name
Range
Step
Unit
Remark Enabling/disabling
zone
1
of
distance protection controlled by 1
21M.Z1.En_PSBR
0 or 1
PSBR (Mho characteristic) 0: disable 1: enable Enabling/disabling
2
21Q.Z1.En_PSBR
0 or 1
zone
1
of
distance protection controlled by PSBR (Quad characteristic)
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zone
2
of
distance protection controlled by 3
21M.Z2.En_PSBR
0 or 1
PSBR (Mho characteristic) 0: disable 1: enable Enabling/disabling
zone
2
of
distance protection controlled by 4
21Q.Z2.En_PSBR
0 or 1
PSBR (Quad characteristic) 0: disable 1: enable Enabling/disabling
zone
3
of
distance protection controlled by 5
21M.Z3.En_PSBR
0 or 1
PSBR (Mho characteristic) 0: disable 1: enable Enabling/disabling
zone
3
of
distance protection controlled by 6
21Q.Z3.En_PSBR
0 or 1
PSBR (Quad characteristic) 0: disable 1: enable
7
21M.I_PSBR
(0.050~30.000)×In
0.001
A
8
21Q.I_PSBR
(0.050~30.000)×In
0.001
A
Current setting for power swing blocking (Mho characteristic) Current setting for power swing blocking (Quad characteristic)
3.6.9 Distance SOTF Protection When the circuit breaker is closed manually or automatically, it is possible to switch on to a fault. This is especially critical if the line in the remote station is grounded, since the distance protection would not clear the fault until overreach zones (zone 2 and/or zone 3) time delays have elapsed. In this situation, however, the fastest possible clearance is required. The SOTF (switch onto fault) protection is a complementary function to the distance protection. With distance SOTF protection, a fast trip is achieved for a fault on the whole line, when the line is being energized. It shall be responsive to all types of faults anywhere within the protected line.
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3.6.9.1 Function Block Diagram 21SOTF 21SOTF.En
21SOTF.On
21SOTF.Blk
21SOTF.Op 21SOTF.Op_PDF
3.6.9.2 I/O Signals Table 3.6-13 I/O signals of distance SOTF protection No.
Input Signal
1
21SOTF.En
2
21SOTF.Blk
No.
Description Distance SOTF protection enabling input, it is triggered from binary input or programmable logic etc. Distance SOTF protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description Accelerate distance protection to trip when manual closing or auto-reclosing to
1
21SOTF.Op
2
21SOTF.Op_PDF
3
21SOTF.On
fault Accelerate distance protection to trip when another fault happened under pole discrepancy conditions Accelerate distance protection is enabled.
3.6.9.3 Logic SIG
21SOTF.En
SIG
21SOTF.Blk
EN
[21SOTF.En]
& & 21SOTF.On
Figure 3.6-39 Logic diagram of enabling distance SOTF protection
Distance SOTF protection can be enabled or disabled, and can be initiated by several cases, including manual closing signal, 3-pole reclosing, 1-pole reclosing and pole discrepancy conditions.
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[52b_PhA]
BI
[52b_PhB]
BI
[52b_PhC]
SIG
FD.Pkp
EN
[SOTF.Opt_Mode_ManCls]=1 or 2
EN
[SOTF.Opt_Mode_ManCls]=0 or 2
BI
ManCls
EN
[21SOTF.En_ManCls]
EN
[21SOTF.Z2.En_ManCls]
SIG
Y.Z2.Flg_PSBR
EN
[21SOTF.Z3.En_ManCls]
SIG
Y.Z3.Flg_PSBR
EN
[21SOTF.Z4.En_ManCls]
SIG
Y.Z4.Flg_PSBR
SIG
21SOTF.On
SIG
FD.Pkp
>=1
&
>=1 0
400ms
Manual closing signal
&
& & [21SOTF.t_ManCls] 0
&
&
21SOTF.Op
>=1
&
&
Figure 3.6-40 Logic diagram of distance SOTF protection by manual closing signal
When the circuit breaker is in open position while the device does not pick up, or external manual closing binary input is energized, then manual closing signal will be kept for 400ms, which will enable SOTF logic only for 400ms.
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FD.Pkp
SIG
21SOTF.On
EN
[21SOTF.En_3PAR]
SIG
3-pole reclosing signal
EN
[21SOTF.Z2.En_3PAR]
SIG
Y.Z2.Flg_PSBR
EN
[21SOTF.Z2.En_PSBR]
SIG
Y.Z2.Rls_PSBR
EN
[21SOTF.Z3.En_3PAR]
&
SIG
Y.Z3.Flg_PSBR
EN
[21SOTF.Z3.En_PSBR]
SIG
Y.Z3.Rls_PSBR
EN
[21SOTF.Z4.En_3PAR]
SIG
Y.Z4.Flg_PSBR
EN
[21SOTF.Z4.En_PSBR]
SIG
Y.Z4.Rls_PSBR
EN
[21SOTF.En_1PAR]
SIG
PD signal
SIG
Y.Z2.Rls_PSBR
&
& >=1 & & &
[21SOTF.t_3PAR]
& >=1
0
>=1 21SOTF.Op
>=1
&
& >=1 &
& [21SOTF.t_1PAR]
&
0
Figure 3.6-41 Logic diagram of distance SOTF protection by 1-pole or 3-pole AR
For single-phase permanent fault, distance SOTF protection for 1-pole reclosing onto the faulty phase will trip three-phase circuit breaker.
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3 Operation Theory SIG
21SOTF.On
SIG
FD.Pkp
EN
[21SOTF.En_PDF]
SIG
Y.Z2.Rls_PSBR (Phase A)
SIG
PD signal (Phase A)
SIG
PD signal (Phase B or C)
SIG
Y.Z2.Rls_PSBR (Phase B)
SIG
PD signal (Phase B)
SIG
PD signal (Phase A or C)
SIG
Y.Z2.Rls_PSBR (Phase C)
SIG
PD signal (Phase C)
SIG
PD signal (Phase A or B)
& & [21SOTF.t_PDF]
0
21SOTF.Op_PDF
&
&
>=1
&
Figure 3.6-42 Logic diagram of distance SOTF protection by PD condition
Under pole discrepancy condition after single-phase tripping, distance SOTF protection will accelerate to operate if another fault happens to the healthy phase. Y: 21M or 21Q 3.6.9.4 Settings Table 3.6-14 Settings of distance SOTF protection No.
Name
Range
Step
Unit
Remark Enabling/disabling distance SOTF
1
21SOTF.En
protection
0 or 1
0: disable 1: enable Enabling/disabling distance
2
21SOTF.Z2.En_ManCls
0 or 1
SOTF
zone
2
of
protection
for
manual closing 1: enable 0: disable Enabling/disabling distance
3
21SOTF.Z3.En_ManCls
0 or 1
SOTF
zone
3
of
protection
for
manual closing 1: enable 0: disable Enabling/disabling
4
21SOTF.Z4.En_ManCls
0 or 1
distance
SOTF
zone
4
of
protection
for
manual closing 3-71
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3 Operation Theory 1: enable 0: disable Enabling/disabling distance 5
21SOTF.Z2.En_3PAR
0 or 1
SOTF
zone
2
of
protection
for
3-pole reclosing 1: enable 0: disable Enabling/disabling distance
6
21SOTF.Z3.En_3PAR
0 or 1
SOTF
zone
3
of
protection
for
3-pole reclosing 1: enable 0: disable Enabling/disabling distance
7
21SOTF.Z4.En_3PAR
0 or 1
SOTF
zone
4
of
protection
for
3-pole reclosing 1: enable 0: disable Enabling/disabling
zone
2
controlled by PSB of distance 8
21SOTF.Z2.En_PSBR
SOTF
0 or 1
protection
for
3-pole
reclosing 1: enable 0: disable Enabling/disabling
zone
3
controlled by PSB of distance 9
21SOTF.Z3.En_PSBR
SOTF
0 or 1
protection
for
3-pole
reclosing 1: enable 0: disable Enabling/disabling
zone
4
controlled by PSB of distance 10
21SOTF.Z4.En_PSBR
SOTF
0 or 1
protection
for
3-pole
reclosing 1: enable 0: disable Enabling/disabling distance SOTF protection under pole discrepancy
11
21SOTF.En_PDF
0 or 1
conditions 1: enable 0: disable Time delay of distance protection
12
21SOTF.t_PDF
0.000~10.000
0.001
s
operating under pole discrepancy conditions
13
SOTF.Opt_Mode_ManCls
0, 1 or 2
Option of manual SOTF mode
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Name
Default Value
Unit
Remark Enabling/disabling distance SOTF protection for
1
21SOTF.En_ManCls
manual closing
1
0: disable 1: enable
2
21SOTF.t_ManCls
0.025
s
Time delay of distance protection accelerating to trip when manual closing Enabling/disabling distance SOTF protection for
3
21SOTF.En_3PAR
3-pole reclosing
1
0: disable 1: enable
4
21SOTF.t_3PAR
0.025
s
Time delay of distance protection accelerating to trip when 3-pole reclosing Enabling/disabling distance SOTF protection for
5
21SOTF.En_1PAR
1-pole reclosing
1
0: disable 1: enable
6
21SOTF.t_1PAR
0.025
s
Time delay of distance protection accelerating to trip when 1-pole reclosing
3.7 Optical Pilot Channel 3.7.1 General Application The devices can transmit permissive signal, blocking signal, transfer signal and transfer trip used by current differential protection via optical fibre channel. The communication rate can be 64kbits/s or 2048kbits/s via optional dedicated optical fibre channel or multiplex channel. By the setting [FO.Protocol], the device can support G.703 or C37.94.
3.7.2 Function Description Besides current and voltage, 8 digital bits are integrated in each frame of transmission message for various applications. Each received message frame via fibre optical channel will pass through security check to ensure the integrity of the message consistently. 8 binary signals are configurable. The communication channel can be configured as single channel mode or as dual channels mode. (FOx, x can be 1 or 2) according to the optical pilot channel module selected.
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3.7.2.1 Channel Interface The modules can communicate in two modes via multiplexer or dedicated optical fibre. Communication through dedicated fibre is usually recommended unless the received power does not meet with the requirement. Channel of 64kbits/s or 2048kbits/s via dedicated fibre is shown in Figure 3.7-1 and Figure 3.7-2. Two fibre cores of optical cable are dedicated to current differential protection. Two fibre cores of optical cable are normally in service, and all data are exchanged via the other healthy core if one core is failed.
Max 2km for 62.5/125um multi-mode FO C37.94 (N*64kbits/s)
TX
RX
RX
TX
PCS-931
PCS-931
ST connectors
ST connectors
Figure 3.7-1 Direct optical link up to 2km with 850nm
Max 40km/100km for 9/125um single-mode FO
TX
RX
RX
TX
PCS-931
PCS-931
FC connectors
FC connectors
Figure 3.7-2 Direct optical link up to 40km with 1310nm or up to 100km with 1550nm
Channel of 64kbits/s or 2048kbits/s via multiplexer is shown in Figure 3.7-3, Figure 3.7-4 and Figure 3.7-5.
C37.94 (N*64kbits/s)
Multi-mode FO
Communication convertor
TX
RX
RX
TX
E
PCS-931
ST connectors
O
Interface Link to communicate device
ST connectors
Figure 3.7-3 Connect to a communication network via communication convertor 3-74
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G.703 (64kbits/s)
MUX-64
Single-mode FO
TX
RX
RX
TX
E
Interface Link to communicate device
PCS-931
FC connectors
O
FC connectors
Figure 3.7-4 Connect to a communication network via MUX-64
G.703-E1 (2048kbits/s)
MUX-2M
Single-mode FO
TX
RX
RX
TX
E
Interface
PCS-931
FC connectors
O
Link to communicate device
FC connectors
Figure 3.7-5 Connect to a communication network via MUX-2M
The protection transmission data format is shown as following table. Bit High
Data Frame
Description
Format
The header of transmission data format
LocID
The identity code of local device
Ia Ib
Three phase current
Ic
low
Time
Time for synchronising
FO.Send1~FO.Send8
The eight signals sent by channel
Inter-trip (phase A/B/C)
Please refer to section 3.8.5.7 for the explanation
Permissive signal (phase A/B/C)
Please refer to section 3.8.5.9 for the explanation
Enable DIFF
Differential protection at both sides are enabled
CRC
3.7.2.2 Communication Clock Valid messages exchange is key factor for current differential protection. The device transmits and receives messages based on respective clocks, which are called transmit clock (i.e. clock TX) and receive clock (i.e. clock RX) respectively. Clock RX is fixed to be extracted from message frame, which can ensure no slip frame and no error message received. 3-75
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Clock TX has two options: 1. Use internal crystal clock, which is called internal clock. (master clock) 2. Use external clock. (slave clock) Depend on the clock used by the device at both ends, there are three modes. 1.
Master-master mode
Both ends use internal clock. 2.
Slave-slave mode
Both ends use external clock. 3.
Master-slave mode
One of them uses internal clock, the other uses external clock The logic setting [FOx.En_IntClock] is used in current differential protection to select the communication clock. The internal clock is enabled automatically when the logic setting [FOx.En_IntClock] is set as “1”. Contrarily, the external clock is enabled automatically when the logic setting [FOx.En_IntClock] is set to “0”. If the device uses multiplex PCM channel, logic setting [FOx.En_IntClock] at both ends should be set as “0” (Mode 2). If the device uses dedicated optical fibre channel, clock Mode 1 and Mode 3 can be used. Mode 1 is recommended in considering simplification to user, i.e. logic setting [FOx.En_IntClock] at both ends should be set as “1”. 3.7.2.3 Identity Code In order to ensure reliability of the device when digital communication channel is applied, settings [FO.LocID] and [FO.RmtID] are provided as identity code to distinguish uniquely the device at remote end using same channel. Under normal conditions, the identity code of the device at local end should be different with that at remote end. In addition, it is recommended that the identity code of all devices, i.e., the setting [FO.LocID], should be unique in the power grid. The setting range is from 0 to 65535. Only for loop test, they are set as the same. The setting [FO.LocID] of the device at an end should be the same as the setting [FO.RmtID] of the device at opposite end and the greater [FO.LocID] between the two ends is chosen as a master end for sampling synchronism, the smaller [FO.LocID] is slave end. If the setting [FO.LocID] is set the same as [FO.RmtID], that implies the device in loopback testing state. The setting [FO.LocID] is packaged in the message frame and transmitted to the remote end. When the [FO.LocID] of the device at remote end received by local device is same to the setting [FO.RmtID] of local device, the message received from the remote end is valid, and protection information involved in message is read. When these settings are not matched, the message is considered as invalid and protection information involved in message is ignored, corresponding alarms will be issued.
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3.7.2.4 Channel Statistics The device has the function of on-line channel monitoring and channel statistics. It can produce channel statistic report automatically at 9:00 every day and the report can be printed for operator to check the channel quality. The monitoring contents of channel status are shown as follows, and they can be viewed by the menu “Main Menu→Test→Prot Ch Counter→Chx Counter”. 1.
FOx.StartTime (starting time)
It shows the starting time of the channel status statistics of the device at local end. 2.
FO.RmtID (ID code of the remote end)
It shows the ID information received by the device at local end now. 3.
FOx.t_ChLag (propagation delay of channel x)
It shows the calculated communication channel time delay of the device at local end now (unit: us). The calculation is based on the assumption of same channel path for to and from remote end. The device measures propagation delay of communication channel based on the below principle. Side S transmits a frame of message to side M, and meanwhile records the transmitting time “tss” on the basis of clock on side S. When side M receives the message, it will record receiving time “tmr” of the message with its own clock, and return a frame of message to side S at next fixed transmitting time, meanwhile data of “tms-tmr” is included in the frame of message. Side S will receive the message from side M at the time “tsr” and obtain the data of “tms-tmr”. Therefore, the propagation delay of the channel “Td” is obtained through calculation:
Td
(t sr t ss ) (t ms t mr ) 2
By using the above calculated “Td”, the device automatically compensate time synchronization of sampling data at each end and transimission time lag.
T1
tss
tsr
tmr Td
tms
"S"
"M"
T2
Figure 3.7-6 Schematic diagram of communication channel time
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4.
FOx.N_CRCFail (total number of error frame of channel x)
It shows the total number of the error frames of the device at local end from starting time of channel statistics until now. Error frame means that this frame fails in CRC check. 5.
FOx.N_FramErr (total number of abnormal messages of channel x)
It shows the total number of abnormal messages of the device at local end from starting time of channel statistics until now. 6.
FOx.N_FramLoss (total number of lost frames of channel x)
It shows the total number of the lost frames of the device at local end from starting time of channel statistics until now. 7.
FOx.N_RmtAbnor (total number of abnormal messages from the remote end of channel x)
It shows the total number of abnormal messages received from the remote end from starting time of channel statistics until now. 8.
FOx.N_CRCFailSec (total number of serious error frames of channel x)
It shows the total number of serious error frame seconds of the device at local end from starting time of the channel statistics until now. 9.
FOx.N_LossSyn (total number of loss synchronous of channel x)
It shows the total number of loss synchronous of the device at local end from starting time of the channel statistics until now.
3.7.3 Function Block Diagram FOx FOx.En
FOx.On
FOx.Send1
FOx.Recv1
FOx.Send2
FOx.Recv2
FOx.Send3
FOx.Recv3
FOx.Send4
FOx.Recv4
FOx.Send5
FOx.Recv5
FOx.Send6
FOx.Recv6
FOx.Send7
FOx.Recv7
FOx.Send8
FOx.Recv8 FOx.Alm FOx.Alm_ID
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3.7.4 I/O Signals Table 3.7-1 I/O signals of pilot channel No.
Input Signal
Description
1
FOx.En
Enabling channel x
2
FOx.Send1
Sending signal 1 of channel x
3
FOx.Send2
Sending signal 2 of channel x
4
FOx.Send3
Sending signal 3 of channel x
5
FOx.Send4
Sending signal 4 of channel x
6
FOx.Send5
Sending signal 5 of channel x
7
FOx.Send6
Sending signal 6 of channel x
8
FOx.Send7
Sending signal 7 of channel x
9
FOx.Send8
Sending signal 8 of channel x
Output Signal
Description
1
FOx.On
Channel x is enabled.
1
FOx.Recv1
Receiving signal 1 of channel x
2
FOx.Recv2
Receiving signal 2 of channel x
3
FOx.Recv3
Receiving signal 3 of channel x
4
FOx.Recv4
Receiving signal 4 of channel x
5
FOx.Recv5
Receiving signal 5 of channel x
6
FOx.Recv6
Receiving signal 6 of channel x
7
FOx.Recv7
Receiving signal 7 of channel x
8
FOx.Recv8
Receiving signal 8 of channel x
9
FOx.Alm
Channel x is abnormal
No.
10
Received ID from the remote end is not as same as the setting [FO.RmtID] of
FOx.Alm_ID
the device in local end
3.7.5 Logic SIG
Receiving transfer signal n from remote side
& FOx.Recvn
SIG
FOx.Alm
SIG
FOx.Alm_ID
SIG
FOx.En
EN
FOx.En
>=1
& FOx.On
Figure 3.7-7 Logic diagram of receiving signal n
Where: n can be 1~8
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3.7.6 Settings Table 3.7-2 Settings of pilot channel No.
Name
Range
Step
Unit
Remark
1
FO.LocID
0-65535
1
Identity code of the device at local end
2
FO.RmtID
0-65535
1
Identity code of the device at remote end
3
FO.Protocol
4
FO.BaudRate
G.703
It is used to select protocol type, G.703 or
C37.94
C37.94
64 or 2048
kbps
Baud rate of optical pilot channel Option of internal clock or external clock
5
FOx.En_IntClock
0 or 1
0: external clock 1: internal clock Enabling/disabling channel x
6
FOx.En
0 or 1
0: disable 1: enable
3.8 Current Differential Protection 3.8.1 General Application Current differential protection can be used as main protection of EHV and HV overhead line or cable. It includes phase-segregated current differential protection and neutral current differential protection. Current differential protection exchanges information among ends through communication channel. The device can flexibly select dedicated optical fibre channel or multiplex channel. The device calculates channel propagation delay continuously, and adjust sampling instant to ensure synchronization of sampled values at both ends. The channel propagation delay is calculated on the basis of the same route for sending and receiving channels. The communication rate used by the device is 64kbits/s or 2048kbits/s. The maximum tolerable one-way channel propagation delay is 20ms. A transfer trip and two transfer signals can be sent to the remote end to fulfill some auxiliary functions via a communication channel. The sensitivity of current differential protection is maintained for long lines by capacitive current compensation. However, line voltage is required for capacitive current compensation and it will be disabled automatically if no voltage is input or VT circuit fails.
3.8.2 Function Description The communication channel between two devices is monitored and its propagation delay is measured continuously. Once channel failure is detected, the current differential protection will be blocked automatically. The detailed channel status, including channel delay, current from the remote end and differential current, can be displayed on the LCD. 3-80
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Current differential protection comprises three elements:
DPFC current differential element (2 stages)
Steady-state current differential element (2 stages)
Neutral current differential element (1 stage)
3.8.2.1 DPFC Current Differential Element (Stage 1) DPFC (Deviation of Power Frequency Component) percent differential element only reflects fault components which can perform a sensitive protection for the transmission line. Lab test shows that it is more sensitive in the heavy load condition than the conventional percent differential element. Operation criteria: ΔIDiffΦ 0.75 ΔIBias Φ ΔIDiffΦ IH
Equation 3.8-1
Where:
ΔIDiffΦ : The DPFC differential current ( ΔIDiffΦ ΔIMΦ ΔINΦ )
ΔIBiasΦ : The DPFC restraint current ( ΔIBiasΦ ΔIMΦ ΔINΦ )
IH : Max(1.5×[87L.I_Pkp],
1.5U N ) X C1L
The calculation of DPFC restraint current and differential current is phase-segregated. In these summations, charging current is eliminated from the phase currents by the charging current compensation function, so it is not needed to consider capacitive current during disturbance status for current differential setting threashold. Operation characteristic curve is shown as following figure.
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k=1 k=0.75
IH
ΔIBias
Figure 3.8-1 Operation characteristic of DPFC current differential element
Due to high slope of DPFC percent differential protection, differential protection has higher ability of anti-CT saturation. Meanwhile, the load current won’t affect the sensitivity of DPFC differential elements, so the sensitivity is very high even for high impedance fault under heavy load. 3.8.2.2 DPFC Current Differential Element (Stage 2) Operation criteria: ΔIDiffΦ 0.75 ΔIBias Φ ΔIDiffΦ IQ
Equation 3.8-2
Where:
IQ : Max([87L.I_Pkp],
1.25U N ) X C1L
ΔIDiffΦ and ΔIBias Φ are the same as those mentioned above.
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k=1 k=0.75
IQ
ΔIBias
Figure 3.8-2 Operation characteristic of DPFC current differential element
When the above criterion is met, the stage 2 of DPFC current differential element will operate after 1¼ cycles. 3.8.2.3 Steady-state Current Differential Element (stage 1) Operation criteria: IDiffΦ 0.6 IBias Φ IDiffΦ IH
Equation 3.8-3
Where:
IDiffΦ : The phase differential current ( IDiffΦ IMΦ INΦ ) IBiasΦ : The phase restraint current ( IBiasΦ IMΦ INΦ )
IH : Max(1.5×[87L.I_Pkp],
1.5U N ) X C1L
Calculation of steady-state restraint current and differential current is phase-segregated. In these summations, charging current is eliminated from phase currents by the charging current compensation function. so it is not needed to consider capacitive current during disturbance status for current differential setting threashold Operation characteristic curve is shown as following figure.
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IDiffΦ
k=0.6
IH
IBiasΦ
Figure 3.8-3 Operation characteristic of steady-state current differential element
3.8.2.4 Steady-state Current Differential Element (stage 2) Operation criteria: IDiffΦ 0.6 IBias Φ IDiffΦ IM
Equation 3.8-4
Where:
IM : Max([87L.I_Pkp],
1.25U N ) X C1L
IDiffΦ and IBias Φ are the same as those mentioned above.
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IDiffΦ
k=0.6
IM
IBiasΦ
Figure 3.8-4 Operation characteristic of steady-state current differential element
When the above criterion is met, the stage 2 of steady-state differential current relay will operate after 1¼ cycles. 3.8.2.5 Neutral Current Differential Element The sensitivity of steady-state differential current element is too low for the slight fault during heavy load, and DPFC current differential element can only reflect the slight fault during heavy load, but low for the slow changing fault due to the small change of fault component. Neutral current differential element can be very sensitive to this kind of fault. Operation criteria: IDiff0 0.75 IBias0 IDiff0 IM IDiffΦ 0.15 IBias Φ IDiffΦ IM
Equation 3.8-5
Where:
IDiff0 : The neutral differential current
IDiffΦ : The phase differential current IBias0 : The neutral restraint current ( IBias0 IM0 IN0 )
IM : [87L.I_Pkp]
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IBiasΦ is the same to those mentioned above In these summations, charging current is eliminated from the phase currents by the charging current compensation function. So it is not needed to consider capacitive current during disturbance status for setting threashold Operation characteristic curve is shown as following figure.
IDiff0
k=0.75
IM
IBias0
Figure 3.8-5 Operation characteristic of neutral current differential element
Due to high slope of neutral current differential protection, differential protection has higher ability of anti-CT saturation. When the above criterion is met, the neutral current differential relay will operate with a time delay (controlled by an internal setting, default value is 40ms). 3.8.2.6 Capacitive Current Compensation For the long transmission line whose capacitive current is very large, in order to increase the sensitivity of current differential element especially for an earth fault associated with high fault resistance, capacitive current must be compensated to eliminate the effect that capacitive current has on differential current. The traditional method of compensating capacitive current can only compensate steady-state capacitive current. However, during the transient period, such as circuit energization (as shown in below figure), external fault clearance, etc., there is large transient capacitive current in the line.
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The traditional method cannot compensate the capacitive current completely, hence, a new method is adopted to compensate transient component of capacitive current. 1.
For long transmission line without shunt reactor
Phase capacitive current of line can be derived from “∏” equivalent circuit. Under normal condition, circuit energization and external fault clearance, not only steady-state component but also transient component of capacitive current can be compensated. It can improve the sensitivity of current differential protection.
A
M
ZL
N
ZL
B
ZL
C
Figure 3.8-6 ∏ equivalent circuit
For various system frequencies, the capacitive current which is shown in above figure can be calculated by: ic C
du c dt
Equation 3.8-6
Where:
i c : Capacitive current flowing through each capacitor C : Capacitance value
uc : Voltage across capacitors Based on the result of above equation, i.e. Equation 3.8-6, capacitance of each phase can be gained. 2.
For long transmission line with shunt reactor
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Because a part of capacitive current has been compensated by shunt reactor, reactive current IL must be subtracted from capacitive current calculated by above equation, i.e. Equation 3.8-6. Lp ua iLa Lf
uf
uL ub
iLb
iL
uc iLc Figure 3.8-7 Equivalent circuit of shunt reactor
The current and voltage of reactor have the following relation: UL (t) - Uf (t) LP
diL (t) dt
Equation 3.8-7
To perform integral operation from t to t-∆t, iL can be calculated by: iL (t) iL (t - Δt)
1 LP
U (t) U (t)dt t
t Δt
L
Equation 3.8-8
f
Then, ic C
3.
du c iL (t) dt
Equation 3.8-9
For short transmission line
Capacitive current is very small, the sensitivity of current differential protection can still meet the requirement. The function, capacitive current compensation, will be disabled automatically if differential current is smaller than 0.1In. 4.
Transient capacitive current compensation
If transient capacitive current compensation is adopted, according to Equation 3.8-6 and Equation 3.8-9, the compensated transient capactive current of each side is calculated, then the transient differential current and restraint current after compensation is calculated, so differential protection function can be accomplished. 3.8.2.7 CT Supervision If CT circuit fails, an alarm will be issued with a time delay. When CT circuit failure occurs at one end, FD and current differential protection on the end might operate. However, FD on another end will not operate and not send any permissive signal of current differential protection. Therefore, the current differential protection will not maloperate. Meanwhile the healthy end will issue alarm signal [87L.Alm_Diff_FO1] which will be treated as the same as the alarm [CTS.Alm]. However, if CT circuit failure associated with internal fault or pickup due to system disturbance is 3-88
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detected, the device will show two kinds of behavior. If logic setting [87L.En_CTS_Blk] (differential protection being blocked during CT circuit failure) is set as “1”, the current differential protection will be blocked. If logic setting [87L.En_CTS_Blk] is set as “0” and the current differential current of the faulty phase is more than the differential current setting [87L.I_Pkp_CTS] during CT circuit failure, the current differential protection will operate with alarm signal being issued at the same time. 3.8.2.8 CT Saturation Two detectors are used to prevent undesired tripping caused by severe CT saturation during external close up fault. If the differential current is determined to be caused by CT saturation, the device will block differential protection to prevent mal-operation. 1.
High restraint coefficient and self-adaptive floating restraint threshold
Due to high slope of DPFC percent differential protection, differential protection has higher ability of anti-CT saturation. For external fault as following figure, the restraint current will be able to reflect the real quantity of system for a short time after current cross zero point and can be used as the restraint current after CT enters into saturation status by the use of self-adaptive floating threshold technology. Fault-Current-SideA 10
A
5 0 -5 -10
0
20
40
60
80
100
120
140
80
100
120
140
80
100
120
140
Fault-Current-SideB 20
A
10 0 -10
0
20
40
60 Diff-Current
20
A
10 0 -10
0
20
40
60 Restraint-Current
20 CT
A
10 0 -10 -20
0
20
40
60
80
100
120
140
(During external fault) Figure 3.8-8 Relation between CT saturation differential current and restraint current
2.
Asynchronous method: as shown in Figure 3.8-8, there is a short time before CT is saturated after fault current cross zero point, during the period, CT can convert fault current accurately, so there is restraint current but no differential current, the congruent relationship between increased differential current and increased restraint current is used to judge if there is a internal or external fault, strong anti-saturation ability can be get according to this method.
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The above methods can prevent current differential protection from mal-operation if there is more than 1/4 cycle before CT is saturated. 3.8.2.9 Synchronous Sampling Between both ends, the device with greater ID code, normally called “master”, is taken as reference, the device on the other end with smaller ID code, normally called “slave”, adjusts the sampling interval to synchronization with “master”. The devices exchange synchronization sampled values via communication channels. The preconditions for synchronization sampling of the devices between both ends include: 1.
The maximum unidirectional channel propagation delay ≤20ms.
2.
The sending and receiving channels are of same route or same propagation delay (i.e. the propagation delay of the two directions shall be equivalent).
Please refer to section 3.7 for more detail about optical pilot channel. 3.8.2.10 CT Ratio Adjust If the ratio of CTs on two ends of the line is different, current of two ends must be corrected to one reference value. PCS-931 regards local end as the referenced end, differential current and restraint current can be calculated since the current of the remote end is corrected by the setting. [87L.K_Cr_CT]. Setting principle: Suppose CT ratio, Terminal M: k M=IM1n : IM2n; Terminal N: kN=IN1n : IN2n IM1n: primary rated current of terminal M, IM2n: secondary rated current of terminal M IN1n: primary rated current of terminal N, IN2n: secondary rated current of terminal N If IM1n>= IN1n Terminal M: [87L.K_Cr_CT]=1.00 Terminal N: [87L.K_Cr_CT]=IN1n / IM1n For example: Terminal M: CT ratio=1250 : 5, the setting [87L.K_Cr_CT] is set as “0.5” Terminal N: CT ratio=2500 : 1, the setting [87L.K_Cr_CT] is set as “1.0” If current of terminal M is IM, current of terminal N is IN, the differential current and restraint current calculated on terminal M is:
I DiffΦ IMΦ
INΦ 87L.K_Cr_CT
I BiasΦ IMΦ
INΦ 87L.K_Cr_CT
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3.8.3 Function Block Diagram 87L 87L.En1
87L.On
87L.En2
87L.Op
87L.Blk
87L.Op_A 87L.Op_B 87L.Op_C 87L.Op_DPFC1 87L.Op_DPFC2 87L.Op_Biased1 87L.Op_Biased2 87L.Op_Neutral 87L.Op_InterTrp 87L.FOx.Alm_Diff 87L.FOx.Alm_Comp
3.8.4 I/O Signals Table 3.8-1 I/O signals of current differential protection No.
Input Signal
1
87L.En1
2
87L.En2
3
87L.Blk
No. 1
Description Current differential protection enabling input 1, it is triggered from binary input or programmable logic etc. Current differential protection enabling input 2, it can be a binary inputs or a logic link. Current differential protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal 87L.On
Description Current differential protection is enabled Current differential protection operates, if any of them “[87L.Op_DPFC1],
2
87L.Op
[87L.Op_DPFC2], [87L.Op_Biased1], [87L.Op_Biased2], [87L.Op_Neutral], [87L.Op_InterTrp]” operates, then [87L.Op] will operate.
3
87L.Op_A
Current differential protection of phase A operates
4
87L.Op_B
Current differential protection of phase B operates
5
87L.Op_C
Current differential protection of phase C operates
6
87L.Op_DPFC1
Stage 1 of DPFC current differential element operates
7
87L.Op_DPFC2
Stage 2 of DPFC current differential element operates
8
87L.Op_Biased1
Stage 1 of steady-state current differential element operates
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87L.Op_Biased2
Stage 2 of steady-state current differential element operates
10
87L.Op_Neutral
Zero-sequence current differential element operates
11
87L.Op_InterTrp
Inter-tripping element operates
12
87L.FOx.Alm_Diff
Differential current of channel x is abnormal The settings [XC1] and [XC0] and differential current of the device for channel
13
87L.FOx.Alm_Comp
x are mismatched.
|IDiff_Actual|<0.7|IDiff_Cal|
or
|IDiff_Cal|<0.7|IDiff_Actual|
under
normal condition.
3.8.5 Logic 3.8.5.1 Common Element SIG
[87L.En2]
SIG
[87L.En1]
EN
[87L.En]
SIG
[87L.Blk]
SIG
[87L.En2]
SIG
[87L.En1]
EN
[87L.En]
SIG
& & Enable DIFF (Local end)
& & Enable DIFF (Remote end)
[87L.Blk] Setting by the remote end
SIG
Enable DIFF (Local end)
SIG
Enable DIFF (Remote end)
& 87L.On
Where: Enable DIFF (Local end): local current differential protection is enabled Enable DIFF (Remote end): remote current differential protection is enabled SET
IDiff>[87L.I_Pkp](A)
& Common differential condition (phase A)
SET
IDiff>0.15×IBias(A)
SET
IDiff>[87L.I_Pkp](B)
SET
IDiff>0.15×IBias(B)
SET
IDiff>[87L.I_Pkp](C)
& Common differential condition (phase B)
& Common differential condition (phase C)
SET
IDiff>0.15×IBias(C)
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Where: IDiff: differential current IBias: restraint current A: phase A B: phase B C: phase C SET
IDiff>[87L.I_Pkp_CTS]
EN
[87L.En_CTS_Blk]
SIG
CT circuit failure
SIG
87L.FO1.Alm_Diff
&
>=1
SIG
SIG
>=1 & &
87L.On Common differential condition
Differential condition 1 (phase A)
phase A
& SIG
Common differential condition
Differential condition 1 (phase B)
phase B
& SIG
Common differential condition
Differential condition 1 (phase C)
phase C
When these signals [87L.En1], [87L.En2] and logic setting [87L.En] are all “1” and the signal [87L.Blk] is 0, the signal “Enable DIFF” is valid. They can be visible or invisible in the device configured before ex-work according to project requirements. If they are invisible, the signal “Enable DIFF (Local end)” is valid by default. SIG
Differential condition 1 (phase A)
SIG
DIFF permitted (phase A)
SIG
Differential condition 1 (phase B)
SIG
DIFF permitted (phase B)
SIG
Differential condition 1 (phase C)
SIG
DIFF permitted (phase C)
SIG
FD.Pkp
& Differential condition 2 (phase A)
& Differential condition 2 (phase B)
& Differential condition 2 (phase C)
DIFF permitted (phase A/B/C): current differential protection permissive signal for phase A/B/C
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that received from the remote end via communication channel. Please refer to section 3.8.5.9 about the conditions to send permissive signal. 3.8.5.2 DPFC Differential Element (stage 1) SIG
Differential condition 2 (phase A)
SIG
DPFC DIFF1 (phase A)
SIG
Differential condition 2 (phase B)
SIG
DPFC DIFF1 (phase B)
SIG
Differential condition 2 (phase C)
SIG
DPFC DIFF1 (phase C)
EN
[87L.En_DPFC1]
SIG
87L.Op_DPFC1 (phase A)
SIG
87L.Op_DPFC1 (phase B)
SIG
87L.Op_DPFC1 (phase C)
& 87L.Op_DPFC1 (phase A)
& 87L.Op_DPFC1 (phase B)
& 87L.Op_DPFC1 (phase C)
>=1 87L.Op_DPFC1
Where: DPFC DIFF1: stage 1 of DPFC differential element 3.8.5.3 DPFC Differential Element (stage 2) SIG
Differential condition 2 (phase A)
SIG
DPFC DIFF2 (phase A)
SIG
Differential condition 2 (phase B)
SIG
DPFC DIFF2 (phase B)
SIG
Differential condition 2 (phase C)
SIG
DPFC DIFF2 (phase C)
EN
[87L.En_DPFC2]
SIG
87L.Op_DPFC2 (phase A)
SIG
87L.Op_DPFC2 (phase B)
SIG
87L.Op_DPFC2 (phase C)
& 1¼ cycles
0ms
87L.Op_DPFC2 (phase A)
1¼ cycles
0ms
87L.Op_DPFC2 (phase B)
1¼ cycles
0ms
87L.Op_DPFC2 (phase C)
&
&
>=1 87L.Op_DPFC2
Where: DPFC DIFF2: stage 2 of DPFC differential element
3-94
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3.8.5.4 Steady-state Differential Element (stage 1) SIG
Differential condition 2 (phase A)
SIG
Steady-state DIFF1 (phase A)
SIG
Differential condition 2 (phase B)
SIG
Steady-state DIFF1 (phase B)
SIG
Differential condition 2 (phase C)
SIG
Steady-state DIFF1 (phase C)
EN
[87L.En_Biased1]
SIG
87L.Op_Biased1 (phase A)
SIG
87L.Op_Biased1 (phase B)
SIG
87L.Op_Biased1 (phase C)
& 87L.Op_Biased1 (phase A)
& 87L.Op_Biased1 (phase B)
& 87L.Op_Biased1 (phase C)
>=1 87L.Op_Biased1
Where: Steady-state DIFF1: stage 1 of steady-state differential element 3.8.5.5 Steady-state Differential Element (stage 2) SIG
Differential condition 2 (phase A)
SIG
Steady-state DIFF2 (phase A)
SIG
Differential condition 2 (phase B)
SIG
Steady-state DIFF2 (phase B)
SIG
Differential condition 2 (phase C)
SIG
Steady-state DIFF2 (phase C)
EN
[87L.En_Biased2]
SIG
87L.Op_Biased2 (phase A)
SIG
87L.Op_Biased2 (phase B)
SIG
87L.Op_Biased2 (phase C)
& 1¼ cycles
0ms
87L.Op_Biased2 (phase A)
1¼ cycles
0ms
87L.Op_Biased2 (phase B)
1¼ cycles
0ms
87L.Op_Biased2 (phase C)
&
&
>=1 87L.Op_Biased2
Where: Steady-state DIFF2: stage 2 of steady-state differential element
3-95
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3.8.5.6 Neutral Current Differential Element SIG
Differential condition 2 (phase A)
SIG
REF DIFF (phase A)
SIG
Differential condition 2 (phase B)
SIG
REF DIFF (phase B)
SIG
Differential condition 2 (phase C)
SIG
REF DIFF (phase C)
EN
[87L.En_Neutral]
SIG
87L.Op_Neutral (phase A)
SIG
87L.Op_Neutral (phase B)
SIG
87L.Op_Neutral (phase C)
& t
0ms
87L.Op_Neutral (phase A)
t
0ms
87L.Op_Neutral (phase B)
t
0ms
87L.Op_Neutral (phase C)
&
&
>=1 87L.Op_Neutral
3.8.5.7 Differential Inter-trip Element When a fault associated with high resistance occurrs in the outlet of long transmission line, the device of local end, which is near the fault, can pick up immediately, but, considering the influence of a considerable power source, the device of the remote end, which is far from the fault, can not pick up due to inapparent fault component. In order to avoid this case, any protection (such as distance protection, overcurrent protection and etc.) of local end operates, inter-trip signal of corresponding phase will be sent to the remote end. After receiving the inter-trip signal, the device of the remote end can pick up, if corresponding differential condition is met and the setting [87L.En_InterTrp] is set as “1”, the faulty phase will be inter-tripped. SIG
Differential condition 2 (phase A)
SIG
Inter-trip element (phase A)
SIG
Differential condition 2 (phase B)
SIG
Inter-trip element (phase B)
SIG
Differential condition 2 (phase C)
SIG
Inter-trip element (phase C)
EN
[87L.En_InterTrp]
SIG
87L.Op_InterTrp (phase A)
SIG
87L.Op_InterTrp (phase B)
SIG
87L.Op_InterTrp (phase C)
& 10ms
0ms
87L.Op_InterTrp (phase A)
10ms
0ms
87L.Op_InterTrp (phase B)
10ms
0ms
87L.Op_InterTrp (phase C)
&
&
>=1 87L.Op_InterTrp
3-96
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3.8.5.8 Weak Infeed SIG
3U0>1V
SIG
3U2>6V
SIG
UA<0.65UN
SIG
UB<0.65UN
SIG
UC<0.65UN
SIG
UAB<0.65UNN
SIG
UBC<0.65UNN
SIG
UCA<0.65UNN
SIG
VTS.Alm
SIG
4Ia
SIG
4Ib
SIG
4Ic
SIG
Permissive signal
SIG
[87L.FOx.Alm_Diff]
SIG
[CTS.Alm]
>=1
>=1
>=1 & >=1 Weak infeed logic
>=1
>=1
& 30ms
>=1
0
Where: Ia, Ib, Ic are three phases current of local end Ia_Rmt, Ib_Rmt, Ic_Rmt are three phases current of remote end UN is rated phase-to-ground voltage UNN is rated phase-to-phase voltage 3.8.5.9 Send Permissive Signal SIG
Differential condition 1 (phase A)
& Send permissive signal (phase A)
SIG
Differential condition 1 (phase B)
& Send permissive signal (phase B)
SIG
Differential condition 1 (phase C)
& Send permissive signal (phase C)
SIG
CB in open position
SIG
Weak infeed logic
SIG
FD.Pkp
>=1
3-97
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At weak infeed end, current fault detector element may not operate, weak infeed logic is used as alternate to determine fault condition by analyzing the voltage and current signals. When three binary inputs [52b_PhA], [52b_PhB] and [52b_PhC] are all energized, the device recognizes the circuit breaker in open position. 3.8.5.10 Differential Protection Self-check SIG
Common differential condition (phase A)
SIG
Common differential condition (phase B)
SIG
Common differential condition (phase C)
SIG
87L.On
SIG
Calculated Idiff ≠ Actual ldiff
EN
[87L.En_CapCurrComp]
>=1 & 10s
10s
87L.FOx.Alm_Diff
& 2s
10s
87L.FOx.Alm_Comp
Where: FOx: channel x Idiff: differential current of channel x Calculated Idiff ≠ Actual ldiff: |IDiff_Actual|<0.7|IDiff_Cal| or |IDiff_Cal|<0.7|IDiff_Actual| under normal condition.
3.8.6 Settings Table 3.8-2 Settings of current differential protection No.
Name
Range
Step
Unit
1
87L.I_Pkp
(0.050~30.000)×In
0.001
2
87L.K_Cr_CT
0.200~10.000
0.001
3
87L.I_Pkp_CTS
(0.050~30.000)×In
0.001
4
87L.XC1L
(40~60000)/In
1
ohm
5
87L.XC0L
(40~60000)/In
1
ohm
6
87L.Z_LocReac
(40~60000)/In
1
ohm
7
87L.Z_LocGndReac
(40~60000)/In
1
ohm
8
87L.Z_RmtReac
(40~60000)/In
1
ohm
9
87L.Z_RmtGndReac
(40~60000)/In
1
ohm
3-98
A
Remark Minimum pickup current setting of current differential protection Current ratio factor of CT
A
Current setting of differential protection when CT circuit failure Positive-sequence
capacitive
impedance of the line Zero-sequence
capacitive
impedance of the line Impedance setting of reactor of local line Impedance setting of ground reactor of local line Impedance setting of reactor of remote line Impedance setting of ground reactor of remote line
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory Enabling/disabling 10
87L.En
differential
protection
0 or 1
0: disable 1: enable Enabling/disabling stage 1 of DPFC
11
87L.En_DPFC1
0 or 1
current
differential
element 0: disable 1: enable Enabling/disabling stage 2 of DPFC
12
87L.En_DPFC2
0 or 1
current
differential
element 0: disable 1: enable Enabling/disabling stage 1 of steady-state current differential
13
87L.En_Biased1
element
0 or 1
0: disable 1: enable Enabling/disabling stage 2 of steady-state current differential 14
87L.En_Biased2
element
0 or 1
0: disable 1: enable Enabling/disabling 15
87L.En_Neutral
neutral
current differential element
0 or 1
0: disable 1: enable Enabling/disabling inter-tripping
16
87L.En_InterTrp
element
0 or 1
0: disable 1: enable Enabling/disabling
local
independent current differential protection (independent current differential 17
87L.En_LocDiff
local
0 or 1
protection
current
means
differential
protection can operate without permissive signal from remote end) 0: disable 1: enable
18
87L.En_CapCurrComp
Enabling/disabling
0 or 1
capacitive
current compensation
3-99
PCS-931 Line Differential Relay Date: 2014-03-05
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87L.En_CTS_Blk
0 or 1
protection
current blocked
during CT circuit failure 0: disable 1: enable
3.9 Current Direction 3.9.1 General Application Overcurrent protection is widely used in the power system as backup protection, but in some cases, the direction of current is necessary to aid to complete the selective tripping. As shown below: L EM
M C
Fault
D
N A
B
EN
Figure 3.9-1 Line fault description
When line LM has an earth fault, the fault currents flowing through the relay A and the relay D are of similar magnitude in most cases. It is desirable that the fault is isolated from the power system by tripping the circuit breaker C and circuit breaker D. Hence, the overcurrent protection of relay A and relay D require to associate with current direction to fulfill selective tripping. Directional earth fault protection has a time delay due to coordinate with that of downstream so it cannot clear the fault quickly.
3.9.2 Function Description The module computes direction of phase current and phase-to-phase current, zero-sequence current and negative-sequence current. The direction of phase current and phase-to-phase current equips with an under-voltage direction function to ensure that phase or phase-to-phase overcurrent protection has explicit directionality when the polarized voltage is too low for close up fault. The direction of zero-sequence current and negative-sequence current direction equips with an impedance compensation function to ensure that zero-sequence or negative-sequence overcurrent protection has explicit directionality when the zero-sequence voltage or the negative-sequence voltage is too low. 3.9.2.1 Phase/Phase-to-phase Current Direction By setting the characteristic angle [RCA_OC] to determine the most sensitive forward angle of phase current and phase-to-phase current, power value is calculated using phase current with 3-100
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3 Operation Theory
phase polarized voltage or phase-to-phase current with phase-to-phase polarized voltage to determine the direction of phase current or phase-to-phase current respectively in forward direction or reverse direction. When the power value is zero, neither forward direction nor reverse direction is considered. As shown below: jX U
φ
θ
I
R
O
Forward direction
Reverse direction
Figure 3.9-2 Vector diagram of current and voltage
Where: φ is the setting [RCA_OC] θ is the phase angle between polarized voltage and current The power value is calculated as below: P=U×[I×COS(θ-φ)] 1.
If P>0, the current direction polarized by U is forward direction
2.
If P<0, the current direction polarized by U is reverse direction
From above diagram can be seen, when θ=φ, P reaches to the maximum value. It is considered as the most sensitive forward direction. Hence, φ is called as sensitivity angle of phase overcurrent protection. 1.
Polarized voltage of phase or phase-to-phase current direction
In the event of asymmetrical fault, because phase or phase-to-phase voltage may decrease to very low voltage whereas positive-sequence voltage does not, the polarized voltage of phase or phase-to-phase current direction uses positive-sequence voltage to avoid wrong direction due to too low polarized voltage. Therefore, using positive-sequence voltage as polarized voltage can ensure that the direction determination has no dead zone for asymmetrical fault. For symmetric fault, if positive-sequence voltage decreases to 15%Un, the device uses memorized 3-101
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3 Operation Theory
positive-sequence voltage as polarized voltage, the memorized positive-sequence voltage is 1.5 cycles pre-fault positive-sequence voltage. 2.
Phase or phase-to-phase current direction under normal polarized voltage condition
When using normal polarized voltage to calculate phase and phase-to-phase current direction, there are total twelve direction determination algorithm including forward direction and reverse direction. Table 3.9-1 Direction description Direction Phase A
Phase B
Phase C
Phase AB
Phase BC
Phase CA
3.
Polarized Voltage
Current
Forward direction
U1a
Ia
Reverse direction
U1a
Ia
Forward direction
U1b
Ib
Reverse direction
U1b
Ib
Forward direction
U1c
Ic
Reverse direction
U1c
Ic
Forward direction
U1ab
Iab
Reverse direction
U1ab
Iab
Forward direction
U1bc
Ibc
Reverse direction
U1bc
Ibc
Forward direction
U1ca
Ica
Reverse direction
U1ca
Ica
Phase or phase-to-phase current direction for under-voltage conditions
When the symmetrical fault occurs on a power system, positive-sequence voltage may reduce to less than 0.15Un, the device will switch to phase or phase-to-phase current direction for under-voltage condition. The 1.5 cycle pre-fault positive-sequence voltage is used as polarized voltage with reverse threshold to ensure stable direction decision when three-phase voltage goes to approximately zero due to close up fault. At first, the threshold is forward offset before direction is determined, and the threshold will be reversed offset after direction is determined. 3.9.2.2 Zero-sequence/Negative-sequence Current Direction By setting the characteristic angle [RCA_ROC] and [RCA_NegOC] to determine the most sensitive forward angle of zero-sequence current and negative-sequence current, power value is calculated using zero-sequence current with zero-sequence voltage or negative-sequence current with negative-sequence voltage to determine the direction of zero-sequence current and negative-sequence current respectively in forward direction or reverse direction. When the power value is between 0 and -0.1In, neither forward direction nor reverse direction is considered.
3-102
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory jX
3U0
θ-180°
-3I0 φ
R O 3I0
θ
Reverse direction
Forward direction
Figure 3.9-3 Vector diagram of zero-sequence power
Vector diagram of negative-sequence power is similar to that of zero-sequence power. Where: φ is the setting [RCA_ROC] or the setting [RCA_NegOC] θ is the phase angle between zero/negative-sequence voltage and zero/negative-sequence current 3I0: calculated zero-sequence current by vector sum of Ia, Ib and Ic The power value is calculated as below: P=U×[I×COS(θ-φ)]
If P>0, the direction of zero /negative-sequence current is reverse direction
If P<-0.1InVA, the direction of zero /negative-sequence current is forward direction
1.
The direction of zero-sequence current
Calculating the power value using zero-sequence current (3I0) and zero-sequence voltage (3U0) to determine the direction of zero-sequence current According to the equation:
The zero-sequence current and the zero-sequence voltage can be gained by calculation 3-103
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3 Operation Theory
Zero-sequence power is: P=3U0×[3I0×COS(θ-φ)] 2.
The direction of negative-sequence current
Calculating the power value using negative-sequence current (3I2) and negative-sequence voltage (3U2) to determine the direction of negative-sequence current According to the equation:
The negative-sequence current and the negative-sequence voltage can be gained by calculation Negative-sequence power is: P=3U2×[3I2×COS(θ-φ)] 3.
The direction of zero-sequence/negative-sequence current with impedance compensation
When zero-sequence impedance or negative-sequence impedance behind the device is very small, if the fault in forward direction happens, the measured zero-sequence voltage or negative-sequence voltage by the device may be relatively small to determine correct direction. In order to solve this problem, compensated zero-sequence voltage and negative-sequence voltage are used for power calculation. The compensation formula is as follows:
is the setting [Z0_Comp], which cannot exceed the total zero-sequence impedance of the protected line is the setting [Z2_Comp], which cannot exceed the total negative-sequence impedance of the protected line
3-104
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3.9.3 Function Block Diagram DIR FwdDir_ROC RevDir_ROC FwdDir_NegOC RevDir_NegOC FwdDir_A FwdDir_B FwdDir_C RevDir_A RevDir_B RevDir_C FwdDir_AB FwdDir_BC FwdDir_CA RevDir_AB RevDir_BC RevDir_CA
3.9.4 I/O Signals Table 3.9-2 I/O signals of current direction No.
Output Signal
Description
1
FwdDir_ROC
The forward direction of zero-sequence power
2
RevDir_ROC
The reverse direction of zero-sequence power
3
FwdDir_NegOC
The forward direction of negative-sequence power
4
RevDir_NegOC
The reverse direction of negative-sequence power
5
FwdDir_A
The forward direction of phase-A current
6
FwdDir_B
The forward direction of phase-B current
7
FwdDir_C
The forward direction of phase-C current
8
RevDir_A
The reverse direction of phase-A current
9
RevDir_B
The reverse direction of phase-B current
10
RevDir_C
The reverse direction of phase-C current
11
FwdDir_AB
The forward direction of phase-AB current
12
FwdDir_BC
The forward direction of phase-BC current
13
FwdDir_CA
The forward direction of phase-CA current
3-105
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 14
RevDir_AB
The reverse direction of phase-AB current
15
RevDir_BC
The reverse direction of phase-BC current
16
RevDir_CA
The reverse direction of phase-CA current
3.9.5 Settings Table 3.9-3 Settings of current direction No.
Name
Range
Step
Unit
1
RCA_OC
30.00~89.00
0.01
Deg
2
RCA_ROC
30.00~89.00
0.01
Deg
3
RCA_NegOC
30.00~89.00
0.01
Deg
4
Z0_Comp
(0.000~4Unn)/In
0.001
ohm
5
Z2_Comp
(0.000~4Unn)/In
0.001
ohm
Remark The characteristic angle of directional phase overcurrent element The characteristic angle of directional earth fault element The characteristic angle of directional negative-sequence overcurrent element The
compensated
zero-sequence
impedance The
compensated
negative-sequence
impedance
3.10 Phase Overcurrent Protection 3.10.1 General Application When a fault occurs in power system, usually the fault current would be very large and phase overcurrent protection operates monitoring fault current is then adopted to avoid further damage to protected equipment. Directional element can be selected to improve the sensitivity and selectivity of the protection. For application on feeder-transformer circuits, second harmonic can also be selected to block phase overcurrent protection to avoid the effect of inrush current on the protection.
3.10.2 Function Description Phase overcurrent protection has following functions: 1.
Four-stage phase overcurrent protection with independent logic, current and time delay settings.
2.
All stages can be selected as definite-time or inverse-time characteristic. The inverse-time characteristic is selectable among IEC and ANSI/IEEE standard inverse-time characteristics, and a user-defined inverse-time curve is available for stage 1 of phase overcurrent protection.
3.
Direction control element can be selected to control each stage phase overcurrent protection with three options: no direction, forward direction and reverse direction.
4.
Second harmonic can be selected to block each stage of phase overcurrent protection.
3.10.2.1 Overview Phase overcurrent protection consists of following three elements: 3-106
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1.
Overcurrent element: each stage is independent overcurrent element.
2.
Direction control element: one direction control element shared by all overcurrent elements, and each overcurrent element can individually select protection direction.
3.
Harmonic blocking element: one harmonic blocking element shared by all overcurrent elements and each phase overcurrent element can individually enable the output signal from harmonic element as a blocking input.
3.10.2.2 Overcurrent Element The operation criterion for each stage of overcurrent element is: Ip> [50/51Px.I_Set]
Equation 3.10-1
Where: Ip is measured phase current. [50/51Px.I_Set] is the current setting of stage x (x=1, 2, 3, or 4) of overcurrent element. 3.10.2.3 Direction Control Element Please refer to section 3.9 for details. 3.10.2.4 Harmonic Blocking Element When phase overcurrent protection is used to protect feeder transformer circuits harmonic blocking function can be selected for each stage of phase overcurrent element by configuring logic setting [50/51Px.En_Hm2_Blk] (x=1, 2, 3 or 4) to prevent maloperation due to inrush current. When the percentage of second harmonic component to fundamental component of any phase current is greater than the setting [50/51P.K_Hm2], harmonic blocking element operates to block stage x overcurrent element if corresponding logic setting [50/51Px.En_Hm2_Blk] enabled. Operation criterion: Equation 3.10-2
Where: is second harmonic of phase current
is fundamental component of phase current. [50/51P.K_Hm2] is harmonic blocking coefficient. If fundamental component of any phase current is lower than the minimum operating current (0.1In), then harmonic calculation is not carried out and harmonic blocking element does not operate.
3-107
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3.10.2.5 Characteristic Curve All stages can be selected as definite-time or inverse-time characteristic, inverse-time operating characteristic is as follows.
Where: Iset is current setting [50/51Px.I_Set]. Tp is time multiplier setting [50/51Px.TMS]. α is a constant. K is a constant. C is a constant. I is measured phase current from line CT The user can select the operating characteristic from various inverse-time characteristic curves by setting [50/51Px.Opt_Curve], and parameters of available characteristics for selection are shown in the following table. Table 3.10-1 Inverse-time curve parameters 50/51Px.Opt_Curve
Time Characteristic
α
K
C
0
Definite time
1
IEC Normal inverse
0.14
0.02
0
2
IEC Very inverse
13.5
1.0
0
3
IEC Extremely inverse
80.0
2.0
0
4
IEC Short-time inverse
0.05
0.04
0
5
IEC Long-time inverse
120.0
1.0
0
6
ANSI Extremely inverse
28.2
2.0
0.1217
7
ANSI Very inverse
19.61
2.0
0.491
8
ANSI Inverse
0.0086
0.02
0.0185
9
ANSI Moderately inverse
0.0515
0.02
0.114
10
ANSI Long-time extremely inverse
64.07
2.0
0.25
11
ANSI Long-time very inverse
28.55
2.0
0.712
12
ANSI Long-time inverse
0.086
0.02
0.185
13
Programmable user-defined
If all available curves do not comply with user application, user may set [50/51Px.Opt_Curve] as “13” to customize the inverse-time curve characteristic with constants α, K and C. (only stage 1) When inverse-time characteristic is selected, if calculated operating time is less than setting [50/51Px.tmin], then the operating time of the protection changes to the value of setting 3-108
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[50/51Px.tmin] automatically. Define-time or inverse-time phase overcurrent protection drops off instantaneously after fault current disappears.
3.10.3 Function Block Diagram 50/51Px 50/51Px.En1
50/51Px.On
50/51Px.En2
50/51Px.StA
50/51Px.Blk
50/51Px.StB 50/51Px.StC 50/51Px.St 50/51Px.Op
3.10.4 I/O Signals Table 3.10-2 I/O signals of phase overcurrent protection No.
Input Signal
1
50/51Px.En1
2
50/51Px.En2
3
50/51Px.Blk
No.
Description Stage x of phase overcurrent protection enabling input 1, it is triggered from binary input or programmable logic etc. Stage x of phase overcurrent protection enabling input 2, it is triggered from binary input or programmable logic etc. Stage x of phase overcurrent protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
50/51Px.On
Stage x of phase overcurrent protection is enabled.
2
50/51Px.Op
Stage x of phase overcurrent protection operates.
3
50/51Px.St
Stage x of phase overcurrent protection starts.
4
50/51Px.StA
Stage x of phase overcurrent protection starts (A-Phase).
5
50/51Px.StB
Stage x of phase overcurrent protection starts (B-Phase).
6
50/51Px.StC
Stage x of phase overcurrent protection starts (C-Phase).
3-109
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3.10.5 Logic SET
Ia>[50/51Px.I_Set]
SET
Ib>[50/51Px.I_Set]
SET
Ic>[50/51Px.I_Set]
SET
[50/51Px.Opt_Dir]=1
SIG
Forward DIR
SET
[50/51Px.Opt_Dir]=2
& 50/51Px.StA
&
&
50/51Px.StB
&
& 50/51Px.StC
>=1
SIG
Reverse DIR
SET
[50/51Px.Opt_Dir]=0
SIG
I3P
SET
[50/51Px.En_Hm2_Blk]
EN
[50/51Px.En]
SIG
50/51Px.En1
SIG
50/51Px.En2
SIG
50/51Px.Blk
SIG
FD.Pkp
&
>=1 2nd Hm Detect
50/51Px.St
& Timer t
50/51Px.Op
t & & 50/51Px.On &
Figure 3.10-1 Logic diagram of phase overcurrent protection
x=1, 2, 3, 4
3.10.6 Settings Table 3.10-3 Settings of phase overcurrent protection No.
Name
Range
Step
Unit
Remark Setting
1
50/51P.K_Hm2
0.000~1.000
0.001
of
component
second for
harmonic
blocking
phase
overcurrent elements 2
50/51P1.I_Set
(0.050~30.000)×In
0.001
A
3
50/51P1.t_Op
0.000~20.000
0.001
s
Current setting for stage 1 of phase overcurrent protection Time delay for stage 1 of phase overcurrent protection Enabling/disabling stage 1 of phase
4
50/51P1.En
overcurrent protection
0 or 1
0: disable 1: enable Enabling/Disabling
5
50/51P1.En_BlkAR
auto-reclosing
blocked when stage 1 of phase
0 or 1
overcurrent protection operates 0: disable
3-110
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3 Operation Theory 1: enable Direction option for stage 1 of phase overcurrent protection 6
50/51P1.Opt_Dir
0, 1 or 2
0: no direction 1: forward direction 2: reverse direction Enabling/disabling second harmonic blocking for stage 1 of phase
7
50/51P1.En_Hm2_Blk
0 or 1
overcurrent protection 0: disable 1: enable Option of characteristic curve for
8
50/51P1.Opt_Curve
0~13
1
stage
1
of
phase
overcurrent
protection Time multiplier setting for stage 1 of 9
50/51P1.TMS
0.010~200.000
0.001
inverse-time
phase
overcurrent
protection Minimum operating time for stage 1 10
50/51P1.tmin
0.000~20.000
0.001
s
of inverse-time phase overcurrent protection Constant
11
50/51P1.Alpha
0.010~5.000
“α”
for
stage
customized
0.001
1
of
inverse-time
characteristic
phase
overcurrent
protection Constant 12
50/51P1.C
0.000~20.000
“C”
for
stage
customized
0.001
1
of
inverse-time
characteristic
phase
overcurrent
protection Constant 13
50/51P1.K
0.050~20.000
“K”
for
stage
customized
0.001
characteristic
1
of
inverse-time phase
overcurrent
protection 14
50/51P2.I_Set
(0.050~30.000)×In
0.001
A
15
50/51P2.t_Op
0.000~20.000
0.001
s
Current setting for stage 2 of phase overcurrent protection Time delay for stage 2 of phase overcurrent protection Enabling/disabling stage 2 of phase
16
50/51P2.En
overcurrent protection
0 or 1
0: disable 1: enable Enabling/Disabling
17
50/51P2.En_BlkAR
auto-reclosing
blocked when stage 2 of phase
0 or 1
overcurrent protection operates 0: disable 3-111
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3 Operation Theory 1: enable Direction option for stage 2 of phase overcurrent protection 18
50/51P2.Opt_Dir
0, 1 or 2
0: no direction 1: forward direction 2: reverse direction Enabling/disabling second harmonic blocking for stage 2 of phase
19
50/51P2.En_Hm2_Blk
0 or 1
overcurrent protection 0: disable 1: enable Option of characteristic curve for
20
50/51P2.Opt_Curve
0~12
stage
2
of
phase
overcurrent
protection Time multiplier setting for stage 2 of 21
50/51P2.TMS
0.010~200.000
0.001
inverse-time
phase
overcurrent
protection. Minimum operating time for stage 2 22
50/51P2.tmin
0.000~20.000
0.001
s
of inverse-time phase overcurrent protection
23
50/51P3.I_Set
(0.050~30.000)×In
0.001
A
24
50/51P3.t_Op
0.000~20.000
0.001
s
Current setting for stage 3 of phase overcurrent protection Time delay for stage 3 of phase overcurrent protection Enabling/disabling stage 3 of phase
25
50/51P3.En
overcurrent protection
0 or 1
0: disable 1: enable Enabling/Disabling
auto-reclosing
blocked when stage 3 of phase 26
50/51P3.En_BlkAR
0 or 1
overcurrent protection operates 0: disable 1: enable Direction option for stage 3 of phase overcurrent protection
27
50/51P3.Opt_Dir
0, 1 or 2
0: no direction 1: forward direction 2: reverse direction Enabling/disabling second harmonic blocking for stage 3 of phase
28
50/51P3.En_Hm2_Blk
0 or 1
overcurrent protection 0: disable 1: enable
29
50/51P3.Opt_Curve
0~12
Option of characteristic curve for
3-112
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3 Operation Theory stage
3
of
phase
overcurrent
protection Time multiplier setting for stage 3 of 30
50/51P3.TMS
0.010~200.000
0.001
inverse-time
phase
overcurrent
protection. Minimum operating time for stage 3 31
50/51P3.tmin
0.000~20.000
0.001
s
of inverse-time phase overcurrent protection
32
50/51P4.I_Set
(0.050~30.000)×In
0.001
A
33
50/51P4.t_Op
0.000~20.000
0.001
s
Current setting for stage 4 of phase overcurrent protection Time delay for stage 4 of phase overcurrent protection Enabling/disabling stage 4 of phase
34
50/51P4.En
overcurrent protection
0 or 1
0: disable 1: enable Enabling/Disabling
auto-reclosing
blocked when stage 4 of phase 35
50/51P4.En_BlkAR
0 or 1
overcurrent protection operates 0: disable 1: enable Direction option for stage 4 of phase overcurrent protection
36
50/51P4.Opt_Dir
0, 1 or 2
0: no direction 1: forward direction 2: reverse direction Enabling/disabling second harmonic blocking for stage 4 of phase
37
50/51P4.En_Hm2_Blk
0 or 1
overcurrent protection 0: disable 1: enable Option of characteristic curve for
38
50/51P4.Opt_Curve
0~12
stage
4
of
phase
overcurrent
protection Time multiplier setting for stage 4 of 39
50/51P4.TMS
0.010~200.000
0.001
inverse-time
phase
overcurrent
protection. Minimum operating time for stage 4 40
50/51P4.tmin
0.010~20.000
0.001
s
of inverse-time phase overcurrent protection
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3.11 Earth Fault Protection 3.11.1 General Application During normal operation of power system, there is trace residual current, whereas a fault current flows to earth will result in greater residual current. Therefore, residual current is adopted for the calculation of earth fault protection. In order to improve the selectivity of earth fault protection in power grid with multiple power sources, directional element can be selected to control earth fault protection. For application on line-transformer unit, second harmonic also can be selected to block earth fault protection to avoid the effect of sympathetic current on the protection.
3.11.2 Function Description Earth fault protection has following functions: 1.
Four-stage earth fault protection with independent logic, current and time delay settings.
2.
All stages can be selected as definite-time or inverse-time characteristic. The inverse-time characteristic is selectable, among IEC and ANSI/IEEE standard inverse-time characteristics, and a user-defined inverse-time curve is available for stage 1 of earth fault protection.
3.
Directional element can be selected to control each stage of earth fault protection with three options: no direction, forward direction and reverse direction.
4.
Second harmonic can be selected to block each stage of earth fault protection.
3.11.2.1 Overview Earth fault protection consists of following three elements: 1.
Overcurrent element: each stage equipped with one independent overcurrent element.
2.
Directional control element: one direction control element shared by all overcurrent elements, and each overcurrent element can individually select protection direction.
3.
Harmonic blocking element: one harmonic blocking element shared by all overcurrent elements and each overcurrent element can individually enable the output signal of harmonic blocking element as a blocking input.
3.11.2.2 Directional Earth-fault Element The operation criterion for each stage of earth fault protection is: 3I0>[50/51Gx.3I0_Set]
Equation 3.11-1
Where: 3I0 is the calculated residual current. [50/51Gx.3I0_Set] is the current setting of stage x (x=1, 2, 3, or 4) of earth fault protection.
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3.11.2.3 Direction Control Element Please refer to section 3.9 for details. 3.11.2.4 Harmonic Blocking Element In order to prevent effects of inrush current on earth fault protection, harmonic blocking function can be selected for each stage of earth fault element by configuring logic setting [50/51Gx.En_Hm2_Blk] (x=1, 2, 3 or 4). When the percentage of second harmonic component to fundamental component of residual current is greater than the setting [50/51G.K_Hm2], harmonic blocking element operates to block stage x of earth fault protection if corresponding logic setting [50/51Gx.En_Hm2_Blk] is enabled Operation criterion: Equation 3.11-2
Where: is second harmonic of residual current
is fundamental component of residual current. [50/51G.K_Hm2] is harmonic blocking coefficient. If fundamental component of residual current is lower than the minimum operating current (0.1In) then harmonic calculation is not carried out and harmonic blocking element does not operate. 3.11.2.5 Characteristic Curve All 4 stages earth fault protection can be selected as definite-time or inverse-time characteristic, and inverse-time operating time curve is as follows.
Equation 3.11-3
Where: Iset
is residual current setting [50/51Gx.3I0_Set].
Tp is time multiplier setting [50/51Gx.TMS]. K is a constant C is a constant. α is a constant. 3-115
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3 Operation Theory
3I0 is the calculated residual current. The user can select the operating characteristic from various inverse-time characteristic curves by setting [50/51Gx.Opt_Curve], and parameters of available characteristics for selection are shown in the following table. Table 3.11-1 Inverse-time curve parameters 50/51Gx.Opt_Curve
Time Characteristic
K
α
C
0
Definite time
1
IEC Normal inverse
0.14
0.02
0
2
IEC Very inverse
13.5
1.0
0
3
IEC Extremely inverse
80.0
2.0
0
4
IEC Short-time inverse
0.05
0.04
0
5
IEC Long-time inverse
120.0
1.0
0
6
ANSI Extremely inverse
28.2
2.0
0.1217
7
ANSI Very inverse
19.61
2.0
0.491
8
ANSI Inverse
0.0086
0.02
0.0185
9
ANSI Moderately inverse
0.0515
0.02
0.114
10
ANSI Long-time extremely inverse
64.07
2.0
0.25
11
ANSI Long-time very inverse
28.55
2.0
0.712
12
ANSI Long-time inverse
0.086
0.02
0.185
13
Programmable User-defined
If all available curves do not comply with user application, user may set [50/51Gx.Opt_Curve] as “13” to customize the inverse-time curve characteristic, and constants K, α and C with configuration tool software. (only stage 1) When inverse-time characteristic is selected, if calculated operating time is less than setting [50/51Gx.tmin], then the operating time of the protection changes to the value of setting [50/51Gx.tmin] automatically. Define-time or inverse-time directional earth-fault protection drops off instantaneously after fault current disappears.
3.11.3 Function Block Diagram 50/51Gx 50/51Gx.En1
50/51Gx.On
50/51Gx.En2
50/51Gx.St
50/51Gx.Blk
50/51Gx.Op
3-116
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3 Operation Theory
3.11.4 I/O Signals Table 3.11-2 I/O signals of earth fault protection No.
Input Signal
1
50/51Gx.En1
2
50/51Gx.En2
3
50/51Gx.Blk
No.
Description Stage x of earth fault protection enabling input 1, it is triggered from binary input or programmable logic etc. Stage x of earth fault protection enabling input 2, it is triggered from binary input or programmable logic etc. Stage x of earth fault protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
50/51Gx.On
Stage x of earth fault protection is enabled.
2
50/51Gx.St
Stage x of earth fault protection starts.
3
50/51Gx.Op
Stage x of earth fault protection operates.
3.11.5 Logic SIG
FD.Pkp
EN
[50/51Gx.En]
SIG
50/51Gx.En1
SIG
50/51Gx.En2
SIG
50/51Gx.Blk
SET
3I0>[50/51Gx.3I0_Set]
EN
[50/51Gx.En_Abnor_Blk]
&
& & 50/51Gx.On
>=1
&
&
& SIG
No abnormal conditions
50/51Gx.St
>=1 Timer t
&
50/51Gx.Op
t
SET
[50/51Gx.Opt_Dir]=1
SIG
Forward DIR
SET
[50/51Gx.Opt_Dir]=2
SIG
Reverse DIR
SET
[50/51Gx.Opt_Dir]=0
SIG
CTS.Alm
EN
[50/51Gx.En_CTS_Blk]
SIG
I3P
SET
[50/51Gx.En_Hm2_Blk]
&
&
>=1
& >=1 2nd Hm Detect
&
Figure 3.11-1 Logic diagram of earth fault protection
3-117
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3 Operation Theory
Where: x=1, 2, 3, 4 Abnormal condition 1: when the system is under pole disagreement condition, for 1-pole AR, earth fault protection will operate. If the logic setting [50/51Gx.En_Abnor_Blk] is set as “1”, the stage x of earth fault protection will be blocked. If the logic setting [50/51Gx.En_Abnor_Blk] is set as “0”, earth fault protection is not controlled by direction element. Abnormal condition 2: When manually closing circuit breaker, three phases of the circuit breaker maybe not operate simultaneously, and SOTF protection should operate. If the logic setting [50/51Gx.En_Abnor_Blk] is set as “1”, the stage x of earth fault protection will be blocked. If the logic setting [50/51Gx.En_Abnor_Blk] is set as “0”, earth fault protection is not controlled by direction element. Abnormal condition 3: VT circuit failure. If the logic setting [50/51Gx.En_Abnor_Blk] is set as “1”, the stage x of earth fault protection will be blocked. If the logic setting [50/51Gx.En_Abnor_Blk] is set as “0”, earth fault protection is not controlled by direction element.
3.11.6 Settings Table 3.11-3 Settings of earth fault protection No.
Name
Range
Step
Unit
Remark Setting
1
50/51G.K_Hm2
0.000~1.000
0.001
of
second
harmonic
component for blocking earth fault elements
2
50/51G1.3I0_Set
(0.050~30.000)×In
0.001
A
3
50/51G1.t_Op
0.000~20.000
0.001
s
Current setting for stage 1 of earth fault protection Time delay for stage 1 of earth fault protection Enabling/disabling stage 1 of
4
50/51G1.En
earth fault protection
0 or 1
0: disable 1: enable Enabling/Disabling auto-reclosing blocked when stage 1 of earth
5
50/51G1.En_BlkAR
0 or 1
fault protection operates 0: disable 1: enable Direction option for stage 1 of earth fault protection
6
50/51G1.Opt_Dir
0, 1 or 2
0: no direction 1: forward direction 2: reverse direction
7
50/51G1.En_Hm2_Blk
Enabling/disabling
0 or 1
second
harmonic blocking for stage 1 of
3-118
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3 Operation Theory earth fault protection 0: disable 1: enable Enabling/disabling blocking for stage 1 of earth fault protection 8
50/51G1.En_Abnor_Blk
0 or 1
under abnormal conditions 0: disable 1: enable Enabling/disabling blocking for stage 1 of earth fault protection
9
50/51G1.En_CTS_Blk
0 or 1
under CT failure conditions 0: disable 1: enable
10
50/51G1.Opt_Curve
0~13
Option of characteristic curve for
1
stage 1 of earth fault protection Time multiplier setting for stage 1
11
50/51G1.TMS
0.010~200.000
0.001
of
inverse-time
earth
fault
protection Minimum operating time for stage 12
50/51G1.tmin
0.050~20.000
0.001
s
1 of inverse-time earth fault protection Constant “α” for stage 1 of
13
50/51G1.Alpha
0.010~5.000
customized
0.001
characteristic
inverse-time earth
fault
protection Constant “C” for stage 1 of 14
50/51G1.C
0.000~20.000
customized
0.001
characteristic
inverse-time earth
fault
protection Constant “K” for stage 1 of 15
50/51G1.K
0.050~20.000
customized
0.001
characteristic
inverse-time earth
fault
protection 16
50/51G2.3I0_Set
(0.050~30.000)×In
0.001
A
17
50/51G2.t_Op
0.000~20.000
0.001
s
Current setting for stage 2 of earth fault protection Time delay for stage 2 of earth fault protection Enabling/disabling stage 2 of
18
50/51G2.En
earth fault protection
0 or 1
0: disable 1: enable Enabling/Disabling auto-reclosing
19
50/51G2.En_BlkAR
0 or 1
blocked when stage 2 of earth fault protection operates 3-119
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 0: disable 1: enable Direction option for stage 2 of earth fault protection 20
50/51G2.Opt_Dir
0, 1 or 2
0: no direction 1: forward direction 2: reverse direction Enabling/disabling
second
harmonic blocking for stage 2 of 21
50/51G2.En_Hm2_Blk
0 or 1
earth fault protection 0: disable 1: enable Enabling/disabling blocking for stage 2 of earth fault protection
22
50/51G2.En_Abnor_Blk
0 or 1
under abnormal conditions 0: disable 1: enable Enabling/disabling blocking for stage 2 of earth fault protection
23
50/51G2.En_CTS_Blk
0 or 1
under CT failure conditions 0: disable 1: enable
24
50/51G2.Opt_Curve
Option of characteristic curve for
0~12
stage 2 of earth fault protection Time multiplier setting for stage 2
25
50/51G2.TMS
0.010~200.000
0.001
of
inverse-time
earth
fault
protection Minimum operating time for stage 26
50/51G2.tmin
0.050~20.000
0.001
s
2 of inverse-time earth fault protection
27
50/51G3.3I0_Set
(0.050~30.000)×In
0.001
A
28
50/51G3.t_Op
0.000~20.000
0.001
s
Current setting for stage 3 of earth fault protection Time delay for stage 3 of earth fault protection Enabling/disabling stage 3 of
29
50/51G3.En
earth fault protection
0, 1 or 2
0: disable 1: enable Enabling/Disabling auto-reclosing blocked when stage 3 of earth
30
50/51G3.En_BlkAR
0 or 1
fault protection operates 0: disable 1: enable
31
50/51G3.Opt_Dir
0 or 1
Direction option for stage 3 of
3-120
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory earth fault protection 0: no direction 1: forward direction 2: reverse direction Enabling/disabling
second
harmonic blocking for stage 3 of 32
50/51G3.En_Hm2_Blk
0 or 1
earth fault protection 0: disable 1: enable Enabling/disabling blocking for stage 3 of earth fault protection
33
50/51G3.En_Abnor_Blk
0 or 1
under abnormal conditions 0: disable 1: enable Enabling/disabling blocking for stage 3 of earth fault protection
34
50/51G3.En_CTS_Blk
0 or 1
under CT failure conditions 0: disable 1: enable
35
50/51G3.Opt_Curve
Option of characteristic curve for
0~12
stage 3 of earth fault protection Time multiplier setting for stage 3
36
50/51G3.TMS
0.010~200.000
0.001
of
inverse-time
earth
fault
protection Minimum operating time for stage 37
50/51G3.tmin
0.050~20.000
0.001
s
3 of inverse-time earth fault protection
38
50/51G4.3I0_Set
(0.050~30.000)×In
0.001
A
39
50/51G4.t_Op
0.000~20.000
0.001
s
Current setting for stage 4 of earth fault protection Time delay for stage 4 of earth fault protection Enabling/disabling stage 4 of
40
50/51G4.En
earth fault protection
0, 1 or 2
0: disable 1: enable Enabling/Disabling auto-reclosing blocked when stage 4 of earth
41
50/51G4.En_BlkAR
0 or 1
fault protection operates 0: disable 1: enable Direction option for stage 4 of
42
50/51G4.Opt_Dir
earth fault protection
0 or 1
0: no direction 1: forward direction 3-121
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 2: reverse direction Enabling/disabling
second
harmonic blocking for stage 4 of 43
50/51G4.En_Hm2_Blk
0 or 1
earth fault protection 0: disable 1: enable Enabling/disabling blocking for stage 4 of earth fault protection
44
50/51G4.En_Abnor_Blk
0 or 1
under abnormal conditions 0: disable 1: enable Enabling/disabling blocking for stage 4 of earth fault protection
45
50/51G4.En_CTS_Blk
0 or 1
under CT failure conditions 0: disable 1: enable
46
50/51G4.Opt_Curve
Option of characteristic curve for
0~12
stage 4 of earth fault protection Time multiplier setting for stage 4
47
50/51G4.TMS
0.010~200.000
0.001
of
inverse-time
earth
fault
protection Minimum operating time for stage 48
50/51G4.tmin
0.050~20.000
0.001
s
4 of inverse-time earth fault protection
3.12 Overcurrent Protection for VT Circuit Failure 3.12.1 General Application When protection VT circuit fails, distance protection will be disabled. As a substitute, definite-time phase overcurrent protection and ground overcurrent protection will be enabled automatically, if selected, as backup protection of distance protection.
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3.12.2 Function Block Diagram 50PVT/50GVT 50PVT.En1
50PVT.On
50PVT.En2
50PVT.Op
50PVT.Blk
50PVT.St
50GVT.En1
50PVT.StA
50GVT.En2
50PVT.StB
50GVT.Blk
50PVT.StC 50GVT.On 50GVT.Op 50GVT.St
3.12.3 I/O Signals Table 3.12-1 I/O signals of overcurrent protection for VT circuit failure No.
Input Signal
1
50PVT.En1
2
50PVT.En2
3
50PVT.Blk
4
50GVT.En1
5
50GVT.En2
6
50GVT.Blk
No.
Description Phase overcurrent protection for VT circuit failure enabling input 1, it is triggered from binary input or programmable logic etc. Phase overcurrent protection for VT circuit failure enabling input 2, it is triggered from binary input or programmable logic etc. Phase overcurrent protection for VT circuit failure blocking input, it is triggered from binary input or programmable logic etc. Ground overcurrent protection for VT circuit failure enabling input 1, it is triggered from binary input or programmable logic etc. Ground overcurrent protection for VT circuit failure enabling input 2, it is triggered from binary input or programmable logic etc. Ground overcurrent protection for VT circuit failure blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
50PVT.On
Phase overcurrent protection for VT circuit failure is enabled.
2
50PVT.Op
Phase overcurrent protection for VT circuit failure operates.
3
50PVT.St
Phase overcurrent protection for VT circuit failure starts.
4
50PVT.StA
Phase overcurrent protection for VT circuit failure starts (A-Phase).
5
50PVT.StB
Phase overcurrent protection for VT circuit failure starts (B-Phase).
6
50PVT.StC
Phase overcurrent protection for VT circuit failure starts (C-Phase).
7
50GVT.On
Ground overcurrent protection for VT circuit failure is enabled.
8
50GVT.Op
Ground overcurrent protection for VT circuit failure operates.
9
50GVT.St
Ground overcurrent protection for VT circuit failure starts.
3-123
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3.12.4 Logic SIG
50GVT.En1
SIG
50GVT.En2
EN
[50GVT.En]
SIG
50GVT.Blk]
SIG
FD.Pkp
& & 50GVT.On & 50GVT.St & SET
3I0>[50GVT.3I0_Set]
SIG
FD.ROC.Pkp
SIG
VTS.Alm
SIG
50PVT.En1
SIG
50PVT.En2
EN
50PVT.En]
SIG
50PVT.Blk]
[50GVT.t_Op]
0ms
50GVT.Op
&
& & 50PVT.On
>=1
&
[50PVT.t_Op]
& SIG
FD.Pkp
SIG
VTS.Alm
SET
Ia>[50PVT.I_Set]
0ms
50PVT.Op 50PVT.St
& 50PVT.StA
& 50PVT.StB SET
Ib>[50PVT.I_Set] & 50PVT.StC
SET
Ic>[50PVT.I_Set]
Figure 3.12-1 Logic diagram of overcurrent protection for VT circuit failure
3.12.5 Settings Table 3.12-2 Settings of overcurrent protection for VT circuit failure No.
Name
Range
Step
Unit
1
50PVT.I_Set
(0.050~30.000)×In
0.001
A
2
50PVT.t_Op
0.000~10.000
0.001
s
Remark Current setting of phase overcurrent protection when VT circuit failure Time delay of phase overcurrent protection when VT circuit failure Enabling/disabling phase overcurrent
3
50PVT.En
protection when VT circuit failure
0 or 1
0: disable 1: enable
4
50GVT.3I0_Set
(0.050~30.000)×In
0.001
A
5
50GVT.t_Op
0.000~10.000
0.001
s
6
50GVT.En
0 or 1
Current setting of ground overcurrent protection when VT circuit failure Time delay of ground overcurrent protection when VT circuit failure Enabling/disabling
3-124
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PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory overcurrent protection when VT circuit failure 0: disable 1: enable
3.13 Residual Current SOTF Protection 3.13.1 General Application When the circuit breaker is closed manually or automatically, it is possible to switch on to an existing fault. This is especially critical if the line in the remote station is grounded, since earth fault protection would not clear the fault until their time delays had elapsed. In this situation, however, the fastest possible clearance is desired. Residual current SOTF (switch onto fault) protection is a complementary function to earth fault protection. With residual current SOTF protection, a fast trip is achieved for a fault on the line, when the line is being energized. It shall be responsive to all types of earth faults anywhere within the protected line, and it shall be enabled for a period of 400ms when the circuit is energized either manually or via an auto-reclosing system.
3.13.2 Function Description Residual current SOTF protection will operate to trip three-phase circuit breaker with a time delay of 60ms when 1-pole auto-reclosing. Residual current SOTF protection will operate to trip three-phase circuit breaker with a time delay of 100ms when 3-pole auto-reclosing or closing manually.
3.13.3 Function Block Diagram 50GSOTF 50GSOTF.En1
50GSOTF.On
50GSOTF.En2
50GSOTF.Op
50GSOTF.Blk
50GSOTF.St
3.13.4 I/O Signals Table 3.13-1 I/O signals of residual SOTF protection No.
Input Signal
1
50GSOTF.En1
2
50GSOTF.En2
3
50GSOTF.Blk
Description Residual current SOTF protection enabling input 1, it is triggered from binary input or programmable logic etc. Residual current SOTF protection enabling input 2, it is triggered from binary input or programmable logic etc. Residual current SOTF protection blocking input, it is triggered from binary input 3-125
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Output Signal
Description
1
50GSOTF.On
Residual current SOTF protection is enabled.
2
50GSOTF.Op
Residual current SOTF protection operates.
3
50GSOTF.St
Residual current SOTF protection starts.
3.13.5 Logic SIG
3-pole AR signal
SIG
Manual closing signal
SET
3I0>[50GSOTF.3I0_Set]
>=1 &
SIG
FD.ROC.Pkp
SIG
1-pole AR signal
SIG
50GSOTF.En1
SIG
50GSOTF.En2
SIG
50GSOTF.Blk
EN
[50GSOTF.En_3I0]
100ms
0ms
&
>=1 50GSOTF.Op
& 60ms
0ms
>=1 50GSOTF.St
& & 50GSOTF.On
Figure 3.13-1 Logic diagram of residual current SOTF protection
3.13.6 Settings Table 3.13-2 Settings of residual current SOTF protection No.
Name
Range
Step
Unit
1
50GSOTF.3I0_Set
(0.050~30.000)×In
0.001
A
Remark Current setting of residual current SOTF protection Enabling/disabling residual current
2
50GSOTF.En_3I0
SOTF protection
0 or 1
0: disable 1: enable
3.14 Voltage Protection Voltage protection has the function of protecting device against undervoltage and overvoltage. Both operational states are unfavorable as overvoltage may cause insulation breakdown while undervoltage may cause stability problem. Each voltage protection function has two individual stages with respective time delay. These voltage protection functions can be switched on or off separately. Selectable definite-time characteristic and multiple inverse-time characteristics are available.
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3.14.1 Overvoltage Protection 3.14.1.1 General Application Abnormal high voltages often occur e.g. in low loaded, long distance transmission lines, in islanded systems when generator voltage regulation fails, or load rejection of a generator. Even if compensation reactors are provided to avoid line overvoltage by compensation of the line capacitance and thus reduction of the overvoltage, the overvoltage will endanger the insulation if the reactors fail. The line must be de-energized within a very short time. The overvoltage protection in this device detects the phase voltages Ua, Ub and Uc or the phase-to-phase voltages Uab, Ubc and Uca with an option of any phase or all phases operation for output. The overvoltage protection can be used for tripping purpose as well as to initiate transfer trip, which selectable controlled by local circuit breaker. 3.14.1.2 Function Description Phase overvoltage protection has following functions: 1.
Two-stage phase overvoltage protection with independent logic, voltage and time delay settings.
2.
Stage 1 and stage 2 can be selected as definite-time or inverse-time characteristic. The inverse-time characteristic is selectable, among IEC and ANSI/IEEE standard inverse-time characteristics.
3.
Phase voltage or phase-to-phase voltage can be selected for protection calculation.
4.
“1-out-of-3” or “3-out-of-3” logic can be selected for protection criterion. (1-out-of-3 means any of three phase voltages, 3-out-of-3 means all three phase voltages)
1.
Operation Criterion
Users can select phase voltage or phase-to-phase voltage for the protection calculation. If setting [59Px.Opt_Up/Upp] is set to “0”, phase voltage criterion is selected and if [59Px.Opt_Up/Upp] is set to “1”, phase-to-phase voltage criterion is selected. When phase voltage or phase-to-phase voltage is greater than any enabled stage voltage setting, the stage protection picks up and operates after delay, which will drop off instantaneously when fault voltage disappears.
Phase voltage criterion
Two operation criteria of definite-time overvoltage protection are shown as follows, which of them is applied depending on the logic setting [59Px.Opt_1P/3P]. UΦ_max>[ 59Px.U_Set]
Equation 3.14-1
or Ua>[59Px.U_Set] & Ub>[59Px.U_Set] & Uc>[59Px.U_Set]
Equation 3.14-2 3-127
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Where: UΦ_max is the maximum value among three phase-voltage. Ua, Ub, Uc are three phase voltages. [59Px.U_Set] is the setting of stage x (x=1 or 2) overvoltage protection. When [59Px.Opt_1P/3P] is set as “0”, “1-out-of-3” logic (Equation 3.14-1) is selected as operation criterion, and when set as “1”, “3-out-of-3” logic (Equation 3.14-2) is selected.
Phase-to-phase voltage criterion
Two operation criteria of definite-time overvoltage protection are shown as follows, which of them is applied depending on the logic setting [59Px.Opt_1P/3P]. UΦΦ_max>[ 59Px.U_Set]
Equation 3.14-3
or Uab>[59Px.U_Set] & Ubc>[59Px.U_Set] & Uca>[59Px.U_Set]
Equation 3.14-4
[59Px.U_Set] is the setting of stage x (x =1 or 2) overvoltage protection. When [59Px.Opt_1P/3P] is set as “0”, “1-out-of-3” logic (Equation 3.14-3) is selected as operation criterion, and when set as “1”, “3-out-of-3” logic (Equation 3.14-4) is selected. 2.
Characteristic Curve
Phase overvoltage protection stage 1 and stage 2 can be selected as definite-time or inverse-time characteristic, and inverse-time operating time curve is as follows.
Where: Uset is the voltage setting [59Px.U_Set] (x=1 or 2). Tp is time multiplier setting [59Px.TMS]. K is a constant. C is a constant. α is a constant. U is the measured voltage For stage 1 and stage 2 of overvoltage protection, operating characteristic can be chosen from definite-time characteristic and 12 inverse-time characteristics by setting the logic setting [59Px.Opt_Curve]. The parameters of each characteristic are listed in the following table.
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Time Characteristic
K
α
C
0
Definite time
1
IEC Normal inverse
0.14
0.02
0
2
IEC Very inverse
13.5
1.0
0
3
IEC Extremely inverse
80.0
2.0
0
4
IEC Short-time inverse
0.05
0.04
0
5
IEC Long-time inverse
120.0
1.0
0
6
ANSI Extremely inverse
28.2
2.0
0.1217
7
ANSI Very inverse
19.61
2.0
0.491
8
ANSI Inverse
0.0086
0.02
0.0185
9
ANSI Moderately inverse
0.0515
0.02
0.114
10
ANSI Long-time extremely inverse
64.07
2.0
0.25
11
ANSI Long-time very inverse
28.55
2.0
0.712
12
ANSI Long-time inverse
0.086
0.02
0.185
When inverse-time characteristic is selected, if calculated operating time is less than setting [59Px.tmin], then the operating time changes to the value of setting [59Px.tmin] automatically. Define-time or inverse-time phase overvoltage protection drops off instantaneously when measured voltage is lower than reset voltage. 3.14.1.3 Function Block Diagram 59Px 59Px.En1
59Px.On
59Px.En2
59Px.St
59Px.Blk
59Px.St1 59Px.St2 59Px.St3 59Px.Op 59Px.Alm 59Px.Op_InitTT
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3.14.1.4 I/O Signals Table 3.14-2 I/O signals of overvoltage protection No.
Input Signal
1
59Px.En1
2
59Px.En2
3
59Px.Blk
No.
Output Signal
Description Stage x of overvoltage protection enabling input 1, it is triggered from binary input or programmable logic etc. Stage x of overvoltage protection enabling input 2, it is triggered from binary input or programmable logic etc. Stage x of overvoltage protection blocking input, it is triggered from binary input or programmable logic etc. Description
1
59Px.On
Stage x of overvoltage protection is enabled.
2
59Px.Op
Stage x of overvoltage protection operates.
3
59Px.St
Stage x of overvoltage protection starts.
4
59Px.St1
Stage x of overvoltage protection starts (A or AB).
5
59Px.St2
Stage x of overvoltage protection starts (B or BC).
6
59Px.St3
Stage x of overvoltage protection starts (C or CA).
7
59Px.Op_InitTT
Stage x of overvoltage protection operates to initiate transfer trip.
8
59Px.Alm
Stage x of overvoltage protection alarms.
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3.14.1.5 Logic EN
[59Px.En]
SIG
59Px.En1
SIG
59Px.En2
SIG
59Px.Blk
& & 59Px.On
BI
[52b_PhA]
BI
[52b_PhB]
BI
[52b_PhC]
EN
[59Px.En_52b_TT]
EN
[59Px.En_TT]
EN
[59Px.En_Alm]
SIG
& & & >=1 59Px.Op_InitTT
&
FD.Pkp
&
SIG
59Px.On
EN
[59Px.Opt_Up/Upp]
&
& >=1
SET
Timer t
&
t
UA>[59Px.U_Set]
&
& SET
UAB>[59Px.U_Set]
&
& >=1
SET
Timer t
&
t
UB>[59Px.U_Set]
59Px.Op
& SET
&
UBC>[59Px.U_Set]
>=1 &
& >=1
SET
>=1
Timer t t
UC>[59Px.U_Set]
& SET
59Px.Alm
&
>=1 59Px.St
UCA>[59Px.U_Set]
59Px.St1 59Px.St2 EN
[59Px.Opt_1P/3P]
59Px.St3
Figure 3.14-1 Logic diagram of stage x of overvoltage protection
x=1, 2 3.14.1.6 Settings Table 3.14-3 Settings of overvoltage protection No.
Name
Range
Step
Unit
1
59P1.U_Set
Un~2Unn
0.001
V
2
59P1.t_Op
0.000~30.000
0.001
s
Remark Voltage setting for stage 1 of overvoltage protection Time delay for stage 1 of overvoltage protection Enabling/disabling stage 1 of overvoltage
3
59P1.En
protection
0 or 1
0: disable 1: enable 3-131
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59P1.Opt_1P/3P
mode
0 or 1
0: 3-out-of-3 mode 1: 1-out-of-3 mode Option of phase-to-phase voltage or phase
5
59P1.Opt_Up/Upp
voltage
0 or 1
0: phase voltage 1: phase-to-phase voltage Enabling/disabling stage 1 of overvoltage
6
59P1.En_Alm
protection for alarm purpose
0 or 1
0: disable 1: enable Enabling/disabling transfer trip controlled by CB open position for stage 1 of
7
59P1.En_52b_TT
0 or 1
overvoltage protection 0: disable 1: enable Enabling/disabling stage 1 of overvoltage
8
59P1.En_TT
protection operate to initiate transfer trip
0 or 1
0: disable 1: enable
9
Option of characteristic curve for stage 1 of
59P1.Opt_Curve
0~12
10
59P1.TMS
0.010~200.000
0.001
11
59P1.tmin
0.050~20.000
0.001
s
12
59P2.U_Set
Un~2Unn
0.001
V
13
59P2.t_Op
0.000~30.000
0.001
s
overvoltage protection Time multiplier setting for stage 1 of inverse-time overvoltage protection Minimum delay for stage 1 of inverse-time overvoltage protection Voltage setting for stage 2 of overvoltage protection Time delay for stage 2 of overvoltage protection Enabling/disabling stage 2 of overvoltage
14
59P2.En
protection
0 or 1
0: disable 1: enable Option of 1-out-of-3 mode or 3-out-of-3
15
59P2.Opt_1P/3P
mode
0 or 1
0: 3-out-of-3 mode 1: 1-out-of-3 mode Option of phase-to-phase voltage or phase
16
59P2.Opt_Up/Upp
voltage
0 or 1
0: phase voltage 1: phase-to-phase voltage
17
59P2.En_Alm
0 or 1
Enabling/disabling stage 2 of overvoltage
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59P2.En_52b_TT
0 or 1
overvoltage protection 0: disable 1: enable Enabling/disabling stage 2 of overvoltage
19
59P2.En_TT
protection operate to initiate transfer trip
0 or 1
0: disable 1: enable Option of characteristic curve for stage 2 of
20
59P2.Opt_Curve
0~12
21
59P2.TMS
0.010~200.000
0.001
22
59P2.tmin
0.050~20.000
0.001
overvoltage protection Time multiplier setting for stage 2 of inverse-time overvoltage protection s
Minimum delay for stage 2 of inverse-time overvoltage protection
3.14.2 Undervoltage Protection 3.14.2.1 General Application The undervoltage protection can be applied to trip when fault occurs in a system. Two stages of undervoltage protection are available measuring phase voltages U A, UB and UC or phase-to-phase voltages UAB, UBC and UCA. The protection output can be selected for either any phase or all phases operation. The undervoltage protection is normally used as decoupling system rather than load shedding. 3.14.2.2 Function Description Phase undervoltage protection has following functions: 1.
Two-stage phase undervoltage protection with independent logic, voltage and time delay settings.
2.
Stage 1 and stage 2 can be selected as definite-time or inverse-time characteristic. The inverse-time characteristic is selectable, among IEC and ANSI/IEEE standard inverse-time characteristics.
3.
Phase voltage or phase-to-phase voltage can be selected for protection calculation.
4.
“1-out-of-3” or “3-out-of-3” logic can be selected for protection criterion. (1-out-of-3 means any of three phase voltages, 3-out-of-3 means all three phase voltages)
1.
Operation Criterion
Users can select phase voltage or phase-to-phase voltage for the protection calculation. If setting [27Px.Opt_Up/Upp] is set to “0”, phase voltage criterion is selected and if [27Px.Opt_Up/Upp] is
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set to “1”, phase-to-phase voltage criterion is selected. When phase voltage or phase-to-phase voltage is less than any enabled stage voltage setting, the stage protection picks up and operates after delay, which will drop off instantaneously when fault voltage disappears.
Phase voltage criterion
Two operation criteria of definite-time undervoltage protection are shown as follows, which of them is applied depending on the logic setting [27Px.Opt_1P/3P]. UΦ_min<[ 27Px.U_Set]
Equation 3.14-5
or Ua<[ 27Px.U_Set] & Ub<[27Px.U_Set] & Uc<[27Px.U_Set]
Equation 3.14-6
Where: UΦ_min is the minimum value among three phase voltages. Ua, Ub and Uc are three phase voltages. [27Px.U_Set] is the setting of stage x (x=1 or 2) undervoltage protection. When [27Px.Opt_1P/3P] is set as “0”, “1-out-of-3” logic (Equation 3.14-5) is selected as operation criterion, and when set as “1”, “3-out-of-3” logic (Equation 3.14-6) is selected.
Phase-to-phase voltage criterion
Two operation criteria of definite-time undervoltage protection are shown as follows, which of them is applied depending on the logic setting [27Px.Opt_Up/Upp]. UΦΦ_min<[ 27Px.U_Set]
Equation 3.14-7
or Uab<[27Px.U_Set] & Ubc<[27Px.U_Set] & Uca<[27Px.U_Set]
Equation 3.14-8
Where: UΦΦ_min is the minimum value among three phase-to-phase voltages. Uab, Ubc and Uca are three phase-to-phase voltages. [27Px.U_Set] is the setting of stage x (x =1 or 2) undervoltage protection. When the setting [27Px.Opt_1P/3P] is set as “0”, “1-out-of-3” logic (Equation 3.14-7) is selected as operation criterion, and when it is set as “1”, “3-out-of-3” logic (Equation 3.14-8) is selected. 2.
Characteristic Curve
Undervoltage protection stage 1 and stage 2 can be selected as definite-time or inverse-time characteristic, and inverse-time operating time curve is as follows.
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Where: Uset is the setting [27Px.U_Set] (x=1 or 2). Tp is time multiplier setting [27Px.TMS]. K is a constant. C is a constant. α is a constant. U is the measured voltage For stage 1 and stage 2 of undervoltage protection, operating characteristic can be chosen from definite-time characteristic and twelve inverse-time characteristics by setting the logic setting [27Px.Opt_Curve]. The parameters of each characteristic are listed in the following table. Table 3.14-4 Inverse-time curve parameters of phase undervoltage protection 27Px.Opt_Curve
Time Characteristic
K
α
C
0
Definite time
1
IEC Normal inverse
0.14
0.02
0
2
IEC Very inverse
13.5
1.0
0
3
IEC Extremely inverse
80.0
2.0
0
4
IEC Short-time inverse
0.05
0.04
0
5
IEC Long-time inverse
120.0
1.0
0
6
ANSI Extremely inverse
28.2
2.0
0.1217
7
ANSI Very inverse
19.61
2.0
0.491
8
ANSI Inverse
0.0086
0.02
0.0185
9
ANSI Moderately inverse
0.0515
0.02
0.114
10
ANSI Long-time extremely inverse
64.07
2.0
0.25
11
ANSI Long-time very inverse
28.55
2.0
0.712
12
ANSI Long-time inverse
0.086
0.02
0.185
When inverse-time characteristic is selected, if calculated operating time is less than setting [27Px.tmin], then the operating time changes to the value of setting [27Px.tmin] automatically.
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Define-time or inverse-time phase under voltage protection drops off instantaneously when measured voltage is higher than reset voltage. 3.14.2.3 Function Block Diagram 27Px 27Px.En1
27Px.On
27Px.En2
27Px.Alm
27Px.Blk
27Px.Op 27Px.St 27Px.St1 27Px.St2 27Px.St3
3.14.2.4 I/O Signals Table 3.14-5 I/O signals of undervoltage protection No.
Input Signal
1
27Px.En1
2
27Px.En2
3
27Px.Blk
No.
Output Signal
Description Stage x of undervoltage protection enabling input 1, it is triggered from binary input or programmable logic etc. Stage x of undervoltage protection enabling input 2, it is triggered from binary input or programmable logic etc. Stage x of undervoltage protection blocking input, it is triggered from binary input or programmable logic etc. Description
1
27Px.On
Stage x of undervoltage protection is enabled.
2
27Px.Op
Stage x of undervoltage protection operates.
3
27Px.Alm
Stage x of undervoltage protection alarms.
4
27Px.St
Stage x of undervoltage protection starts.
5
27Px.St1
Stage x of undervoltage protection starts (A or AB).
6
27Px.St2
Stage x of undervoltage protection starts (B or BC).
7
27Px.St3
Stage x of undervoltage protection starts (C or CA).
3.14.2.5 Logic When FD element reflecting current operates, including DPFC current element and residual current element, the undervoltage protection is released for operation. When any of the following conditions is fulfilled, the undervoltage protection will be blocked. 1.
VT signal fails;if the voltage comes from busbar VT, the voltage will restore to the normal immediately after the fault being cleared away. However, if the voltage comes from line VT, the voltage will drop to zero immediately after the fault is cleared. The undervoltage protection
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will be continuously in operation, thus an auxiliary current criterion is provided to solve it. 2.
Any phase is out of service, i.e. Up<0.01Un and IP<0.06In.
3.
Any phase of circuit breaker is open (binary input of normal close contact of breaker is energized) and the corresponding phase current is smaller than 0.06In. SIG
20ms
Pole dead
100ms >=1
SIG
VTS.Alm
Block UV
SIG
CB open position
Figure 3.14-2 Blocking logic of undervoltage protection EN
[27Px.En]
SIG
27Px.En1
SIG
27Px.En2
SIG
27Px.Blk
EN
[27Px.En_Alm]
SET
[27Px.Opt_1P/3P]
SIG
FD.Pkp
SIG
27Px.On
SIG
Block UV
SET
[27Px.Opt_Up/Upp]
& & 27Px.On
&
&
& >=1
SET
Timer t
& &
t
UA<[27Px.U_Set] &
SET
UAB<[27Px.U_Set] &
& >=1
SET
&
Timer t
27Px.Op
t
UB<[27Px.U_Set]
&
& SET
>=1
27Px.Alm
&
UBC<[27Px.U_Set] >=1 &
& >=1
SET
UC<[27Px.U_Set] &
Timer t t
>=1 27Px.St
SET
UCA<[27Px.U_Set] 27Px.St1 27Px.St2 27Px.St3
Figure 3.14-3 Logic diagram of stage x of undervoltage protection
x=1, 2
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3.14.2.6 Settings Table 3.14-6 Settings of undervoltage protection No.
Name
Range
Step
Unit
1
27P1.U_Set
0~Unn
0.001
V
2
27P1.t_Op
0.000~30.000
0.001
s
Remark Voltage setting for stage 1 of undervoltage protection Time delay for stage 1 of undervoltage protection Enabling/disabling stage 1 of undervoltage
3
27P1.En
protection
0 or 1
0: disable 1: enable Option of 1-out-of-3 mode or 3-out-of-3
4
27P1.Opt_1P/3P
mode
0 or 1
0: 3-out-of-3 mode 1: 1-out-of-3 mode Option
5
27P1.Opt_Up/Upp
of
voltage
criterion
adopting
phase-to-phase voltage or phase voltage
0 or 1
0: phase voltage 1: phase-to-phase voltage Enabling/disabling stage 1 of undervoltage
6
27P1.En_Alm
protection operate to alarm
0 or 1
0: disable 1: enable Option of characteristic curve for stage 1
7
27P1.Opt_Curve
0~12
1
8
27P1.TMS
0.010~200.000
0.001
9
27P1.tmin
0.050~20.000
0.001
s
10
27P2.U_Set
0~Unn
0.001
V
11
27P2.t_Op
0.000~30.000
0.001
s
of undervoltage protection Time multiplier setting for stage 1 of inverse-time undervoltage protection Minimum delay for stage 1 of inverse-time undervoltage protection Voltage setting for stage 2 of undervoltage protection Time delay for stage 2 of undervoltage protection Enabling/disabling stage 2 of undervoltage
12
27P2.En
protection
0 or 1
0: disable 1: enable Option of 1-out-of-3 mode or 3-out-of-3
13
27P2.Opt_1P/3P
mode
0 or 1
0: 3-out-of-3 mode 1: 1-out-of-3 mode
14
27P2.Opt_Up/Upp
Option
0 or 1
of
voltage
criterion
adopting
phase-to-phase voltage or phase voltage
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27P2.En_Alm
protection operate to alarm
0 or 1
0: disable 1: enable
16
27P2.Opt_Curve
0~12
17
27P2.TMS
0.010~200.000
0.001
18
27P2.tmin
0.050~20.000
0.001
Option of characteristic curve for stage 2
1
of undervoltage protection Time multiplier setting for stage 2 of inverse-time undervoltage protection s
Minimum delay for stage 2 of inverse-time undervoltage protection
3.15 Frequency Protection 3.15.1 Overfrequency Protection 3.15.1.1 General Application If the power frequency of regional rises due to the active power excess demand, overfrequency protection operates to perform generator rejection to shed part of the generators automatically according to the rising frequency so that power supply and the load are re-balanced. 3.15.1.2 Function Description Overfrequency protection consists of the four stages (stage 1 to stage 4). When system frequency is greater than the setting [81O.f_Pkp], overfrequency protection will put into service. In order to prevent possible maloperation of overfreqency protection in conditions of high harmonics, voltage circuit failures and so on, such blocking measures are carried out as follows: 1.
Blocking in undervoltage condition
If the positive voltage U1<0.15Un, the calculation of protection is not carried out and the output relay will be blocked. 2.
Frequency abnormality condition
When f<40Hz or f>65Hz, overfrequency protection will be blocked Operation criteria of overfrequency protection is shown in the following equation. f>[81O.OFx.f_Set]
Equation 3.15-1
Where: f is system frequency. [81O.OFx.f_Set] is the frequency setting of stage x (x=1, 2, 3, or 4) of overfrequency protection.
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3.15.1.3 Function Block Diagram 81O.OFx 81O.En1
81O.OFx.On
81O.En2
81O.St
81O.Blk
81O.OFx.Op
3.15.1.4 I/O Signals Table 3.15-1 I/O signals of overfrequency protection No.
Input Signal
1
81O.En1
2
81O.En2
3
81O.Blk
No.
Description Overfrequency protection enabling input 1, it is triggered from binary input or programmable logic etc. Overfrequency protection enabling input 2, it is triggered from binary input or programmable logic etc. Overfrequency protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
81O.OFx.On
Stage x of overfrequency protection is enabled (x=1, 2, 3 or 4).
2
81O.OFx.Op
Stage x of overfrequency protection operates (x=1, 2, 3 or 4).
3
81O.St
Overfrequency protection starts.
3.15.1.5 Logic SIG
81O.En1
SIG
81O.En2
EN
[81O.OF1.En]
SIG
81O.Blk
SIG
FD.Pkp
OTH
U1<0.15Un
SIG
f<40 or f>65
OTH
f>[81O.f_Pkp]
& & 81O.OF1.On
& ≥1
& 50ms
0ms 81O.St1
& SET
f>[81O.OF1.f_Set]
EN
[81O.OF1.En]
[81O.OF1.t_Op]
&
0ms
81O.OF1.Op
Figure 3.15-1 Logic diagram of overfrequency protection (stage 1)
3-140
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81O.En1
SIG
81O.En2
EN
[81O.OF2.En]
SIG
81O.Blk
SIG
FD.Pkp
OTH
U1<0.15Un
SIG
f<40 or f>65
OTH
f>[81O.f_Pkp]
& & 81O.OF2.On
& ≥1
& 50ms
0ms 81O.St2
& SET
f>[81O.OF2.f_Set]
EN
[81O.OF2.En]
[81O.OF2.t_Op]
&
0ms
81O.OF2.Op
Figure 3.15-2 Logic diagram of overfrequency protection (stage 2) SIG
81O.En1
SIG
81O.En2
EN
[81O.OF3.En]
SIG
81O.Blk
SIG
FD.Pkp
OTH
U1<0.15Un
SIG
f<40 or f>65
OTH
f>[81O.f_Pkp]
& & 81O.OF3.On
& ≥1
& 50ms
0ms 81O.St3
& SET
f>[81O.OF3.f_Set]
EN
[81O.OF3.En]
[81O.OF3.t_Op]
&
0ms
81O.OF3.Op
Figure 3.15-3 Logic diagram of overfrequency protection (stage 3) SIG
81O.En1
SIG
81O.En2
EN
[81O.OF4.En]
SIG
81O.Blk
SIG
FD.Pkp
OTH
U1<0.15Un
SIG
f<40 or f>65
OTH
f>[81O.f_Pkp]
& & 81O.OF4.On
& ≥1
& 50ms
0ms 81O.St4
& SET
f>[81O.OF4.f_Set]
EN
[81O.OF4.En]
[81O.OF4.t_Op]
&
0ms
81O.OF4.Op
Figure 3.15-4 Logic diagram of overfrequency protection (stage 4)
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81O.St1
SIG
81O.St2
SIG
81O.St3
SIG
81O.St4
≥1
≥1 81O.St
≥1
Figure 3.15-5 Logic diagram of overfrequency protection (start)
3.15.1.6 Settings Table 3.15-2 Settings of overfrequency protection No.
Name
Range
Step
Unit
1
81O.f_Pkp
50.000~65.000 (Hz)
0.001
Hz
2
81O.OF1.f_Set
50.000~65.000 (Hz)
0.001
Hz
3
81O.OF1.t_Op
0.050~20.000 (s)
0.001
s
Remark Frequency
pickup
81O.OF1.En
for
overfrequency protection Frequency setting for stage 1 of overfrequency protection Time
delay
for
stage
1
of
1
of
overfrequency protection Enabling/disabling
4
setting
stage
overfrequency protection
0 or 1
0: disable 1: enable
5
81O.OF2.f_Set
50.000~65.000 (Hz)
0.001
Hz
6
81O.OF2.t_Op
0.050~20.000 (s)
0.001
s
Frequency setting for stage 2 of overfrequency protection Time
delay
for
81O.OF2.En
2
of
2
of
overfrequency protection Enabling/disabling
7
stage
stage
overfrequency protection
0 or 1
0: disable 1: enable
8
81O.OF3.f_Set
50.000~65.000 (Hz)
0.001
Hz
9
81O.OF3.t_Op
0.050~20.000 (s)
0.001
s
Frequency setting for stage 3 of overfrequency protection Time
delay
for
81O.OF3.En
3
of
3
of
overfrequency protection Enabling/disabling
10
stage
stage
overfrequency protection
0 or 1
0: disable 1: enable
11
81O.OF4.f_Set
50.000~65.000 (Hz)
0.001
Hz
12
81O.OF4.t_Op
0.050~20.000 (s)
0.001
s
13
81O.OF4.En
0 or 1
Frequency setting for stage 4 of overfrequency protection Time
delay
for
Enabling/disabling
3-142
stage
4
of
4
of
overfrequency protection stage
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3.15.2 Underfrequency Protection 3.15.2.1 General Application In case of frequency decline due to lack of active power in the power system, underfrequency protection operates to shed part of the load according to the declined value of frequency to re-balance the power supply and the load. 3.15.2.2 Function Description Underfrequency protection consists of the four stages (stage 1 to stage 4). When system frequency is smaller than the setting [81U.f_Pkp], underfrequency protection will put into service. In order to prevent possible maloperation of underfrequency protection in conditions of high harmonics, voltage circuit failures and so on, such blocking measures are carried out as follows: 1.
Blocking in undervoltage condition
If the positive voltage U1<0.15Un, the calculation of protection is not carried out and the output relay will be blocked. 2.
df/dt blocking element
If -df/dt≥[81U.df/dt_Blk], the calculation of protection is not carried out and the output relay will be blocked. The blocking element will not be released automatically until the system frequency recovers to be less than the setting [81U.f_Pkp]. 3.
Frequency abnormality condition
When f<40Hz or f>65Hz, underfrequency protection will be blocked Operation criteria of underfrequency protection is shown in the following equation. f<[81U.UFx.f_Set]
Equation 3.15-2
Where: f is system frequency. [81U.UFx.f_Set] is the frequency settings of stage x (x=1, 2, 3 or 4) of underfrequency protection. The equation of df/dt blocking function is as follows. df/dt≥[81U.df/dt_Blk]
Equation 3.15-3
Where: df/dt is the frequency slip speed and the time step (i.e. dt) for the calucation is equal to 5 cycle. [81U.df/dt_Blk] is the setting of df/dt blocking underfrequency protection. Underfrequency protection can be blocked by the frequency slip speed (df/dt). If the logic setting 3-143
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[81U.UFx.En_df/dt_Blk] (x=1, 2, 3 or 4) is set as “1”, when Equation 3.15-2 and Equation 3.15-3 are met, it is decided that a fault occurred and the corresponding stage underfrequency protection is blocked at the same time for the purpose of waiting for operation of other related protection. The blocking signal will not reset until the system frequency recovers, i.e. the system frequency is greater than the setting [81U.f_Pkp]. If the logic setting is set as “0”, when Equation 3.15-2 and Equation 3.15-3 are met, the stage underfrequency protection will be released to operate. 3.15.2.3 Function Block Diagram 81U.UFx 81U.En1
81U.UFx.On
81U.En2
81U.St
81U.Blk
81U.UFx.Op
3.15.2.4 I/O Signals Table 3.15-3 I/O signals of underfrequency protection No.
Input Signal
1
81U.En1
2
81U.En2
3
81U.Blk
No.
Description Underfrequency protection enabling input 1, it is triggered from binary input or programmable logic etc. Underfrequency protection enabling input 2, it is triggered from binary input or programmable logic etc. Underfrequency protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
81U.UFx.On
Stage x of underfrequency protection is enabled (x=1, 2, 3 or 4).
2
81U.UFx.Op
Stage x of underfrequency protection operates (x=1, 2, 3 or 4).
3
81U.St
Underfrequency protection starts.
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3.15.2.5 Logic SIG
81U.En1
SIG
81U.En2
EN
[81U.UF1.En]
SIG
81U.Blk
SIG
FD.Pkp
OTH
U1<0.15Un
SIG
f<40 or f>65
OTH
f<[81U.f_Pkp]
50ms
SET
-df/dt>[81U.df/dt_Blk]
>=1
& & 81U.UF1.On
& & ≥1
0ms 81U.St1
& [81U.UF1.t_Op]
EN
81U.UF1.En_df/dt_Blk
SET
f<[81U.UF1.f_Set]
EN
[81U.UF1.En]
0ms
81U.UF1.Op
&
Figure 3.15-6 Logic diagram of underfrequency protection (stag1) SIG
81U.En1
SIG
81U.En2
EN
[81U.UF2.En]
SIG
81U.Blk
SIG
FD.Pkp
OTH
U1<0.15Un
SIG
f<40 or f>65
OTH
f<[81U.f_Pkp]
50ms
SET
-df/dt>[81U.df/dt_Blk]
>=1
& & 81U.UF2.On
& & ≥1
0ms 81U.St2
& [81U.UF2.t_Op]
EN
81U.UF2.En_df/dt_Blk
SET
f<[81U.UF2.f_Set]
EN
[81U.UF2.En]
0ms
81U.UF2.Op
&
Figure 3.15-7 Logic diagram of underfrequency protection (stag2)
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81U.En1
SIG
81U.En2
EN
[81U.UF3.En]
SIG
81U.Blk
SIG
FD.Pkp
OTH
U1<0.15Un
SIG
f<40 or f>65
OTH
f<[81U.f_Pkp]
50ms
SET
-df/dt>[81U.df/dt_Blk]
>=1
& & 81U.UF3.On
& & ≥1
0ms 81U.St3
& [81U.UF3.t_Op]
EN
81U.UF3.En_df/dt_Blk
SET
f<[81U.UF3.f_Set]
EN
[81U.UF3.En]
0ms
81U.UF3.Op
&
Figure 3.15-8 Logic diagram of underfrequency protection (stag3) SIG
81U.En1
SIG
81U.En2
EN
[81U.UF4.En]
SIG
81U.Blk
SIG
FD.Pkp
OTH
U1<0.15Un
SIG
f<40 or f>65
OTH
f<[81U.f_Pkp]
50ms
SET
-df/dt>[81U.df/dt_Blk]
>=1
& & 81U.UF4.On
& & ≥1
0ms 81U.St4
& [81U.UF4.t_Op]
EN
81U.UF4.En_df/dt_Blk
SET
f<[81U.UF4.f_Set]
EN
[81U.UF4.En]
0ms
81U.UF4.Op
&
Figure 3.15-9 Logic diagram of underfrequency protection (stag4)
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81U.St1
SIG
81U.St2
SIG
81U.St3
SIG
81U.St4
>=1 >=1 81U.St
>=1
Figure 3.15-10 Logic diagram of underfrequency protection (start)
3.15.2.6 Settings Table 3.15-4 Settings of underfrequency protection No.
Name
Range
Step
Unit
1
81U.f_Pkp
45.000~60.000
0.01
Hz
2
81U.df/dt_Blk
0.200~20.000
0.01
Hz/s
3
81U.UF1.f_Set
45.000~60.000
0.001
Hz
4
81U.UF1.t_Op
0.050~30.000
0.01
s
Remark Frequency
pickup
81U.UF1.En
for
underfrequency protection Rate
of
frequency
change
for
blocking underfrequency protection Frequency setting for stage 1 of underfrequency protection Time
delay
for
stage
1
of
1
of
underfrequency protection Enabling/disabling
5
setting
stage
underfrequency protection
0 or 1
0: disable 1: enable Enabling/disabling rate of frequency change
6
81U.UF1.En_df/dt_Blk
0 or 1
to
block
stage
1
of
underfrequency protection 0: disable 1: enable
7
81U.UF2.f_Set
45.000~60.000
0.001
Hz
8
81U.UF2.t_Op
0.050~30.000
0.01
s
Frequency setting for stage 2 of underfrequency protection Time
delay
for
81U.UF2.En
2
of
2
of
underfrequency protection Enabling/disabling
9
stage
stage
underfrequency protection
0 or 1
0: disable 1: enable Enabling/disabling rate of frequency change
10
81U.UF2.En_df/dt_Blk
0 or 1
to
block
stage
2
of
underfrequency protection 0: disable 1: enable
11
81U.UF3.f_Set
45.000~60.000
0.001
Hz
Frequency setting for stage 3 of 3-147
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81U.UF3.t_Op
0.050~30.000
0.01
s
Time
delay
for
81U.UF3.En
3
of
3
of
underfrequency protection Enabling/disabling
13
stage
stage
underfrequency protection
0 or 1
0: disable 1: enable Enabling/disabling rate of frequency change
14
81U.UF3.En_df/dt_Blk
0 or 1
to
block
stage
3
of
underfrequency protection 0: disable 1: enable
15
81U.UF4.f_Set
45.000~60.000
0.001
Hz
16
81U.UF4.t_Op
0.050~30.000
0.01
s
Frequency setting for stage 4 of underfrequency protection Time
delay
for
Enabling/disabling 17
81U.UF4.En
stage
4
of
4
of
underfrequency protection stage
underfrequency protection
0 or 1
0: disable 1: enable Enabling/disabling rate of frequency change
18
81U.UF4.En_df/dt_Blk
0 or 1
to
block
stage
4
of
underfrequency protection 0: disable 1: enable
3.16 Breaker Failure Protection 3.16.1 General Application Duplicated protection configurations are usually adopted for EHV power system, but the primary equipment, circuit breaker, is not duplicated. Breaker failure protection is adopted to cater circuit breaker tripping failure. Breaker failure protection issues a back-up trip command to trip adjacent circuit breakers in case of a tripping failure of the circuit breaker, and clears the fault as requested by the device. To utilize the protection information of faulty equipment and the electrical information of failure circuit breaker to constitute the criterion of breaker failure protection, it can ensure that the adjacent circuit breakers of failure circuit breaker are tripped with a shorter time delay, so that the affected area is minimized, and ensure stable operation of the entire power grid to prevent generators, transformers and other components from seriously damaged.
3.16.2 Function Description The instantaneous re-tripping function, after receiving tripping signal from other device and the corresponding phase overcurrent element operating, is available and provides phase-segregated 3-148
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binary output contact, which can ensure the circuit breaker is still tripped in case the secondary circuit between the device and the circuit breaker is abnormal, to avoid undesired tripping of breaker failure protection and the expansion of the affected area. Instantaneous re-tripping function does not block AR. When both the phase-segregated tripping contact from line protection and the corresponding phase overcurrent element operate, or both the three-phase tripping contact and any phase overcurrent element operate, breaker failure protection will send three-phase tripping command to trip local circuit breaker after time delay of [50BF.t1_Op] and trip all adjacent circuit breakers after time delay of [50BF.t2_Op]. When the protection element except undervoltage element within this device operates and issues tripping signal, breaker failure protection will also be initiated. Taking into account that the faulty current is too small for generator or transformer fault, the sensitivity of phase current element may not meet the requirements, zero-sequence current criterion and negative-sequence current criterion are provided in addition to the phase overcurrent element for breaker failure protection initiated by input signal [50BF.ExTrp3P_GT] from generator and transformer protection. They can be enabled or disabled by logic settings [50BF.En_3I0_3P] and [50BF.En_I2_3P] respectively. For some special fault (for example, mechanical protection or overvoltage protection operating), maybe faulty current is very small and current criterion of breaker failure protection is not met, in order to make breaker failure protection can also operate under the above situation, an input signal [50BF.ExTrp_WOI] is equipped to initiate breaker failure protection, once the input signal is energized, normally closed auxiliary contact of circuit breaker is chosen in addition to breaker failure current check to trigger breaker failure timer. The device takes current as priority with CB auxiliary contact (52b) as an option criterion for breaker failure check.
3.16.3 Function Block Diagram 50BF 50BF.ExTrp3P_L
50BF.On
50BF.ExTrp3P_GT
50BF.Op_ReTrpA
50BF.ExTrp_WOI
50BF.Op_ReTrpB
50BF.ExTrpA
50BF.Op_ReTrpC
50BF.ExTrpB
50BF.Op_ReTrp3P
50BF.ExTrpC
50BF.Op_t1
50BF.En
50BF.Op_t2
50BF.Blk
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3.16.4 I/O Signals Table 3.16-1 I/O signals of breaker failure protection No.
Input Signal
Description
1
50BF.ExTrp3P_L
Input signal of three-phase tripping contact from line protection
2
50BF.ExTrp3P_GT
3
50BF.ExTrpA
Input signal of phase-A tripping contact from external device
4
50BF.ExTrpB
Input signal of phase-B tripping contact from external device
5
50BF.ExTrpC
Input signal of phase-C tripping contact from external device
Input signal of three-phase tripping contact from generator or transformer protection
Input signal of three-phase tripping contact from external device. Once it is 6
50BF.ExTrp_WOI
energized, normally closed auxiliary contact of circuit breaker is chosen in addition to breaker failure current check to trigger breaker failure timers.
7
50BF.En
8
50BF.Blk
No.
Output Signal
Input signal of enabling breaker failure protection Breaker failure protection blocking input, such as function blocking binary input. When the input is 1, breaker failure protection is reset and time delay is cleared. Description
1
50BF.On
Breaker failure protection is enabled
2
50BF.Op_ReTrpA
Breaker failure protection operates to re-trip phase-A circuit breaker
3
50BF.Op_ReTrpB
Breaker failure protection operates to re-trip phase-B circuit breaker
4
50BF.Op_ReTrpC
Breaker failure protection operates to re-trip phase-C circuit breaker
5
50BF.Op_ReTrp3P
Breaker failure protection operates to re-trip three-phase circuit breaker
6
50BF.Op_t1
Stage 1 of breaker failure protection operates
7
50BF.Op_t2
Stage 2 of breaker failure protection operates
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3.16.5 Logic SIG
50BF.En
EN
[50BF.En]
SIG
50BF.Blk
SIG
50BF.On
SIG
FD.Pkp
EN
[50BF.En_ReTrp]
EN
[50BF.En_3I0_1P]
SET
3I0>[50BF.3I0_Set]
SIG
BFI_A
& 50BF.On
&
>=1
>=1
&
& >=1
BI
[50BF.ExTrpA]
SET
IA>[50BF.I_Set]
SIG
BFI_B
>=1
&
[50BF.ExTrpB]
SET
IB>[50BF.I_Set]
SIG
BFI_C
>=1
&
[50BF.ExTrpC]
SET
IC>[50BF.I_Set]
SIG
BFI_3P
BI
[50BF.ExTrp3P_L]
[50BF.t_ReTrp] 0ms
[50BF.Op_ReTrpB]
[50BF.t_ReTrp] 0ms
[50BF.Op_ReTrpC]
& >=1
BI
[50BF.Op_ReTrpA]
& >=1
BI
[50BF.t_ReTrp] 0ms
>=1 >=1 >=1 & >=1
BI
[50BF.ExTrp3P_GT]
BI
[50BF.ExTrp_WOI]
EN
[50BF.En_3I0_3P]
[50BF.Op_ReTrp3P]
&
>=1
&
SET
3I0>[50BF.3I0_Set]
EN
[50BF.En_I2_3P]
SET
I2>[50BF.I2_Set]
EN
[50BF.En_CB_Ctrl]
BI
[52b_PhA]
&
>=1 >=1 &
&
&
[50BF.t1_Op]
0ms
[50BF.Op_t1]
[50BF.t2_Op]
0ms
[50BF.Op_t2]
&
& BI
[52b_PhB]
BI
[52b_PhC]
SIG
50BF.On
SIG
FD.Pkp
&
Figure 3.16-1 Logic diagram of breaker failure protection
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3.16.6 Settings Table 3.16-2 Settings of breaker failure protection No.
Name
Range
Step
Unit
Remark Current setting of phase current criterion for BFP
1
50BF.I_Set
(0.050~30.000 )×In
0.001
A
2
50BF.3I0_Set
(0.050~30.000 )×In
0.001
A
3
50BF.I2_Set
(0.050~30.000 )×In
0.001
A
4
50BF.t_ReTrp
0.000~10.000
0.001
s
Time delay of re-tripping for BFP
5
50BF.t1_Op
0.000~10.000
0.001
s
Time delay of stage 1 for BFP
6
50BF.t2_Op
0.000~10.000
0.001
s
Time delay of stage 2 for BFP
7
50BF.En
0 or 1
8
50BF.En_ReTrp
0 or 1
9
50BF.En_3I0_1P
0 or 1
10
50BF.En_3I0_3P
0 or 1
11
12
50BF.En_I2_3P
50BF.En_CB_Ctrl
Current setting of zero-sequence current criterion for BFP Current setting of negative-sequence current criterion for BFP
Enabling/disabling breaker failure protection 0: disable 1: enable Enabling/disabling re-trip function for BFP 0: disable 1: enable Enabling/disabling zero-sequence current criterion for BFP initiated by single-phase tripping contact 0: disable 1: enable Enabling/disabling zero-sequence current criterion for BFP initiated by three-phase tripping contact 0: disable 1: enable
0 or 1
Enabling/disabling negative-sequence current criterion for BFP initiated by three-phase tripping contact 0: disable 1: enable
0 or 1
Enabling/disabling breaker failure protection can be initiated by normally closed contact of circuit breaker 0: disable 1: enable
3.17 Thermal Overload Protection 3.17.1 General Application During overload operation of a transmission line (specially for cable), great current results in 3-152
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greater heat to lead temperature increase and if the temperature reaches too high values the equipment might be damaged. Thermal overload protection estimates the internal heat content (temperature) continuously. This estimation is made by using a thermal model with two time constants, which is based on current measurement. When the temperature increases to the alarm value, the protection issues alarm signals to remind the operator for attention, and if the temperature continues to increase to the trip value, the protection sends trip command to disconnect the protected line.
3.17.2 Function Description Thermal overload protection has following functions:
Thermal time characteristic adopting IEC 60255-8
Two stages for alarm purpose and two stages for trip purpose
Thermal accumulation can be cleared by external input signal
The device provides a thermal overload model which is based on the IEC60255-8 standard. The thermal overload formulas are shown as below. 1.
Criterion of cooling start characteristic:
2.
Criterion of hot start characteristic:
Where: T = Time to operate (in seconds)
= Thermal time constant of the equipment to be protected, the setting [49.Tau] IB = Full load current rating, the setting [49.Ib_Set] I = The RMS value of the largest phase current IP = Steady state pre-loading before application of the overload k = Factor associated to the thermal state formula, the setting [49.K] ln = Natural logarithm The characteristic curve of thermal overload model is shown in Figure 3.17-1.
3-153
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t
Ip P=— IB
P = 0.0 P = 0.6 P = 0.8 P = 0.9
kIB
I
Figure 3.17-1 Characteristic curve of the thermal overload model
The hot start characteristic is adopted in the device. The calculation is carried out at zero of Ip, so users need not to set the value of Ip. Tripping outputs of the protection is controlled by current, even if the thermal accumulation value is greater than the setting for tripping, the protection drops off instantaneously when current disappears. Alarm outputs of the protection is not controlled by current, and only if the thermal accumulation value is greater than the setting for alarm, alarm output contacts, which can be connected to block the auto-reclosure, will operate.
3.17.3 Function Block Diagram 49 49.Clr_Cmd
49.On
49.En
49.St
49.Blk
49-1.Alm 49-1.Op 49-2.Alm 49-2.Op
3.17.4 I/O Signals Table 3.17-1 I/O signals of thermal overload protection No.
Input Signal
1
49.Clr_Cmd
2
49.En
3
49.Blk
Description Input signal of clear thermal accumulation value Thermal overload protection enabling input, it is triggered from binary input or programmable logic etc. Thermal overload protection blocking input, it is triggered from binary input or
3-154
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Output Signal
Description
1
49.On
Thermal overload protection is enabled.
2
49.St
Thermal overload protection starts.
3
49-1.Op
Stage 1 of thermal overload protection operates to trip.
4
49-2.Op
Stage 2 of thermal overload protection operates to trip.
5
49-1.Alm
Stage 1 of thermal overload protection operates to alarm.
6
49-2.Alm
Stage 2 of thermal overload protection operates to alarm.
3.17.5 Logic SIG
49.En
SIG
49.Blk
EN
[49-1.En_Trp]
EN
[49-1.En_Alm]
& & 49.On >=1
& SIG
FD.Pkp
49.St &
Timer t
49-1.Op
t SIG
I3P Timer t
& SET
[49.Ib_Set]
BI
[49.Clr_Cmd]
49-1.Alm
t
Figure 3.17-2 Logic diagram of thermal overload protection (stage 1)
SIG
49.En
SIG
49.Blk
EN
[49-2.En_Trp]
EN
[49-2.En_Alm]
SIG
FD.Pkp
& & 49.On >=1
& 49.St &
Timer t
49-2.Op
t SIG
I3P &
SET
[49.Ib_Set]
BI
[49.Clr_Cmd]
Timer t
49-2.Alm
t
Figure 3.17-3 Logic diagram of thermal overload protection (stage 2)
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3.17.6 Settings Table 3.17-2 Settings of thermal overload protection No.
Name
Range
Step
Unit
1
49-1.K
1.000~3.000
0.001
%
2
49-2.K
1.000~3.000
0.001
%
3
49.Ib_Set
(0.050~30.000 )×In
0.001
A
4
49.Tau
0.100~100.000
0.001
min
5
49-1.En_Alm
0 or 1
6
49-1.En_Trp
0 or 1
7
49-2.En_Alm
0 or 1
8
49-2.En_Trp
0 or 1
Remark The factor setting for stage 1 of thermal overload protection which is associated to the thermal state formula The factor setting for stage 2 of thermal overload protection which is associated to the thermal state formula The reference current setting of the thermal overload protection The time constant setting of the IDMT overload protection Enabling/disabling stage 1 of thermal overload protection for alarm purpose 0: disable 1: enable Enabling/disabling stage 1 of thermal overload protection for trip purpose 0: disable 1: enable Enabling/disabling stage 2 of thermal overload protection for alarm purpose 0: disable 1: enable Enabling/disabling stage 2 of thermal overload protection for trip purpose 0: disable 1: enable
3.18 Stub Overcurrent Protection 3.18.1 General Application Stub overcurrent protection is mainly designed for one and a half breakers arrangement. When line disconnector is open and transmission line is put into maintenance, line VT is no voltage. Distance protection is disabled, and stub overcurrent protection is enabled. It is used to protect stub section among for two circuit breakers and line disconnector. Usually, stub overcurrent protection is enabled automatically by normally closed auxiliary contact of line disconnector.
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CT2
Bus
Bus
To the device
Line
Line
Figure 3.18-1 3/2 breakers arrangement
3.18.2 Function Block Diagram 50STB 50STB.En1
50STB.On
50STB.En2
50STB.Op
50STB.Blk
50STB.St
50STB.89b_DS
50STB.StA 50STB.StB 50STB.StC
3.18.3 I/O Signals Table 3.18-1 I/O signals of stub overcurrent protection No.
Input Signal
1
50STB.En1
2
50STB.En2
3
50STB.Blk
4
50STB.89b_DS
No.
Description Stub overcurrent protection enabling input 1, it is triggered from binary input or programmable logic etc. Stub overcurrent protection enabling input 2, it is triggered from binary input or programmable logic etc. Stub overcurrent protection blocking input, it is triggered from binary input or programmable logic etc. Normally closed auxiliary contact of line disconnector
Output Signal
Description
1
50STB.On
Stub overcurrent protection is enabled.
2
50STB.Op
Stub overcurrent protection operates.
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50STB.St
Stub overcurrent protection starts.
4
50STB.StA
Phase A of stub overcurrent protection starts.
5
50STB.StB
Phase B of stub overcurrent protection starts.
6
50STB.StC
Phase C of stub overcurrent protection starts.
3.18.4 Logic Only one stage is available to stub overcurrent protection. Based on calculating summation current from dual CTs, the logic scheme of stub overcurrent protection is shown as Figure 3.18-2. SIG
50STB.En1
SIG
50STB.En2
SIG
50STB.Blk
EN
[50STB.En]
SIG
FD.Pkp
& & 50STB.On
&
[50STB.t_Op]
>=1 SIG
50STB.Op
50STB.89b_DS 50STB.St
& 50STB.StA SET
Ia>[50STB.I_Set]
& 50STB.StB SET
Ib>[50STB.I_Set]
& 50STB.StC SET
Ic>[50STB.I_Set]
Figure 3.18-2 Logic diagram of stub overcurrent protection
3.18.5 Settings Table 3.18-2 Settings of stub overcurrent protection No.
Name
Range
Step
Unit
1
50STB.I_Set
(0.050~30.000)×In
0.001
A
2
50STB.t_Op
0.000~10.000
0.001
s
Remark Current setting of stub overcurrent protection Time delay of stub overcurrent protection Enabling/disabling stub overcurrent
3
50STB.En
protection
0 or 1
1: enable 0: disable
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3.19 Dead Zone Protection 3.19.1 General Application Generally, fault current is very large when multi-phase fault occurs between CT and circuit breaker (i.e. dead zone) and it will have a greater impact on the system. Breaker failure protection can operate after a longer time delay, in order to clear the dead zone fault quickly and improve the system stability, dead zone protection with shorter time delay (compared with breaker failure protection) is adopted.
3.19.2 Function Description For some wiring arrangement (for example, circuit breaker is located between CT and the line), if fault occurs between CT and circuit breaker, line protection can operate to trip circuit breaker quickly, but the fault have not been cleared since local circuit breaker is tripped. Here dead zone protection is needed in order to trip relevant circuit breaker. The criterion for dead zone protection is: when dead zone protection is enabled, binary input of initiating dead zone protection is energized (by default, three-phase tripping signal is used to initiate dead zone protection), if overcurrent element for dead zone protection operates, then corresponding circuit breaker is tripped and three phases normally closed contact of the circuit breaker are energized, dead zone protection will operate to trip adjacent circuit breaker after a time delay.
3.19.3 Function Block Diagram 50DZ 50DZ.En1
50DZ.On
50DZ.En2
50DZ.Op
50DZ.Blk
50DZ.St
50DZ.Init
3.19.4 I/O Signal Table 3.19-1 I/O signals of dead zone protection No.
Input Signal
Description
1
50DZ.En1
Dead zone protection enabling input 1, it can be binary inputs or logic link.
2
50DZ.En2
Dead zone protection enabling input 2, it can be binary inputs or logic link.
3
50DZ.Blk
4
50DZ.Init
No.
Dead zone protection blocking input, such as function blocking binary input. When the input is 1, dead zone protection is reset and time delay is cleared. Initiation signal input of the dead zone protection.
Output Signal
Description
1
50DZ.On
Dead zone protection is enabled.
2
50DZ.St
Dead zone protection starts.
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50DZ.Op
Dead zone protection operates.
3.19.5 Logic EN
[50DZ.En]
SIG
50DZ.En1
SIG
50DZ.En2
SIG
50DZ.Blk
SIG
FD.Pkp
BI
[52b_PhA]
BI
[52b_PhB]
BI
[52b_PhC]
SET
Ia > [50DZ.I_Set]
SET
Ib > [50DZ.I_Set]
SET
Ic > [50DZ.I_Set]
SIG
& & 50DZ.On
&
&
50DZ.St
& >=1
[50DZ.t_Op]
&
0ms
50DZ.Op
50DZ.Init
Figure 3.19-1 Dead zone protection
3.19.6 Settings Table 3.19-2 Settings of dead zone protection No.
Name
Range
Step
Unit
Remark Current
1
50DZ.I_Set
(0.050~30.000)×In
0.001
A
setting
for
dead
zone
protection. This setting shall ensure the protection being sensitive enough if dead zone fault occurs.
2
50DZ.t_Op
0.000~10.000
0.001
s
Time delay of dead zone protection. Enabling/disabling
3
50DZ.En
0 or 1
-
dead
zone
protection. 1: enable 0: disable
3.20 Pole Discrepancy Protection 3.20.1 General Application The pole discrepancy of circuit breaker may occur during operation of a breaker with segregated operating gears for the three phases. The reason could be an interruption in the tripping/closing circuits, or mechanical failure. A pole discrepancy can only be tolerated for a limited period. When there is loading, zero-sequence or negative-sequence current will be generated in the power
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system, which will result in overheat of the generator or the motor. With the load current increasing, overcurrent elements based on zero-sequence current or negative-sequence current may operate. Pole discrepancy protection is required to operate before the operation of these overcurrent elements.
3.20.2 Function Description Pole discrepancy protection determines three-phase breaker pole discrepancy condition by its phase segregated CB auxiliary contacts. In order to improve the reliability of pole discrepancy protection, the asymmetrical current component can be selected as addition criteria when needed.
3.20.3 Function Block Diagram 62PD 62PD.En1
62PD.On
62PD.En2
62PD.Op
62PD.Blk
62PD.St
3.20.4 I/O Signals Table 3.20-1 I/O signals of pole discrepancy protection No.
Input Signal
1
62PD.En1
2
62PD.En2
3
62PD.Blk
No.
Description Pole discrepancy protection enabling input 1, it is triggered from binary input or programmable logic etc. Pole discrepancy protection enabling input 2, it is triggered from binary input or programmable logic etc. Pole discrepancy protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
62PD.On
Pole discrepancy protection is enabled.
2
62PD.Op
Pole discrepancy protection operates to trip
3
62PD.St
Pole discrepancy protection starts
3.20.5 Logic Phase-segregated circuit breaker auxiliary contacts are connected to the device. When the state of three phase-segregated circuit breaker auxiliary contacts are inconsistent, pole discrepancy protection will be started and initiate output after a time delay [62PD.t_Op]. Pole discrepancy protection can be blocked by external input signal [62PD.Blk]. In general, this input signal is usually from the output of 1-pole AR initiation, so as to prevent pole discrepancy protection from operation during 1-pole AR initiation.
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62PD.En1
SIG
62PD.En2
EN
[62PD.En]
BI
[62PD.Blk]
SIG
BI
& & 62PD.On
&
FD.Pkp
62PD.St
& [62PD.t_Op]
[62PD.In_PD]
EN
[62PD.En_3I0/I2_Ctrl]
SET
3I0>[62PD.3I0_Set]
SET
I2>[62PD.I2_Set]
0ms
62PD.Op
>=1 >=1
Figure 3.20-1 Logic diagram of pole discrepancy protection
The signal “62PD.In_PD” is input signal of pole discrepancy status, which is always from PD signal of circuit breaker position supervison module. When the states of three auxiliary contacts of phase-segregate circuit breaker are inconsistent, the signal is energized.
3.20.6 Settings Table 3.20-2 Settings of pole discrepancy protection No.
Name
Range
Step
Unit
1
62PD.3I0_Set
(0.050~30.000 )×In
0.001
A
2
62PD.I2_Set
(0.050~30.000 )×In
0.001
A
3
62PD.t_Op
0.000~600.000
0.001
s
4
62PD.En
0 or 1
5
62PD.En_3I0/I2_Ctrl
0 or 1
Remark Current setting of residual current criterion for pole discrepancy protection Current setting of negative-sequence current criterion for pole discrepancy protection Time delay of pole discrepancy protection Enabling/disabling pole discrepancy protection 0: disable 1: enable Enabling/disabling residual current criterion and negative-sequence current criterion for pole discrepancy protection 0: disable 1: enable
3.21 Broken Conductor Protection 3.21.1 General Application Single-phase earthing fault and two-phases earthing fault are the most common fault on circuits, the fault is easy to detect because the fault current will increase obviously. 3-162
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Broken-conductor fault is difficult to detect since there is no increase of current but negative-sequence current, so negative-sequence overcurrent protection can be considered to clear broken-conductor fault. However, under heavy load condition, negative-sequence current is relative large due to unbalance loading, but negative-sequence current because of broken-conductor fault under light load condition is relative small. If negative-sequence current protection is set larger than maximum negative-sequence current under loading, the protection may be failure to operate if broken-conductor fault happens under light load condition, negative-sequence overcurrent protection is therefore not suitable to apply for broken-conductor fault. The network of single-phase broken condition is similar to that of two-phases earthing fault, positive-sequence, negative-sequence and zero-sequence network is connected in parallel, I2/I1= Z0/(Z0+Z2), generally, zero-sequence impedance is larger than positive-sequence impedance, i.e. I2/I1>0.5. The network of two-phases broken condition is similar to that of single-phase earthing fault, positive-sequence, negative-sequence and zero-sequence network is connected in series, so I2/I1=1.
3.21.2 Function Description Broken-conductor fault mainly is single-phase broken or two-phases broken. According to the ratio of negative-sequence current to positive-sequence current (I2/I1), it is used to judge whether there is an broken-conductor fault. Negative-sequence current under normal operating condition (i.e. unbalance current) is due to CT error and unbalance load, so the ratio of negative-sequence current to positive-sequence current (amplitude) is relative steady. The value with margin can then be used as the setting of broken conductor protection. It is mainly used to detect broken-conductor fault and CT circuit failure as well.
3.21.3 Function Block Diagram 46BC 46BC.En1
46BC.On
46BC.En2
46BC.St
46BC.Blk
46BC.Op 46BC.Alm
3.21.4 I/O Signals Table 3.21-1 I/O signals of broken conductor protection No.
Input Signal
1
46BC.En1
2
46BC.En2
Description Enable broken conductor protection input 1, it is triggered from binary input or programmable logic etc. Enable broken conductor protection input 2, it is triggered from binary input or programmable logic etc.
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Broken conductor protection blocking input, it is triggered from binary input or
46BC.Blk
No.
programmable logic etc.
Output Signal
Description
1
46BC.On
Broken-conductor protection is enabled.
2
46BC.St
Broken-conductor protection starts.
3
46BC.Op
Broken-conductor protection operates to trip.
4
46BC.Alm
Broken-conductor protection operates to alarm.
3.21.5 Logic SIG
[46BC.En1]
SIG
[46BC.En2]
&
&
SIG
46BC.On
[46BC.Blk]
46BC.St & [46BC.t_Op] 0ms
SET
Ia>[46BC.I_Min]
SET
Ib>[46BC.I_Min]
SET
Ic>[46BC.I_Min]
>=1
SET
SET
&
I2/I1>[46BC.I2/I1_Set]
46BC.Op
[46BC.En_Trp] & 46BC.Alm
SET
[46BC.En_Alm]
Figure 3.21-1 Logic diagram of broken conductor protection
3.21.6 Settings Table 3.21-2 Settings of broken conductor protection No.
Name
Range
Step
Unit
Remark Ratio
1
46BC.I2/I1_Set
0.20~1.00
0.001
setting
(negative-sequence
current to positive-sequence current) of broken conductor protection
2
46BC.t_Op
0.000~600.000
0.001
s
3
46BC.I_Min
(0.050~30.000)×In
0.001
A
Time
delay
of
broken
conductor
protection Minimum operation current of broken conductor protection Enabling/disabling broken conductor
4
46BC.En_Trp
protection to operate to trip
0 or 1
0: disable 1: enable
5
46BC.En_Alm
Enabling/disabling broken conductor
0 or 1
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3.22 Reverse Power Protection 3.22.1 General Application Due to various reasons lead to lose motivity, synchronous generator is changed to run as a motor state, Absorbing energy from the power grid to drive a turbine (gas turbine) operation. In order to prevent turbine blade or gas turbine gear from being damaged, reverse power protection (reversal direction) should be configured.
3.22.2 Function Description Reverse power protection provides two stages: stage 1 can be set as alarm purpose or tripping purpose, and stage 2 is only for tripping purpose. When reverse power value of the generator detected is greater than reverse power protection setting ([32R1.P_Set]), reverse power protection can operate to alarm or trip with the time delay. After overload protection, over-excitation protection or loss-of-excitation protection, such as abnormal operation protection operates, the generator needs sequential tripping. The steam valve of turbine has to be closed firstly, and sequential tripping reverse power protection blocked by position contact of steam valve and circuit breaker operates to trip with the time delay. Generator power is calculated by three-phase voltage and three-phase current of generator terminal. Positive sequence component of active power is calculated by fundamental wave of the voltage and current The benefits is that reverse power protection is independent of the asymmetric component, so as to truly reflect the load of the engine power system. The level of generator absorbing the active power will depend on the need to overcome the friction loss, according to different types of generator units, the settings of reverse power protection will be different. During testing in the primary side of the generator unit, the active power absorbed by the generator can be measured by the device. The operation criterion: [32R.Opt_Dir]=1 AND P<-[32Rx.P_Set] or [32R.Opt_Dir]=0 AND P>[32Rx.P_Set]
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3.22.3 Function Block Diagram 32R 32R1.En
P1
32R1.Blk
32R1.On
32R2.En
32R1.St
32R2.Blk
32R1.Op 32R1.Alm 32R2.On 32R2.St 32R2.Op
3.22.4 I/O Signals Table 3.22-1 I/O signals of reverse power protection No.
Input Signal
1
32R1.En
2
32R1.Blk
3
32R2.En
4
32R2.Blk
No.
Description Enable stage 1 of reverse power protection input 1, it is triggered from binary input or programmable logic etc. Stage 1 of reverse power protection blocking input, it is triggered from binary input or programmable logic etc. Enable stage 2 of reverse power protection input 2, it is triggered from binary input or programmable logic etc. Stage 2 of reverse power protection blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
P1
Positive-sequence active power
2
32R1.On
Stage 1 of reverse power protection is enabled.
3
32R1.St
Stage 1 of reverse power protection starts.
4
32R1.Op
Stage 1 of reverse power protection operates to trip.
5
32R1.Alm
Stage 1 of reverse power protection operates to alarm.
6
32R2.On
Stage 2 of reverse power protection is enabled.
7
32R2.St
Stage 2 of reverse power protection starts.
8
32R2.Op
Stage 2 of reverse power protection operates to trip.
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3.22.5 Logic SIG
32R1.En
SIG
32R1.Blk
EN
[32R1.En_Alm]
EN
[32R1.En_Trp]
SIG
32R1.On
SET
[32R.Opt_Dir]=1
SIG
P1<-[32R1.P_Set]
& &
SET
[32R.Opt_Dir]=0
SIG
P1>[32R1.P_Set]
32R1.On
>=1
& & 32R1.St
>=1 &
& EN
[32R1.t_Alm]
0s
32R1.Alm
[32R1.t_Trp]
0s
32R1.Op
[32R1.En_Alm]
& EN
[32R1.En_Trp]
Figure 3.22-1 Logic diagram of stage 1 of reverse power protection SIG
32R2.En
SIG
32R2.Blk
EN
[32R2.En_Trp]
SIG
32R2.On
SET
[32R.Opt_Dir]=1
SIG
P1<-[32R2.P_Set]
SET
[32R.Opt_Dir]=0
SIG
P1>[32R2.P_Set]
& & 32R2.On
& 32R2.St
& >=1 &
& [32R2.t_Trp]
EN
0s
32R2.Op
[32R2.En_Trp]
Figure 3.22-2 Logic diagram of stage 2 of reverse power protection
When stage 2 of reverse power protection is used as sequential tripping reverse power protection, it can be selectable to be controlled by position contact of steam valve and circuit breaker
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3.22.6 Settings Table 3.22-2 Settings of broken conductor protection No.
Name
Range
Step
Unit
Remark Power setting of stage 1 of reverse
1
32R1.P_Set
(0.100~50.000)×In
0.01
W
power protection It should be greater 0.5 times the measured value of reverse power.
2
32R1.t_Alm
0.100~3000.000
0.01
s
3
32R1.t_Trp
0.100~3000.000
0.01
s
Time delay of stage 1 of reverse power protection for alarm purpose Time delay of stage 1 of reverse power protection for tripping purpose Enabling/disabling stage 1 of reverse
4
32R1.En_Trp
power protection to operate to trip
0 or 1
0: disable 1: enable Enabling/disabling stage 1 of reverse
5
32R1.En_Alm
power protection to operate to alarm
0 or 1
0: disable 1: enable Power setting of stage 2 of reverse
6
32R2.P_Set
(0.100~50.000)×In
0.01
W
power protection It should be greater 0.5 times the measured value of reverse power.
7
32R2.t_Trp
0.100~3000.000
0.01
s
Time delay of stage 2 of reverse power protection Enabling/disabling stage 2 of reverse
8
32R2.En_Trp
power protection to operate to alarm
0 or 1
0: disable 1: enable The directionality option of reverse
9
32R.Opt_Dir
power protection
0 or 1
0: forward direction 1: reverse direction
3.23 Synchrocheck 3.23.1 General Application The purpose of synchrocheck is to ensure two systems are synchronism before they are going to be connected. When two asynchronous systems are connected together, due to phase difference between the two systems, larger impact will be led to the system during closing. Thus auto-reclosing and manual closing are applied with the synchrocheck to avoid this situation and maintain the system 3-168
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stability. The synchrocheck includes synchronism check and dead charge check.
3.23.2 Function Description The synchronism check function measures the conditions across the circuit breaker and compares them with the corresponding settings. The output is only given if all measured quantities are simultaneously within their set limits. The dead charge check function measures the amplitude of line voltage and bus voltage at both sides of the circuit breaker, and then compare them with the live check setting [25.U_Lv] and the dead check setting [25.U_Dd]. The output is only given when the measured quantities comply with the criteria. Synchrocheck in this device can be used for auto-reclosing and manual closing for both single-breaker and dual-breakers. Details are described in the following sections. When used for the synchrocheck of single-breaker, comparative relationship between reference voltage (UL, three-phase protection voltage) and synchronism voltage (UB, single-phase synchronism voltage) for synchronism check is as follows. UL
UB
Figure 3.23-1 Relationship between reference voltage and synchronism voltage
Figure 3.23-1 shows the characteristics of synchronism check element used for the auto-reclosing if both line and busbar are live. The synchronism check element operates if voltage difference, phase angle difference and frequency difference are all within their setting values. 1.
The voltage difference is checked by the following equations.
UB≥[25.U_Lv] UL≥[25.U_Lv] |UB-UL|≤[25.U_Diff] 2.
The phase difference is checked by the following equations.
UB×UL×cosØ≥0 UB×UL×sin([25.phi_Diff])≥UB×UL×|sinØ| Where, 3-169
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Ø is phase difference between UB and UL 3.
The frequency difference is checked by the following equations.
|f(UB)-f(UL)|≤[25.f_Diff] If frequency check is disabled (i.e. [25.En_fDiffChk] is set as “0”), a detected maximum slip cycle can also be determined by the following equation based on phase difference setting and the synchronism check time setting: f =[25.phi_Diff]/(180×[25.t_SynChk]) Where: f is slip cycle If frequency check is enabled (i.e. [25.En_fDiffChk] is set as “1”), then [25.t_SynChk] can be set to be a very small value (default value is 50ms). 3.23.2.1 Synchronism Voltage Circuit Failure Supervision If synchronism voltage from line VT or busbar VT is used for auto-reclosing with synchronism or dead line or busbar check, the synchronism voltage is monitored. If the circuit breaker is in closed state (52b of three phases are de-energized), but the synchronism voltage is lower than the setting [25.U_Lv], it means that synchronism voltage circuit fails and an alarm [25.Alm_VTS_UB] or [25.Alm_VTS_UL] will be issued with a time delay of 10s. If auto-reclosing is disabled, or the logic setting [25.En_NoChk] is set as “1”, synchronism voltage is not required and synchronism voltage circuit failure supervision will be disabled. When synchronism voltage circuit failure is detected, function of synchronism check and dead check in auto-reclosing logic will be disabled. After synchronism voltage reverted to normal condition, the alarm will be reset automatically with a time delay of 10s. SIG
FD.Pkp
SIG
79.Inprog
SIG
UL<[25.U_Lv]
BI
>=1 & 10s
10s
>=1 &
25.MCB_VT_UL
EN
25.En_SynChk
SIG
25.En_DdL_DdB
SIG
25.En_DdL_LvB
SIG
25.En_LvL_DdB
SIG
25.Blk_VTS_UL
25.Alm_VTS_UL
>=1 &
Figure 3.23-2 Line voltage circuit failure supervision logic 3-170
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FD.Pkp
SIG
79.Inprog
SIG
UB<[25.U_Lv]
BI
>=1 & 10s
10s
>=1 & 25.Alm_VTS_UB
25.MCB_VT_UB
EN
25.En_SynChk
SIG
25.En_DdL_DdB
SIG
25.En_DdL_LvB
SIG
25.En_LvL_DdB
SIG
25.Blk_VTS_UB
>=1 &
Figure 3.23-3 Bus Voltage Circuit Failure Supervision logic
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3.23.3 Function Block Diagram 25 25.Blk_Chk
25.Ok_fDiffChk
25.Blk_SynChk
25.Ok_UDiffChk
25.Blk_DdChk
25.Ok_phiDiffChk
25.Start_Chk
25.Ok_DdL_DdB
25.Blk_VTS_UB
25.Ok_DdL_LvB
25.Blk_VTS_UL
25.Ok_LvL_DdB
25.MCB_VT_UB
25.Chk_LvL
25.MCB_VT_UL
25.Chk_DdL 25.Chk_LvB 25.Chk_DdB 25.Ok_DdChk 25.Ok_SynChk 25.Ok_Chk 25.Alm_VTS_UL 25.Alm_VTS_UB f_Prot f_Syn U_Diff f_Diff phi_Diff
3.23.4 I/O Signals Table 3.23-1 I/O signals of synchrocheck No.
Input Signal
Description
1
25.Blk_Chk
Input signal of blocking synchrocheck function for AR.
2
25.Blk_SynChk
3
25.Blk_DdChk
4
25.Start_Chk
5
25.Blk_VTS_UB
VT circuit supervision (UB) is blocked
6
25.Blk_VTS_UL
VT circuit supervision (UL) is blocked
Input signal of blocking synchronism check for AR. If the value is “1”, the output of synchronism check is “0”. Input signal of blocking dead charge check for AR. Input signal of starting synchronism check, usually it was starting signal of AR from auto-reclosing module.
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25.MCB_VT_UB
Binary input for VT MCB auxiliary contact (UB)
8
25.MCB_VT_UL
Binary input for VT MCB auxiliary contact (UL)
No.
Output Signal
Description To indicate that frequency difference condition for synchronism check of AR is
1
25.Ok_fDiffChk
2
25.Ok_UDiffChk
3
25.Ok_phiDiffChk
4
25.Ok_DdL_DdB
Dead line and dead bus condition is met
5
25.Ok_DdL_LvB
Dead line and live bus condition is met
6
25.Ok_LvL_DdB
Live line and dead bus condition is met
7
25.Chk_LvL
Line voltage is greater than the voltage setting [25.U_Lv]
8
25.Chk_DdL
Line voltage is smaller than the voltage setting [25.U_Dd]
9
25.Chk_LvB
Bus voltage is greater than the voltage setting [25.U_Lv]
10
25.Chk_DdB
Bus voltage is smaller than the voltage setting [25.U_Dd]
11
25.Ok_DdChk
To indicate that dead charge check condition of AR is met
12
25.Ok_SynChk
To indicate that synchronism check condition of AR is met
13
25.Ok_Chk
To indicate that synchrocheck condition of AR is met
14
25.Alm_VTS_UB
Synchronism voltage circuit is abnormal (UB)
15
25.Alm_VTS_UL
Reference voltage circuit is abnormal (UL)
16
f_Prot
Frequency of the voltage used by protection calculation
17
f_Syn
Frequency of the voltage used by synchrocheck
18
U_Diff
Voltage difference for synchronism check
19
f_Diff
Frequency difference for synchronism check
20
phi_Diff
Phase difference for synchronism check
met, frequency difference between UB and UL is smaller than [25.f_Diff]. To indicate that voltage difference condition for synchronism check of AR is met, voltage difference between UB and UL is smaller than [25.U_Diff] To indicate phase difference condition for synchronism check of AR is met, phase difference between UB and UL is smaller than [25.phi_Diff].
3.23.5 Logic These logic diagrams give the introduction to the working principles of the synchronism check and dead charge check. 3.23.5.1 Synchronism Check Logic The frequency difference, voltage difference, and phase difference of voltages from both sides of the circuit breaker are calculated in the device, they are used as input conditions of the synchronism check. When the synchronism check function is enabled and the voltages of both ends meets the requirements of the voltage difference, phase difference, and frequency difference, and there is no synchronism check blocking signal, it is regarded that the synchronism check conditions are met.
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25.Blk_Chk
SIG
25.Blk_SynChk
EN
[25.En_SynChk]
SIG
25.Start_Chk
SIG
UB>[25.U_Lv]
SIG
UL>[25.U_Lv]
SIG
25.Ok_UDiff
SIG
25.Ok_phiDiff
SIG
25.Ok_fDiff
>=1 &
&
& 50ms
0ms
[25.t_SynChk]
&
0ms
25.Ok_SynChk
Figure 3.23-4 Synchronism check
3.23.5.2 Dead Charge Check Logic The dead charge check conditions have three types, namely, live-bus and dead-line check, dead-bus and live-line check and dead-bus and dead-line check. The above three modes can be enabled and disabled by the corresponding logic settings. The device can calculate the measured bus voltage and line voltage at both sides of the circuit breaker and compare them with the settings [25.U_Lv] and [25.U_Dd]. When the voltage is higher than [25.U_Lv], the bus/line is regarded as live. When the voltage is lower than [25.U_Dd], the bus/line is regarded as dead. SIG
25.Blk_Chk
SIG
25.Blk_DdChk
>=1 &
SIG
25.Start_Chk
EN
[25.En_DdL_DdB]
SIG
Uref<[25.U_Dd]
SIG
Usyn>[25.U_Lv]
EN
[25.En_DdL_LvB]
SIG
Uref<[25.U_Dd]
SIG
Usyn>[25.U_Lv]
EN
[25.En_LvL_DdB]
SIG
Uref>[25.U_Lv]
SIG
Usyn<[25.U_Dd]
SIG
25.Alm_VTS_UB
SIG
25.Alm_VTS_UL
& [25.t_DdChk]
>=1
0ms
25.Ok_DdChk
& 25.Ok_DdL_DdB &
& 25.Ok_DdL_LvB &
& 25.Ok_LvL_DdB &
>=1
Figure 3.23-5 Dead charge check logic
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3.23.5.3 Synchrocheck Logic
SIG
25.Ok_SynChk
EN
25.En_NoChk
SIG
25.Ok_DdChk
>=1 25.Ok_Chk
Figure 3.23-6 Synchrocheck logic
This device comprises two synchrocheck modules, correspond to circuit breaker 1 and circuit breaker 2 respectively.
3.23.6 Settings Table 3.23-2 Settings of synchrocheck No.
Name
Range
Step
Unit
Remark Voltage selecting mode of line. 0: A-phase voltage 1: B-phase voltage
1
25.Opt_Source_UL
0~5
1
2: C-phase voltage 3: AB-phase voltage 4: BC-phase voltage 5: CA-phase voltage Voltage selecting mode of bus. 0: A-phase voltage 1: B-phase voltage
2
25.Opt_Source_UB
0~5
1
2: C-phase voltage 3: AB-phase voltage 4: BC-phase voltage 5: CA-phase voltage
3
25.U_Dd
0.05Un~0.8Un
0.001
V
Voltage threshold of dead check
4
25.U_Lv
0.5Un~Un
0.001
V
Voltage threshold of live check
5
25.K_Usyn
0.20-5.00
6
25.phi_Diff
0~ 89
Compensation
1
Deg
25.phi_Comp
0~359
for
Phase
difference
1
Deg
limit
of
synchronism check for AR Compensation
7
coefficient
synchronism voltage
difference
for
phase
between
two
synchronism voltages 8
25.f_Diff
0.02~1.00
0.01
Hz
9
25.U_Diff
0.02Un~0.8Un
V
10
25.t_DdChk
0.010~25.000
s
Frequency
difference
limit
of
synchronism check for AR Voltage
difference
limit
of
synchronism check for AR Time delay to confirm dead check
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25.t_SynChk
0.010~25.000
s
Time
delay
to
confirm
synchronism check condition Enabling/disabling
12
25.En_fDiffChk
frequency
difference check
0 or 1
0: disable 1: enable Enabling/disabling
13
25.En_SynChk
synchronism
check
0 or 1
0: disable 1: enable Enabling/disabling dead line and
14
25.En_DdL_DdB
dead bus (DLDB) check
0 or 1
0: disable 1: enable Enabling/disabling dead line and
15
25.En_DdL_LvB
live bus (DLLB) check
0 or 1
0: disable 1: enable Enabling/disabling live line and
16
25.En_LvL_DdB
dead bus (LLDB) check
0 or 1
0: disable 1: enable Enabling/disabling AR without any
17
25.En_NoChk
check
0 or 1
0: disable 1: enable
3.24 Automatic Reclosure 3.24.1 General Application To maintain the integrity of the overall electrical transmission system, the device is installed on the transmission system to isolate faulted segments during system disturbances. Faults caused by lightning, wind, or tree branches could be transient in nature and may disappear once the circuit is de-energized. According to statistics, for overhead transmission line, 80%~90% of the faults on overhead lines are the transient faults. Auto-reclosing systems are installed to restore the faulted section of the transmission system once the fault is extinguished (providing it is a transient fault). For certain transmission systems, auto-reclosure is used to improve system stability by restoring critical transmission paths as soon as possible. Besides overhead lines, other equipment failure, such as cables, busbar, transformer fault and so on, are generally permanent fault, and auto-reclosing is not initiated after faulty feeder is tripped. For some mixed circuits, such as overhead line with a transformer unit, hybrid transmission lines, etc., it is required to ensure that auto-reclosing is only initiated for faults overhead line section, or
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make a choice according to the situation.
3.24.2 Function Description This auto-reclosing logic can be used with either integrated device or external device. When the auto-reclosure is used with integrated device, the internal protection logic can initiate AR, moreover, a tripping contact from external device can be connected to the device via opto-coupler input to initiate integrated AR function. When external auto-reclosure is used, the device can output some configurable output to initiate external AR, such as, contact of initiating AR, phase-segregated tripping contact, single-phase tripping contact, three-phase tripping contact and contact of blocking AR. According to requirement, these contacts can be selectively connected to external auto-reclosure device to initiate AR. For phase-segregated circuit breaker, AR mode can be 1-pole AR for single-phase fault and 3-pole AR for multi-phase fault, or always 3-pole AR for any kinds of fault according to system requirement. For persistent fault or multi-shot AR number preset value is reached, the device will send final tripping command. The device will provide appropriate tripping command based on faulty phase selection if adopting 1-pole AR. AR can be enabled or disabled by logic setting or external signal via binary input. When AR is enabled, the device will output contact [79.On], otherwise, output contact [79.Off]. After some reclosing conditions, such as, CB position, CB pressure and so on, is satisfied, the device will output contact [79.Ready]. According to requirement, the device can be set as one-shot or multi-shot AR. When adopting multi-shot AR, the AR mode of first time reclosing can be set as 1-pole AR, 3-pole AR or 1/3-pole AR. The rest AR mode is only 3-pole AR and its number is determined by the maximum 3-pole reclosing number. For one-shot AR or first reclosing of multi-shot AR, AR mode can be selected by logic setting [79.En_1PAR], [79.En_3PAR] and [79.En_1P/3PAR] or external signal via binary inputs. When 3-pole or 1/3-pole AR mode is selected, the following three types of check modes can be selected: dead charge check, synchronism check and no check.
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3.24.3 Function Block Diagram 79 79.En
79.On
79.Blk
79.Off
79.Sel_1PAR
79.Close
79.Sel_3PAR
79.Ready
79.Sel_1P/3PAR
79.AR_Blkd
79.Trp
79.Active
79.Trp3P
79.Inprog
79.TrpA
79.Inprog_1P
79.TrpB
79.Inprog_3P
79.TrpC
79.Inprog_3PS1
79.LockOut
79.Inprog_3PS2
79.PLC_Lost
79.Inprog_3PS3
79.WaitMaster
79.Inprog_3PS4
79.CB_Healthy
79.WaitToSlave
79.Clr_Counter
79.Perm_Trp1P
79.Ok_Chk
79.Perm_Trp3P
79.Rcls_Status 79.Fail_Rcls 79.Succ_Rcls 79.Fail_Chk 79.Mode_1PAR 79.Mode_3PAR 79.Mode_1/3PAR
3.24.4 I/O Signals Table 3.24-1 I/O signals of auto-reclosing No.
Input Signal
1
79.En
2
79.Blk
Description Binary input for enabling AR. If the logic setting [79.En_ExtCtrl]=1, enabling AR will be controlled by the external signal via binary input Binary input for disabling AR. If the logic setting [79.En_ExtCtrl]=1, disabling AR will be controlled by the external input
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3
79.Sel_1PAR
4
79.Sel_3PAR
5
79.Sel_1P/3PAR
6
79.Trp
Input signal of single-phase tripping from line protection to initiate AR
7
79.Trp3P
Input signal of three-phase tripping from line protection to initiate AR
8
79.TrpA
Input signal of A-phase tripping from line protection to initiate AR
9
79.TrpB
Input signal of B-phase tripping from line protection to initiate AR
10
79.TrpC
Input signal of C-phase tripping from line protection to initiate AR
breaker Input signal for selecting 3-pole AR mode of corresponding circuit breaker Input signal for selecting 1/3-pole AR mode of corresponding circuit breaker
Input signal of blocking reclosing, usually it is connected with the 11
79.LockOut
operating signals of definite-time protection, transformer protection and busbar differential protection, etc.
12
79.PLC_Lost
13
79.WaitMaster
14
79.CB_Healthy
15
79.Clr_Counter
Clear the reclosing counter
16
79.Ok_Chk
Synchrocheck condition of AR is met
No.
Input signal of indicating the alarm signal that signal channel is lost Input signal of waiting for reclosing permissive signal from master AR (when reclosing multiple circuit breakers) The input for indicating whether circuit breaker has enough energy to perform the close function
Output Signal
Description
1
79.On
Automatic reclosure is enabled
2
79.Off
Automatic reclosure is disabled
3
79.Close
Output of auto-reclosing signal
4
79.Ready
Automatic reclosure have been ready for reclosing cycle
5
79.AR_Blkd
Automatic reclosure is blocked
6
79.Active
Automatic reclosing logic is actived
7
79.Inprog
Automatic reclosing cycle is in progress
8
79.Inprog_1P
The first 1-pole AR cycle is in progress
9
79.Inprog_3P
3-pole AR cycle is in progress
10
79.Inprog_3PS1
First 3-pole AR cycle is in progress
11
79.Inprog_3PS2
Second 3-pole AR cycle is in progress
12
79.Inprog_3PS3
Third 3-pole AR cycle is in progress
13
79.Inprog_3PS4
Fourth 3-pole AR cycle is in progress
14
79.WaitToSlave
15
79.Perm_Trp1P
16
79.Perm_Trp3P
17
79.Rcls_Status
Waiting signal of automatic reclosing which will be sent to slave (when reclosing multiple circuit breakers) Single-phase circuit breaker will be tripped once protection device operates Three-phase circuit breaker will be tripped once protection device operates Automatic reclosure status 0: AR is ready.
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79.Fail_Rcls
Auto-reclosing fails
19
79.Succ_Rcls
Auto-reclosing is successful
20
79.Fail_Chk
Synchrocheck for AR fails
21
79.Mode_1PAR
Output of 1-pole AR mode
22
79.Mode_3PAR
Output of 3-pole AR mode
23
79.Mode_1/3PAR
Output of 1/3-pole AR mode Automatic reclosure counter
24
79.N_Total_Rcls
Recorded number of all reclosing attempts
25
79.N_1PS1
Recorded number of first 1-pole reclosing attempts
26
79.N_3PS1
Recorded number of first 3-pole reclosing attempts
27
79.N_3PS2
Recorded number of second 3-pole reclosing attempts
28
79.N_3PS3
Recorded number of third 3-pole reclosing attempts
29
79.N_3PS4
Recorded number of fourth 3-pole reclosing attempts
3.24.5 Logic 3.24.5.1 AR Ready For the first reclosing of multi-shot AR, AR mode can be 1-pole AR or 3-pole AR, however, the selection is valid only to the first reclosing, after that it can only be 3-pole AR. When logic setting [79.SetOpt] is set as “1”, AR mode is determined by logic settings. When logic setting [79.SetOpt] is set as “0”, AR mode is determined by external signal via binary inputs. An auto-reclosure must be ready to operate before performing reclosing. The output signal [79.Ready] means that the auto-reclosure can perform at least one time of reclosing function, i.e., breaker open-close-open. When the device is energized or after the settings are modified, the following conditions must be met before the reclaim time begins: 1.
AR function is enabled.
2.
The circuit breaker is ready, such as, normal storage energy and no low pressure signal.
3.
The duration of the circuit breaker in closed position before fault occurrence is not less than the setting [79.t_CBClsd].
4.
There is no block signal of auto-reclosing.
After the auto-reclosure operates, the auto-reclosure must reset, i.e., [79.Active]=0, in addition to the above conditions for reclosing again. The logic of AR ready is shown in Figure 3.24-2. When there is a fault on an overhead line, the concerned circuit breakers will be tripped normally. After fault is cleared, the tripping command will drop off immediately. In case the circuit breaker is in failure, etc., and the tripping signal of the circuit breaker maintains and in excess of the time 3-180
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delay [79.t_PersistTrp], AR will be blocked, as shown in the following figure. SIG
Any tripping signal
SIG
79.LockOut
SIG
1-pole AR Initiation
SIG
Any tripping signal
En
[79.En_PDF_Blk]
SIG
79.Sel_1PAR
[79.t_PersistTrp] 0ms
>=1 0ms [79.t_DDO_BlkAR] [79.t_SecFault] 0ms
&
&
>=1 &
En
[79.N_Rcls]=1
SIG
Three phase trip
SIG
Phase A open
SIG
Phase B open
79.AR_Blkd
>=1 &
&
>=1
& SIG
Phase C open
Figure 3.24-1 Logic diagram of AR block
The input signal [79.CB_Healthy] must be energized before auto-reclosure gets ready. Because most circuit breakers can finish one complete process: open-closed-open, it is necessary that circuit breaker has enough energy before reclosing. When the time delay of AR is exhausted, AR will be blocked if the input signal [79.CB_Healthy] is still not energized within time delay [79.t_CBReady]. If this function is not required, the input signal [79.CB_Healthy] can be not to configure, and its state will be thought as “1” by default. In orde to block AR reliably even if the signal of manually open circuit breaker not connected to the input of blocking AR, when the circuit breaker is open by manually and there is CB position input under normal conditions, AR will be blocked with the time delay of 100ms if AR is not initated and no any trip signal. When auto-reclosure is blocked, auto-reclosing failure, synchrocheck failure or last shot is reached, or when the internal blocking condition of AR is met (such as, zone 3 of distance protection operates, the device operates for multi-phase fault, three-phase fault and so on. These flags of blocking AR have been configured in the device, additional configuration is not required.), auto-reclosure will be discharged immediately and next auto-reclosing will be disabled. When the input signal [79.LockOut] is energized, auto-reclosure will be blocked immediately. The blocking flag of AR will be also controlled by the internal blocking condition of AR. When the blocking flag of AR is valid, auto-reclosure will be blocked immediately.
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3 CB closed
[79.t_CBClsd]
SIG
79.Active
>=1
SIG
Any tripping signal
100ms
&
>=1
&
& 100ms
SIG
79.Ready
79.Inprog [79.CB_Healthy]
0ms
SIG
79.AR_Blkd
>=1
SIG
BlockAR
SIG
79.Fail_Rcls
SIG
79.Fail_Chk
SIG
Last shot is made
EN
[79.En]
EN
[79.En_ExtCtrl]
BI
0
[79.t_CBReady]
&
>=1 & >=1
& >=1 79.On
& SIG
79.En
SIG
79.Blk
&
Figure 3.24-2 Logic diagram of AR ready
When a fault occurs under pole disagreement condition, blocking AR can be enabled or disabled. The time delay [79.t_SecFault] is used to discriminate another fault which begins after 1-pole AR initiated. AR will be blocked if another fault happens after this time delay if the logic setting [79.En_PDF_Blk] is set as “1”, and 3-pole AR will be initiated if [79.En_PDF_Blk] is set as “1”. AR will be blocked immediately once the blocking condition of AR appears, but the blocking condition of AR will drop off with a time delay [79.t_DDO_BlkAR] after blocking signal disappears. When one-shot and 1-pole AR is enabled, auto-reclosure will be blocked immediately if there are binary inputs of multi-phase CB position is energized. When any protection element operates to trip, the device will output a signal [79.Active] until AR drop off (Reset Command). Any tripping signal can be from external protection device or internal protection element. AR function can be enabled by internal logic settings of AR mode or external signal via binary inputs in addition to internal logic setting [79.En]. When logic setting [79.En_ExtCtrl] is set as “1”, AR enable are determined by external signal via binary inputs and logic settings. When logic setting [79.En_ExtCtrl] set as “0”, AR enable are determined only by logic settings. For one-shot reclosing, if 1-pole AR mode is selected, auto-reclosure will reset when there is three-phase tripping signal or input signal of multi-phase open position. 3-182
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79.On
SIG
79.Mode_3PAR
SIG
79.Ready
SIG
79.Trp
SIG
79.Trp3P
SIG
79.TrpA
SIG
79.TrpB
SIG
79.TrpC
SIG
Phase A open
SIG
Phase B open
SIG
Phase C open
Logic
79.Perm_Trp3P 79.Perm_Trp1P
Figure 3.24-3 Logic diagram of tripping condition output
When AR is enabled, the device will output the signal [79.Perm_Trp3P] if AR is not ready, or AR mode is set as 3-Pole AR, or another fault occurs after the circuit breaker is open. 3.24.5.2 AR Initiation AR mode can be selected by external signal via binary inputs or internal logic settings. If the logic setting [79.SetOpt] set as “1”, AR mode is determined by the internal logic settings. If the logic settings [79.SetOpt] set as “0”, AR mode is determined by the external inputs. 1.
AR initiated by tripping signal of line protection
AR can be initiated by tripping signal of line protection, and the tripping signal may be from internal trip signal or external trip signal. When selecting 1-pole AR or 1/3-pole AR, line single-phase fault will trigger 1-pole AR. When AR is ready to reclosing (“79.Ready”=1) and the single-phase tripping command is received, this single-phase tripping command will be kept in the device, and 1-pole AR will be initiated after the single-phase tripping command drops off. The single-phase tripping command kept in the device will be cleared after the completion of auto-reclosing sequence (Reset Command). Its logic is shown in Figure 3.24-4.
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Reset Command
& >=1
SIG
Single-phase Trip
& SIG
&
79.Ready
SIG
79.Sel_1PAR
SIG
79.Sel_1P/3PAR
1-pole AR Initiation
>=1
Figure 3.24-4 Single-phase tripping initiating AR
When selecting 3-pole AR or 1/3-pole AR, three-phase tripping will trigger 3-pole AR. When AR is ready to reclosing (“79.Ready”=1) and the three-phase tripping command is received, this three-phase tripping command will be kept in the device, and 3-pole AR will be initiated after the three-phase tripping command drops off. The three-phase tripping command kept in the device will be cleared after the completion of auto-reclosing sequence (Reset Command). Its logic is shown in Figure 3.24-5. SIG
Reset Command
& >=1
SIG
Three-phase Trip
& SIG
&
79.Ready
SIG
79.Sel_3PAR
SIG
79.Sel_1P/3PAR
3-pole AR Initiation
>=1
Figure 3.24-5 Three-phase tripping initiating AR
2.
AR initiated by CB state
A logic setting [79.En_CBInit] is available for selection that AR is initiated by CB state. Under normal conditions, when AR is ready to reclosing (“79.Ready”=1), AR will be initiated if circuit breaker is open and corresponding phase current is nil. AR initiated by CB state can be divided into initiating 1-pole AR and 3-pole AR, their logics are shown in Figure 3.24-6 and Figure 3.24-7 respectively. Usually normally closed contact of circuit breaker is used to reflect CB state.
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SIG
Phase A open
SIG
Phase B open
>=1 & &
& &
SIG
Phase C open
EN
[79.En_CBInit]
SIG
79.Ready
SIG
79.Sel_1PAR
SIG
79.Sel_1P/3PAR
1-pole AR Initiation
>=1
Figure 3.24-6 1-pole AR initiation
SIG
Phase A open
SIG
Phase B open
SIG
Phase C open
EN
[79.En_CBInit]
SIG
79.Ready
EN
[79.Sel_3PAR]
EN
[79.Sel_1P/3PAR]
&
&
& 3-pole AR Initiation
>=1
Figure 3.24-7 3-pole AR initiation
3.24.5.3 AR Reclosing After AR is initiated, the device will output the initiating contact of AR. For 1-pole AR, in order to prevent pole discrepancy protection from maloperation under pole discrepancy conditions, the contact of “1-pole AR initiation” can be used to block pole discrepancy protection. When the dead time delay of AR expires after AR is initiated, as for 1-pole AR, the result of synchronism check will not be judged, and reclosing command will be output directly. As far as the 3-pole AR, if the synchronism check is enabled, the release of reclosing command shall be subject to the result of synchronism check. After the dead time delay of AR expires, if the synchronism check is still unsuccessful within the time delay [79.t_wait_Chk], the signal of synchronism check failure (79.Fail_Chk) will be output and the AR will be blocked. If 3-pole AR with no-check is enabled, the condition of synchronism check success (25.Ok_Chk) will always be established. And the signal of synchronism check success (25.Ok_Chk) from the synchronism check logic can be applied by auto-reclosing function inside the device or external auto-reclosure device.
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>=1 79.Inprog
79.Inprog_3P
SIG
1-pole AR Initiation
[79.t_Dd_1PS1]
0ms
SIG
3-pole AR Initiation
[79.t_Dd_3PS1]
0ms
>=1 AR Pulse
&
& [79.t_Wait_Chk] 0ms SIG
79.Fail_Chk
79.Ok_Chk
Figure 3.24-8 One-shot AR
In the process of channel abnormality, an internal fault occurs on the transmission line, backup protection at both ends of line will operate to trip the circuit breaker of each end. The operation time of backup protection at both ends of the line is possibly non-accordant, whilst the time delay of AR needs to consider the arc-extinguishing and insulation recovery ability for transient fault, so the time delay of AR shall be considered comprehensively according to the operation time of the device at both ends. When the communication channel of main protection is abnormal (input signal [79.PLC_Lost] is energized), and the logic setting [79.En_AddDly] is set as “1”, then the dead time delay of AR shall be equal to the original dead time delay of AR plus the extra time delay [79.t_AddDly], so as to ensure the recovery of insulation intensity of fault point when reclosing after transient fault. This extra time delay [79.t_AddDly] is only valid for the first shot AR.
>=1 SIG
BI
Any tripping signal
& &
[79.PLC_Lost]
SIG
79.Active
EN
[79.En_AddDly]
& Extend AR time
Figure 3.24-9 Extra time delay of AR
Reclosing pulse length may be set through the setting [79.t_PW_AR]. For the circuit breaker without anti-pump interlock, a logic setting [79.En_CutPulse] is available to control the reclosing pulse. When this function is enabled, if the device operates to trip during reclosing, the reclosing pulse will drop off immediately, so as to prevent multi-shot reclosing onto fault. After the reclosing command is issued, AR will drop off with time delay [79.t_Reclaim], and can carry out next reclosing.
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SIG
SIG
WaitMasterValid
& 0ms
50ms
0ms
[79.t_PW_AR]
>=1
AR Pulse
SIG
Single-phase Trip
SIG
Three-phase Trip
EN
[79.En_CutPulse]
79.AR_Out
>=1 & &
>=1 & SIG
[79.t_Reclaim]
79.AR_Out
0ms
Reset Command
Figure 3.24-10 Reclosing output logic
The reclaim timer defines a time from the issue of the reclosing command, after which the reclosing function resets. Should a new trip occur during this time, it is treated as a continuation of the first fault. The reclaim timer is started when the CB closing command is given. SIG
1-pole AR Initiation
>=1 0ms
SIG
3-pole AR Initiation
SIG
79.Fail_Rcls
SET
[79.Opt_Priority]=High
[79.t_Fail]
>=1 & 79.WaitToSlave
Figure 3.24-11 Wait toslave signal
The output signal “79.WaitToSlave” is usually configured to the signal “79.WaitMaster” of slave AR. Slave AR is permissible to reclosing only if master AR is reclosed successfully. 3.24.5.4 Reclosing Failure and Success For transient fault, the fault will be cleared after the device operates to trip. After the reclosing command is issued, AR will drop off after time delay [79.t_Reclaim], and can carry out next reclosing. When the reclosing is unsuccessful or the reclosing condition is not met after AR initiated, the reclosing will be considered as unsuccessful, including the following cases. 1.
If any protection element operates to trip when AR is enabled ([79.On]=1) and AR is not ready ([79.Ready]=0), the device will output the signal (79.Fail_Rcls).
2.
For one-shot AR, if the tripping command is received again within reclaim time after the reclosing pulse is issued, the reclosing shall be considered as unsuccessful.
3.
For multi-shot AR, if the reclosing times are equal to the setting value of AR number and the 3-187
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tripping command is received again after the last reclosing pulse is issued, the reclosing shall be considered as unsuccessful. 4.
The logic setting [79.En_FailCheck] is available to judge whether the reclosing is successful by CB state, when it is set as “1”. If CB is still in open position with a time delay [79.t_Fail] after the reclosing pulse is issued, the reclosing shall be considered as unsuccessful. For this case, the device will issue a signal (79.Fail_Rcls) to indicate that the reclosing is unsuccessful, and this signal will drop off after (Reset Command). AR will be blocked if the reclosing shall be considered as unsuccessful. SET
[79.Opt_Priority]=Low
SIG
79.WaitMaster
SIG
79.On
SIG
79.Ready
SIG
Any tripping command
& WaitMaster Valid
&
&
>=1 0ms
SIG
Last shot is made
SIG
79.Inprog
SIG
79.AR_Blkd
SIG
WaitMasterValid
200ms
>=1 79.Fail_Rcls
&
& [79.t_WaitMaster]
0ms
>=1 SIG
AR Pulse
SIG
3 CB closed
EN
[79.En_FailCheck]
& [79.t_Fail]
0ms
& & 79.Succ_Rcls
& 0
[79.t_Fail]
Figure 3.24-12 Reclosing failure and success
After unsuccessful AR is confirmed, AR will be blocked. AR will not enter into the ready state unless the circuit breaker position drops off , and can only begin to enter into the ready state again after the circuit breaker is closed. 3.24.5.5 Reclosing Numbers Control The device may be set up into one-shot or multi-shot AR. Through the setting [79.N_Rcls], the maximum number of reclosing attempts may be set up to 4 times. Generally, only one-shot AR is selected. Some corresponding settings may be hidden if one-shot AR is selected. 1.
1-pole AR
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[79.N_Rcls]=1 means one-shot reclosing. For one-shot 1-pole AR mode, 1-pole AR will be initiated only for single-phase fault and respective faulty phase selected, otherwise, AR will be blocked. For single-phase transient fault on the line, line protection device will operate to trip and 1-pole AR is initiated. After the dead time delay for 1-pole AR is expired, the device will send reclosing pulse, and then the auto-reclosure will drop off after the time delay [79.t_Reclaim] to ready for the next reclosing. For permanent fault, the device will operate to trip again after the reclosing is performed, and the device will output the signal of reclosing failure [79.Fail_Rcls]. [79.N_Rcls]>1 means multi-shot reclosing. For multi-shot reclosing in 1-pole AR mode, the first reclosing is 1-pole AR, and the subsequent reclosing can only be 3-pole AR. For single-phase transient fault on the line, line protection device will operate to trip and then 1-pole AR is initiated. After the dead time delay of the first reclosing is expired, the device will send reclosing pulse, and then the auto-reclosure will drop off after the time delay [79.t_Reclaim] to ready for the next reclosing. For permanent fault, the device will operate to trip again after the reclosing is performed, and then 3-pole AR is initiated. At this time, the time delay applies the setting [79.t_Dd_3PS2]. After the time delay is expired, if the reclosing condition is met, the device will send reclosing pulse. The sequence is repeated until the reclosing is successful or the maximum permit reclosing number [79.N_Rcls] is reached. If the first fault is multi-phase fault, the device operates to trip three-phase and initiate 3-pole AR. At this time, the time delay applies the setting [79.t_Dd_3PS1]. For the possible reclosing times of 3-pole AR in 1-pole AR mode, please refer to Table 3.24-2. 2.
3-pole AR
[79.N_Rcls]=1 means one-shot reclosing. For one-shot 3-pole AR mode, line protection device will operate to trip when a transient fault occurs on the line and 3-pole AR will be initiated. After the dead time delay for 3-pole AR is expired, the device will send reclosing pulse, and then the auto-reclosure will drop off after the time delay [79.t_Reclaim] to ready for the next reclosing. For permanent fault, the device will operate to trip again after the reclosing is performed, and the device will output the signal of reclosing failure [79.Fail_Rcls]. [79.N_Rcls]>1 means multi-shot reclosing. For multi-shot reclosing in 3-pole AR mode, line protection device will operate to trip when a transient fault occurs on the line and 3-pole AR will be initiated. After the dead time delay of the first reclosing is expired, the device will send reclosing pulse, and then the auto-reclosure will drop off after the time delay [79.t_Reclaim] to ready for the next reclosing. For permanent fault, the device will operate to trip again after the reclosing is performed, and then 3-pole AR is initiated after the tripping contact drops off. After the time delay for AR is expired, the device will send reclosing pulse. The sequence is repeated until the reclosing is successful or the maximum permit reclosing number [79.N_Rcls] is reached. 3.
1/3-pole AR
[79.N_Rcls]=1 means one-shot reclosing. For one-shot 1/3-pole AR mode, line protection device will operate to trip when a transient fault occurs on the line and 1-pole AR will be initiated for single-phase fault and 3-pole AR will be initiated for multi-phase fault. After respective dead time delay for AR is expired, the device will send reclosing pulse, and then the auto-reclosure will drop off after the time delay [79.t_Reclaim] to ready for the next reclosing. For permanent fault, the device will operate to trip again after the reclosing is performed, and the device will output the
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signal of reclosing failure [79.Fail_Rcls]. [79.N_Rcls]>1 means multi-shot reclosing. For multi-shot reclosing in 1/3-pole AR mode, line protection device will operate to trip when a transient fault occurs on the line and AR will be initiated. After the dead time delay of the first reclosing is expired, the device will send reclosing pulse, and then the auto-reclosure will drop off after the time delay [79.t_Reclaim] to ready for the next reclosing. For permanent fault, the device will operate to trip again after the reclosing is performed, and then 3-pole AR is initiated after the tripping contact drops off. After the time delay for AR is expired, the device will send reclosing pulse. The sequence is repeated until the reclosing is successful or the maximum permit reclosing number [79.N_Rcls] is reached. For the possible reclosing times of 3-pole AR in 1/3-pole AR mode, please refer to Table 3.24-2. The table below shows the number of reclose attempts with respect to the settings and AR modes. Table 3.24-2 Reclosing number
Setting Value
1-pole AR
3-pole AR
1/3-pole AR
N-1AR
N-3AR
N-1AR
N-3AR
N-1AR
N-3AR
1
1
0
0
1
1
1
2
1
1
0
2
1
2
3
1
2
0
3
1
3
4
1
3
0
4
1
4
N-1AR: the reclosing number of 1-pole AR N-3AR: the reclosing number of 3-pole AR 4.
Coordination between dual auto-reclosures
Duplicated protection configurations are normally applied for UHV lines. If reclosing function is integrated within line protections, the auto-reclosing function can be enabled in any or both of the line protections without coordination. If both sets of reclosing functions are enabled, when one of them first recloses onto a permanent fault, the other will block the reclosing pulse according to the latest condition of the faulty phase. For one-shot AR mode, if the current is detected in the faulty phase, AR will be blocked immediately to prevent the circuit breaker from repetitive reclosing. For multi-shot AR mode, if the current is detected in the faulty phase, the current reclosing pulse will be blocked and go into the next reclosing pulse logic automatically. If the maximum permitted reclosing number [79.N_Rcls] is reached, the auto-reclosure will drop off after the time delay [79.t_Reclaim]. For one-shot or multi-shot AR, there is a corresponding reclosing counter at each stage. After reclosing pulse is sent, the corresponding reclosing counter will plus 1 and the reclosing counter may be cleared by the submenu “Clear Counter”. If the circuit breaker is reclosed by other devices during AR initiation, the auto-reclosure will go into the next reclosing pulse logic. 3.24.5.6 AR Time Sequence Diagram The following two examples indicate typical time sequence of AR process for transient fault and permanent fault respectively. 3-190
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Fault Trip CB 52b
Open [79.t_Reclaim]
79.t_Reclaim 79.Active 79.Inprog
[79.t_Dd_1PS1]
79.Inprog_1P
[79.t_Dd_1PS1]
79.Ok_Chk AR Out
[79.t_PW_AR]
79.Perm_Trp3P 79.Fail_Rcls Time
Figure 3.24-13 Single-phase transient fault
Signal
Fault Trip Open
52b
Open [79.t_Reclaim]
79.t_Reclaim 79.Active 79.Inprog 79.Inprog_1P
[79.t_Dd_1PS1]
79.Inprog_3PS2
[79.t_Dd_3PS2]
79.Ok_Chk AR Out
[79.t_PW_AR]
[79.t_PW_AR]
79.Perm_Trp3P 79.Fail_Rcls
200ms Time
Figure 3.24-14 Single-phase permanent fault ([79.N_Rcls]=2)
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3.24.6 Settings Table 3.24-3 Settings of auto-reclosing No.
Name
Range
Step
Unit
1
Remark
1
79.N_Rcls
1~4
Maximum number of reclosing attempts
2
79.t_Dd_1PS1
0.000~600.000
0.001
s
Dead time of first shot 1-pole reclosing
3
79.t_Dd_3PS1
0.000~600.000
0.001
s
Dead time of first shot 3-pole reclosing
4
79.t_Dd_3PS2
0.000~600.000
0.001
s
5
79.t_Dd_3PS3
0.000~600.000
0.001
s
6
79.t_Dd_3PS4
0.000~600.000
0.001
s
7
79.t_CBClsd
0.000~600.000
0.001
s
Dead time of second shot 3-pole reclosing Dead time of third shot 3-pole reclosing Dead
time
of
fourth shot
3-pole
reclosing Time delay of circuit breaker in closed position before reclosing Time delay to wait for CB healthy, and begin to timing when the input signal
8
79.t_CBReady
0.000~600.000
0.001
s
[79.CB_Healthy] is de-energized and if it is not energized within this time delay, AR will be blocked. Maximum wait time for synchronism
9
79.t_Wait_Chk
0.000~600.000
0.001
s
10
79.t_Fail
0.000~600.000
0.001
s
11
79.t_PW_AR
0.000~600.000
0.001
s
Pulse width of AR closing signal
12
79.t_Reclaim
0.000~600.000
0.001
s
Reclaim time of AR
13
79.t_PersistTrp
0.000~600.000
0.001
s
check Time delay allow for CB status change to conform reclosing successful
Time delay of excessive trip signal to block auto-reclosing Drop-off time delay of blocking AR,
14
79.t_DDO_BlkAR
0.000~600.000
0.001
s
when
blocking
disappears,
signal
AR
blocking
for
AR
condition
drops off after this time delay 15
79.t_AddDly
0.000~600.000
0.001
s
16
79.t_WaitMaster
0.000~600.000
0.001
s
Additional time delay for auto-reclosing Maximum
wait
time
for
reclosing
permissive signal from master AR Time delay of discriminating another fault, and begin to times after 1-pole AR
17
79.t_SecFault
0.000~600.000
0.001
s
initiated, 3-pole AR will be initiated if another fault happens during this time delay. AR will be blocked if another fault happens after that.
18
79.En_PDF_Blk
0 or 1
Enabling/disabling
3-192
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79.En_AddDly
an additional dead time delay
0 or 1
0: disable 1: enable Enabling/disabling adjust the length of
20
79.En_CutPulse
reclosing pulse
0 or 1
0: disable 1: enable Enabling/disabling confirm whether AR
21
79.En_FailCheck
is successful by checking CB state
0 or 1
0: disable 1: enable Enabling/disabling auto-reclosing
22
79.En
0 or 1
0: disable 1: enable Enabling/disabling AR by external input
23
79.En_ExtCtrl
signal besides logic setting [79.En]
0 or 1
0: only logic setting 1: logic setting and external input signal Enabling/disabling AR be initiated by
24
79.En_CBInit
open state of circuit breaker
0 or 1
0: disable 1: enable Option of AR priority None: single-breaker arrangement
25
79.Opt_Priority
None, High or
High: master
Low
arrangement Low:
slave
AR of multi-breaker AR
of
multi-breaker
arrangement Control option of AR mode 1: select AR mode by internal logic 26
79.SetOpt
0 or 1
settings 0: select AR mode by external input signals Enabling/disabling 1-pole AR mode
27
79.En_1PAR
0 or 1
0: disable 1: enable Enabling/disabling 3-pole AR mode
28
79.En_3PAR
0 or 1
0: disable 1: enable 3-193
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79.En_1P/3PAR
0 or 1
0: disable 1: enable
3.25 Transfer Trip 3.25.1 General Application This function module provides a binary input [TT.Init] for receiving transfer trip from the remote end. This feature ensures simultaneous tripping at both ends.
3.25.2 Function Description Transfer trip can be controlled by local fault detector by logic settings [TT.En_FD_Ctrl]. In addition, the binary input [TT.Init] is always supervised, and the device will issue an alarm [TT.Alm] and block transfer trip once the binary input is energized for longer than 4s and drop off after resumed to normal with a time delay of 10s.
3.25.3 Function Block Diagram TT TT.Init
TT.Alm
TT.En
TT.Op
TT.Blk
TT.On
3.25.4 I/O Signals Table 3.25-1 I/O signals of transfer trip No.
Input Signal
1
TT.Init
2
TT.En
3
TT.Blk
No.
Description Input signal of initiating transfer trip after receiving transfer trip Transfer trip enabling input, it is triggered from binary input or programmable logic etc. Transfer trip blocking input, it is triggered from binary input or programmable logic etc.
Output Signal
Description
1
TT.Alm
Input signal of receiving transfer trip is abnormal
2
TT.Op
Transfer trip operates
3
TT.On
Transfer trip is enabled
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3.25.5 Logic SIG
TT.En
& TT.On
SIG
TT.Blk 4s
BI
[TT.Init]
SIG
TT.Alm
EN
[TT.En_FD_Ctrl]
SIG
FD.Pkp
BI
[TT.Init]
10s
TT.Alm
& TT.Op
>=1
Figure 3.25-1 Logic diagram of transfer trip
3.25.6 Settings Table 3.25-2 Settings of Transfer trip No. 1
2
Name TT.t_Op
TT.En_FD_Ctrl
Range
Step
Unit
0.000~600.000
0.001
s
Remark Time delay of transfer trip Transfer trip controlled by local fault detector element 0: not controlled by local fault detector element 1: controlled by local fault detector element
0 or 1
3.26 Trip Logic 3.26.1 General Application For any enabled protection tripping elements, their operation signal will convert to appropriate tripping signals through trip logics and then trigger output contacts by configuration.
3.26.2 Function Description This module gathers signals from phase selection and protection tripping elements and then converts the operation signal from protection tripping elements to appropriate tripping signals. The device can implement phase-segregated tripping or three-phase tripping, and may output the contact of blocking AR and the contact of initiating breaker failure protection.
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3.26.3 Function Block Diagram PTRC En
TrpA
Blk
TrpB
Faulty phase selection
TrpC
PrepTrp3P
Trp
Line tripping element
Trp3P
Breaker tripping element
BFI_A
Initiating BFP element
BFI_B BFI_C BFI Trp3P_PSFail BlkAR On
3.26.4 I/O Signals Table 3.26-1 I/O signals of trip logic No.
Input Signal
Description Trip enabling input, it is triggered from binary input or programmable
1
En logic etc. Trip blocking input, it is triggered from binary input or programmable
2
Blk logic etc.
3
Faulty phase selection (phase
The result of fault phase selection
A, phase B, phase C)
If multi-phase is selected, three-phase breakers will be tripped. Input signal of permitting three-phase tripping
4
PrepTrp3P
When this signal is valid, three-phase tripping will be adopted for any kind of faults.
5
Line tripping element
6
Breaker tripping element
7
Initiating BFP element
No.
All operation signals of various line protection tripping elements, such as distance protection, overcurrent protection, etc. All protection tripping elements concerned with breaker, such as pole discrepancy protection, etc. Tripping element to initiate BFP
Output Signal
Description
1
On
Tripping logic is enabled.
2
TrpA
Tripping A-phase circuit breaker
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TrpB
Tripping B-phase circuit breaker
4
TrpC
Tripping C-phase circuit breaker
5
Trp
Tripping any phase circuit breaker
6
Trp3P
Tripping three-phase circuit breaker
7
BFI_A
8
BFI_B
9
BFI_ C
10
BFI
11
Trp3P_PSFail
Initiating three-phase tripping due to failure in fault phase selection
12
BlkAR
Blocking auto-reclosing
Protection tripping signal of A-phase configured to initiate BFP, BFI signal shall be reset immediately after tripping signal drops off. Protection tripping signal of B-phase configured to initiate BFP, BFI signal shall be reset immediately after tripping signal drops off. Protection tripping signal of C-phase configured to initiate BFP, BFI signal shall be reset immediately after tripping signal drops off. Protection tripping signal configured to initiate BFP, BFI signal shall be reset immediately after tripping signal drops off.
3.26.5 Logic After tripping signal is issued, the tripping pulse will be kept as same as the setting [t_Dwell_Trp] at least. When the time delay is expired, for phase-segregated tripping, the tripping signal will drop off immediately if the faulty current of corresponding phase is less than 0.06In (In is secondary rated current), otherwise the tripping signal will be always kept until the faulty current of corresponding phase is less than 0.06In. For three-phase tripping, the tripping signal will drop off immediately if three-phase currents are all less than 0.06In, otherwise the tripping signal will be always kept until three-phase currents are all less than 0.06In.
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SIG
FPS (phase A)
&
SIG
FPS (phase B)
&
SIG
FPS (phase C)
&
SIG
Line tripping element
SIG
En
SIG
Blk
SIG
Breaker tripping element
SIG
PrepTrp3P
&
>=1
&
>=1
&
>=1
& &
>=1
>=1 &
EN
SIG
[En_Trp3P]
Trp
SIG
Line tripping element
SIG
FPS (phase A)
&
SIG
FPS (phase B)
&
SIG
FPS (phase C)
&
&
>=1
>=1
>=1 & 200ms SIG
0ms
Trp3P_PSFail
Line tripping element
& SIG
SIG
SIG
SIG
SIG
SIG
TrpA
[t_Dwell_Trp]
0
&
[t_Dwell_Trp]
0
&
[t_Dwell_Trp]
0
&
TrpA
Ia<0.06In TrpB
& TrpB
Ib<0.06In TrpC
& TrpC
Ib<0.06In
SIG
TrpA
SIG
TrpB
SIG
TrpC
>=1 Trp
3-198
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TrpA
SIG
TrpB
SIG
TrpC
& Trp3P
Figure 3.26-1 Tripping logic
>=1
& BFI
SIG
Initiating BFP element
& BFI_A
SIG
TrpA
& BFI_B SIG
TrpB
& BFI_C SIG
TrpC
Figure 3.26-2 Breaker failure initiation logic
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Y.ZPx.Op
EN
[Y.ZPx.En_BlkAR]
SIG
Y.ZGx.Op
EN
[Y.ZGx.En_BlkAR]
SIG
50/51Px.Op
EN
[50/51Px.En_BlkAR]
SIG
50/51Gx.Op
EN
50/51Gx.En_BlkAR
SIG
50PVT.Op
SIG
50GVT.Op
SIG
59Pz.Op
SIG
27Pz.Op
SIG
81U.UFx.Op
SIG
81O.OFx.Op
SIG
50BF.Op_t1
SIG
50BF.Op_t2
SIG
49-1.Op
SIG
49-2.Op
SIG
50STB.Op
SIG
62PD.Op
SIG
46BC.Op
SIG
TT.Op
EN
En_MPF_Blk_AR
SIG
Multi-phase fault
EN
En_3PF_Blk_AR
SIG
Three-phase fault
EN
En_PhSF_Blk_AR
SIG
Phase selection failure
SIG
21SOTF.Op
SIG
50GSOTF.Op
SIG
Manual closing signal
SIG
50DZ.Op
SIG
32Rz.Op
& >=1 >=1 &
& >=1 &
>=1
>=1
>=1 >=1
>=1 BlkAR
>=1
>=1
>=1
>=1
>=1
&
&
>=1
&
>=1 &
>=1
>=1
Figure 3.26-3 Blocking AR logic 3-200
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Where: Y can be 21M or 21Q x can be 1, 2, 3 or 4 z can be 1 or 2
3.26.6 Settings Table 3.26-2 Settings of trip logic No.
Name
Range
Step
Unit
Remark Enabling/disabling
1
En_MPF_Blk_AR
auto-reclosing
blocked
when multi-phase fault happens
0 or 1
0: disable 1: enable Enabling/disabling
2
En_3PF_Blk_AR
auto-reclosing
blocked
when three-phase fault happens
0 or 1
0: disable 1: enable Enabling/disabling 3
En_PhSF_Blk_AR
auto-reclosing
blocked
when faulty phase selection fails
0 or 1
0: disable 1: enable Enabling/disabling three-phase tripping mode 4
En_Trp3P
for any fault conditions
0 or 1
0: disable 1: enable The dwell time of tripping command, empirical value is 0.04
5
t_Dwell_Trp
0.000~10.000
0.001
s
The tripping contact shall drop off under conditions of no current or protection tripping element drop-off.
3.27 VT Circuit Supervision 3.27.1 General Application The purpose of VT circuit supervision is to detect whether VT circuit is normal. Because some protection functions, such as distance protection, under-voltage protection and so on, will be influenced by VT circuit failure, these protection functions should be disabled when VT circuit fails. VT circuit failure can be caused by many reasons, such as fuse blown due to short-circuit fault, poor contact of VT circuit, VT maintenance and so on. The device can detect them and issue an alarm signal to block relevant protection functions. However, the alarm of VT circuit failure should not be issued when the following cases happen. 1.
Line VT is used as protection VT and the protected line is out of service. 3-201
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2.
Only current protection functions are enabled and VT is not connected to the device.
3.27.2 Function Description VT circuit supervision can detect failure of single-phase, two-phase and three-phase on protection VT. Under normal condition, the device continuously supervises input voltage from VT, VT circuit failure signal will be activated if residual voltage exceeds the threshold value or positive-sequence voltage is lower than the threshold value. If the device is under pickup state due to system fault or other abnormality, VT circuit supervision will be disabled. Under normal conditions, the device detect residual voltage greater than 8% of Unn to determine single-phase or two-phase VT circuit failure, and detect three times positive-sequence voltage less than Unn to determine three-phase VT circuit failure. Upon detecting abnormality on VT circuit, an alarm will comes up with the time delay [VTS.t_DPU] and drop off with the time delay [VTS.t_DDO] after VT circuit restored to normal. VT (secondary circuit) MCB auxiliary contact as a binary input can be connected to the binary input circuit of the device. If MCB is open (i.e. [VTS.MCB_VT] is energized), the device will consider the VT circuit is not in a good condition and issues an alarm without a time delay. When VT is not connected into the device, the alarm will be not issued if the logic setting [VTS.En_Out_VT] is set as “1”. However, the alarm is still issued if the binary input [VTS.MCB_VT] is energized, no matter that the logic setting [VTS.En_Out_VT] is set as “1” or “0”. When VT neutral point fails, third harmonic of residual voltage is comparatively large. If third harmonic amplitude of residual voltage is larger than 0.2Unn and without operation of fault detector element, VT neutral point failure alarm signal [VTNS.Alm] will be issued with the time delay [VTS.t_DPU] and drop off with the time delay [VTS.t_DDO] after three phases voltage restored to normal.
3.27.3 Function Block Diagram VTS
VTS.En
VTNS VTS.Alm
VTS.Blk
VTNS.En
VTNS.Alm
VTNS.Blk
VTS.MCB_VT
3.27.4 I/O Signals Table 3.27-1 I/O signals of VT circuit supervision No.
Input Signal
1
VTS.En
2
VTS.Blk
Description VT supervision enabling input, it is triggered from binary input or programmable logic etc. VT supervision blocking input, it is triggered from binary input or programmable
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3
VTNS.En
4
VTNS.Blk
5
VTS.MCB_VT
No.
programmable logic etc. VT neutral point supervision blocking input, it is triggered from binary input or programmable logic etc. Binary input for VT MCB auxiliary contact
Output Signal
Description
1
VTS.Alm
Alarm signal to indicate VT circuit fails
2
VTNS.Alm
Alarm signal to indicate VT neutral point fails
3.27.5 Logic
& SIG
FD.Pkp
SIG
79.Inprog
SIG
3U0>0.08Unn
SIG
3U1
EN
[VTS.En_LineVT]
SIG
52b_3P
EN
[VTS.En_Out_VT]
>=1
>=1 & >=1
BI
1: open 0: closed
&
[VTS.t_DPU] [VTS.t_DDO]
& >=1
>=1 &
VTS.Alm
[VTS.MCB_VT]
EN
[VTS.En]
SIG
[VTS.En]
SIG
[VTS.Blk]
&
Figure 3.27-1 Logic of VT circuit supervision
& SIG
FD.Pkp
SIG
79.Inprog
SIG
U03>0.2Unn
>=1
&
1: open 0: closed
>=1
[VTS.t_DPU] EN
[VTS.En_Out_VT]
EN
[VTS.En]
SIG
[VTNS.En]
SIG
[VTNS.Blk]
[VTS.t_DDO]
&
VTNS.Alm
&
Figure 3.27-2 Logic of VT neutral point supervision
Unn: rated phase-to-phase voltage U03: third harmonic amplitude of neutral point residual voltage 3-203
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If there is already a VTS alarm before FD operated, VTS will continue to block distance protection, that is VTS will be latched when FD operates.
3.27.6 Settings Table 3.27-2 VTS Settings No.
Name
Range
Step
Unit
Remark
1
VTS.t_DPU
0.200~100.000
0.001
s
Pickup time delay of VT circuit supervision
2
VTS.t_DDO
0.200~100.000
0.001
s
Dropoff time delay of VT circuit supervision No voltage used for protection calculation 1: enable
3
VTS.En_Out_VT
0: disable
0 or 1
In general, when VT is not connected to the device, this logic setting should be set as “1” Voltage selection for protection calculation
4
VTS.En_LineVT
from busbar VT or line VT
0 or 1
1: line VT 0: busbar VT Alarm function of VT circuit supervision
5
VTS.En
0 or 1
1: enable 0: disable
3.28 CT Circuit Supervision 3.28.1 General Application The purpose of the CT circuit supervision is to detect any abnormality on CT secondary circuit.
3.28.2 Function Description Under normal conditions, CT secondary signal is continuously supervised by detecting the residual current and voltage. If residual current is larger than 10%In whereas residual voltage is less than 3V, an error in CT circuit is considered, the concerned protection functions are blocked and an alarm is issued with a time delay of 10s and drop off with a time delay of 10s after CT circuit is restored to normal condition.
3.28.3 Function Block Diagram CTS CTS.En
CTS.Alm
CTS.Blk
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3.28.4 I/O Signals Table 3.28-1 I/O signals of CT circuit supervision No.
Input Signal
1
CTS.En
2
CTS.Blk
No. 1
Description CT circuit supervision enabling input, it is triggered from binary input or programmable logic etc. CT circuit supervision blocking input, it is triggered from binary input or programmable logic etc.
Output Signal CTS.Alm
Description Alarm signal to indicate CT circuit fails
3.28.5 Logic SIG
CTS.En
SIG
CTS.Blk
SIG
3I0>0.1In
SIG
3U0<3V
SIG
IA<0.06In
SIG
IB<0.06In
SIG
IC<0.06In
& & 10s
10s
CTS.Alm
&
>=1
Figure 3.28-1 Logic diagram of CT circuit failure
3.29 Control and Synchrocheck for Manual Closing 3.29.1 General Application The purpose of control is to open or close primary equipment, including circuit breaker (CB), disconnector (DS) and earth switch (ES), or to issue outputs for signaling purpose. Synchronism check and dead check are also provided for the control processes as below: 1. Local manual closing CB 2. Local closing CB by access the menu “Local Cmd→Control” 3. Remote closing CB from SCADA (i.e., local HMI system) or control center (CC) Programmable interlocking logics within a bay and amongst different bays are provided by using PCS-Explorer.
3.29.2 Function Description 1. Control High reliability is ensured by adopting the principle of selection before operation (abbreviated SBO). When the binary input [BI_Maintenance] is energized as “1”, remote control from
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SCADA/CC will be disabled, but local control will not be influenced. The integrated control process is as follow: 1) The control source (SCADA/CC, or local LCD control operation, or manual control operation) sends control selection command to this device 2) This device sends back the control selection result (success or failure) to the control source after logic judgment 3) The control source sends control operation command to this device if the control selection result is “success”. The control source will send control cancellation command to this device if the control selection result is “failure”. 4) This device sends back the control operation result (success or failure) to the control source after logic judgment. Logic calculation result of interlocking is input to the remote control module as a criterion of remote operation. When the enabling parameter of remote open/close interlock is “1”, remote control module determines whether it can be output according to the calculation result of interlocking. If the current breaker position or programmable part can meet the interlocking condition, remote control can be output normally, otherwise remote operation is blocked. When the enabling parameter of remote open/close interlock is “0”, interlocking function is disabled and remote control will be output directly without the judgment of interlocking. Holding time of each binary output contact can be set by configuring corresponding settings and is often configured as 250ms. However, for the control circuits without latched relays, the holding time must be longer to ensure successful control operation.
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CSWI01.CILO.Disable
SIG
BIinput.CILO.Disable
EN
[CSWI01.En_Cls_Blk]
SIG
CSWI01.CILO.EnCls
SIG
CSWI01.RmtCtrl
SIG
BIinput.RmtCtrl
SIG
CSWI01.Cmd_RmtCtrl
SIG
CSWI01.LocCtrl
SIG
BIinput.LocCtrl
SIG
CSWI01.ManSynCls
SIG
CSWI01.Cmd_LocCtrl
SET
MCBrd.25.En_SynChk
SIG
Sig_Ok_Chk
SET
MCBrd.25.En_LvL_DdB
SET
MCBrd.25.En_DdL_LvB
SET
MCBrd.25.En_DdL_DdB
SIG
Sig_Ok_Chk
SET
MCBrd.25.En_NoChk
SIG
CSWIxx.CILO.Disable
SIG
BIinput.CILO.Disable
EN
[CSWIxx.En_Cls_Blk]
SIG
CSWIxx.CILO.EnCls
SIG
CSWIxx.RmtCtrl
SIG
BIinput.RmtCtrl
SIG
CSWIxx.Cmd_RmtCtrl
SIG
CSWIxx.LocCtrl
SIG
BIinput.LocCtrl
SIG
CSWIxx.Cmd_LocCtrl
>=1
>=1
>=1
& &
>=1
[CSWI01.t_PW_Cls]
0ms
[CSWI01.Op_Cls]
>=1
& >=1
>=1 >=1
>=1 >=1
>=1
>=1
& [CSWIxx.t_PW_Cls]
0ms
[CSWIxx.Op_Cls]
>=1
& >=1
>=1
&
Figure 3.29-1 Logic diagram of closing primary equipment
Where: xx=02~10 Only the first closing command “CSWI01.Op_Cls” controlled by synchrocheck logic can be used 3-207
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for CB closing. After receiving a closing command, this device will continuously check whether the 2 voltages (Incoming voltage and reference voltage) involved in synchronism check (or dead check) can meet the criteria. Within the duration of [MCBrd.25.t_Wait_Chk], if the synchronism check (or dead check) criteria are not met, the signal “Sig_Ok_Chk” will be set as “0”; if the synchronism check (or dead check) criteria are met, the signal “Sig_Ok_Chk” will be set as “1”. Access the menu “Local Cmd→Control” to issue control command locally, and this signal “CSWIxx.Cmd_LocCtrl” will be set as “1”. Remote control commands from SCADA/CC can be transmitted via IEC 60870-5-103 protocol or IEC 61850 protocol, and this signal “CSWIxx.Cmd_RmtCtrl” will be set as “1”. SIG
CSWI01.CILO.Disable
SIG
BIinput.CILO.Disable
EN
[CSWI01.En_Opn_Blk]
SIG
CSWI01.CILO.EnOpn
SIG
CSWI01.RmtCtrl
SIG
BIinput.RmtCtrl
SIG
CSWI01.Cmd_RmtCtrl
SIG
CSWI01.LocCtrl
SIG
BIinput.LocCtrl
SIG
CSWI01.ManOpn
SIG
CSWI01.Cmd_LocCtrl
SIG
CSWIxx.CILO.Disable
SIG
BIinput.CILO.Disable
EN
[CSWIxx.En_Opn_Blk]
SIG
CSWIxx.CILO.EnOpn
SIG
CSWIxx.RmtCtrl
SIG
BIinput.RmtCtrl
SIG
CSWIxx.Cmd_RmtCtrl
SIG
CSWIxx.LocCtrl
SIG
BIinput.LocCtrl
SIG
CSWIxx.Cmd_LocCtrl
>=1
>=1
& [CSWI01.t_PW_Opn]
0ms
[CSWI01.Op_Opn]
[CSWIxx.t_PW_Opn]
0ms
[CSWIxx.Op_Opn]
>=1
& >=1
>=1
& >=1
>=1
>=1
&
>=1
& >=1
>=1
&
Figure 3.29-2 Logic diagram of open primary equipment
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Where: xx=01~10 The control output fulfills signal output circuit, and opens or closes circuit breaker, disconnector and earth switch according to the control command. Object manipulation strictly performs three steps: selection, check and excute, and perform output relay check, to ensure that the remote control can be excuted safely and reliably. When logic interlock is enabled, the device can receive the programmable interlock logic. The device can automatically initiate the interlock logic to determine whether to allow control operations. The device provides corresponding settings ([CSWIxx.En_Opn_Blk] and [CSWIxx.En_Cls_Blk]) for each control object. When they are set as “1”, the interlock function of the corresponding control object is enabled. The interlock logic can be configured by using PCS-Explorer, and downloaded to the device via the Ethernet port. If the interlock function is enabled, but it is not configured the interlock logic, the result of the logic output is 0. The control record is a file which is used to store remote control command records of this device circularly. If the record number is to 256, the storage area of the control record will be full. If this device has received a new remote command, this device will delete the oldest remote control record, and then store the latest remote control record. There are 10 configuration page corresponding to 10 control outputs in totall respectively. Each configuration page can finish some signals configuration, including remote control, local control, disable interlock blocking, and so on. In order to conveniently configure control output, the same output signals, including “BIinput.RmtCtrl”, “BIinput.LocCtrl” and “BIinput.CILO.Disable”, are available after processing binary signals internally, as shown in figure below.
Figure 3.29-3 Configuration page of control output 01 (default configration)
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Figure 3.29-4 Configuration page of control output 02 (default configration)
Control output 03~10 is as same as control output 02. The configuration rule about remote control and local control to binary outputs is as bellow: Remot
Local
CSWIxx.
BIinput.
CSWIxx.
BIinput.
RmtCtrl
RmtCtrl
LocCtrl
LocCtrl
X
X
X
X
0
X
X
X
X
0
X
X
1
X
X
X
X
1
X
X
X
X
0
X
X
X
X
0
X
X
1
X
X
X
X
1
0
X
0
X
0
X
X
0
X
0
0
X
X
0
X
0
0
X
1
X
X
0
1
X
0
X
X
1
X
0
X
1
1
X
0
X
1
X
X
0
X
1
0
X
X
1
X
0
1
X
1
X
Control Mode
Neither Local control nor remote control are permissible. Only local control is permissible.
Only remote control is permissible.
Only remote control is permissible.
Only local control is permissible.
Neither Local control nor remote control are permissible.
Only local control is permissible.
Only remote control is permissible.
Both Local control and remote control are permissible.
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X
X
1
X
1
1
X
X
1
X
1
For remote control or local control, they can be configured by either of “CSWIxx.RmtCtrl” and “BIinput.RmtCtrl”, or either of “CSWIxx.LocCtrl” and “BIinput.LocCtrl”. X means that it is not configured. 2. Synchrocheck Three synchrocheck modes are designed for CB closing: no check mode, dead check mode and synchronism check mode, if any one of the condition of three synchrocheck modes satisfied, then synchrocheck signal “Sig_Ok_Chk” will be asserted. The synchronism check function measures the conditions across the circuit breaker and compares them with the corresponding settings. The output is only given if all measured quantities are simultaneously within their set limits. Compared to the synchronism check for auto-reclosing, an additional criterion is applied to check the rate of frequency change (df/dt) between both sides of the CB. When the following four conditions are all met, the synchronism check is successful. 1) Phase angle difference between incoming voltage and reference voltage is less than the setting [MCBrd.25.phi_Diff] 2) Frequency difference between incoming voltage and reference voltage is less than [MCBrd.25.f_Diff] 3) Voltage difference between between incoming voltage and reference voltage is less than [MCBrd.25.U_Diff] 4) Rate of frequency change between incoming voltage and reference voltage is less than [MCBrd.25.df/dt] The dead check function measures the amplitude of line voltage and bus voltage at both sides of the circuit breaker, and then compare them with the live check setting [MCBrd.25.U_Lv] and the dead check setting [MCBrd.25.U_Dd]. The dead check is successful when the measured quantities comply with the criteria. When this device is set to work in no check mode and receives a closing command, CB will be closed without synchronism check and dead check.
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3.29.3 Function Block Diagram CSWI01 CILO.EnOpn
Op_Opn
CILO.EnCls
Op_Cls
RmtCtrl LocCtrl CILO.Disable ManSynCls ManOpn
CSWIxx CILO.EnOpn
Op_Opn
CILO.EnCls
Op_Cls
RmtCtrl LocCtrl CILO.Disable
BIinput RmtCtrl
RmtCtrl
LocCtrl
LocCtrl
CILO.Disable
CILO.Disable
xx can be from 02 to 10
3.29.4 I/O Signals Table 3.29-1 I/O signals of control No.
Input Signal
Description From receiving a closing command, this device will continuously check
1
Sig_Ok_Chk
whether the 2 voltages (Incoming voltage and reference voltage) involved in synchronism check(or dead check) can meet the criteria. Within the duration of [MCBrd.25.t_Wait_Chk], if the synchronism
3-212
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CSWIxx.CILO.EnOpn
It is the interlock status of No.xx open output of BO module (xx=01~10)
3
CSWIxx.CILO.EnCls
It is the interlock status of No.xx closing output of BO module (xx=01~10) It is used to select the local control to No.xx controlled object (CB/DS/ES).
4
CSWIxx.LocCtrl
When the local control is active, No.xx binary outputs can only be locally controlled. (xx=01~10) It is used to select the remote control to No.xx controlled object
5
(CB/DS/ES). When the remote control is active, No.xx binary outputs can
CSWIxx.RmtCtrl
only be remotely controlled by SCADA or control centers. (xx=01~10) It is used to disable the interlock blocking function for control output. If the 6
signal “CSWIxx.CILO.Disable” is “1”, No.xx binary outputs of the device
CSWIxx.CILO.Disable
will not be blocked by interlock conditions. (xx=01~10) It is used to select the remote control to controlled object (CB/DS/ES). 7
When the remote control is active, all binary outputs can only be remotely
BIinput.RmtCtrl
controlled by SCADA or control centers. 8
It is used to select the local control to controlled object (CB/DS/ES). When
BIinput.LocCtrl
the local control is active, all binary outputs can only be locally controlled. It is used to disable the interlock blocking function for control output. If the
9
signal “BIinput.CILO.Disable” is “1”, all binary outputs of this device will
BIinput.CILO.Disable
not be blocked by interlock conditions. When 10
the
condition
of
local
control
is
met
and
the
signal
“CSWI01.ManSynCls” is “1”, the output contact [BO_CtrlCls01] is closed
CSWI01.ManSynCls
to execute manually closing the circuit breaker with synschrochcek. When 11
the
condition
of
local
control
is
met
and
the
signal
“CSWI01.ManOpn” is “1”, the output contact [BO_CtrlOpn01] is closed to
CSWI01.ManOpn
execute manually open the circuit breaker. No.
Output Signal
Description
1
CSWIxx.Op_Opn
No.xx command output for open. (xx=01~10)
2
CSWIxx.Op_Cls
No.xx command output for closing. (xx=01~10)
3
BIinput.RmtCtrl
In order to be convenient to user configure control output, three same
4
BIinput.LocCtrl
output signals with input signals are available. The relationship with 10 binary output have been configured inside the device. The user only assigns a specific binary input to input signal, the relevant function can be
5
gained. If some binary output need not be controlled by three signals,
BIinput.CILO.Disable
please cancle the configuration by PCS-Explorer, and configure it independently.
3.29.5 Settings Table 3.29-2 Control Settings No. 1
Name CSWIxx.t_PW_Opn
Range 0~65535
Step 1
Unit
Remark
ms
No.xx holding time of a normal open contact 3-213
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CSWIxx.t_PW_Cls
0~65535
1
ms
of remote closing CB, disconnector or for signaling purpose. (xx=01, 02….10) These settings are applied to configure the
3
CSWIxx.t_DPU_DPS
0~60000
1
ms
debouncing time. “DPU” is the abbreviation of “Delay Pick Up”. (xx=01, 02….10) Enabling/disabling No.xx open output of the BO module be controlled by the interlocking
4
CSWIxx.En_Opn_Blk
logic
0 or 1
0: disable 1: enable (xx=01, 02….10) Enabling/disabling No.xx closing output of the BO module be controlled by the interlocking 5
CSWIxx.En_Cls_Blk
logic
0 or 1
0: disable 1: enable (xx=01, 02….10) Table 3.29-3 Synchrocheck Settings No.
Name
Range
Step
Unit
Remark Voltage selecting mode of line 0: A-phase voltage 1: B-phase voltage
1
MCBrd.25.Opt_Source_UL
0~5
1
2: C-phase voltage 3: AB-phase voltage 4: BC-phase voltage 5: CA-phase voltage Voltage selecting mode of bus 0: A-phase voltage 1: B-phase voltage
2
MCBrd.25.Opt_Source_UB
0~5
1
2: C-phase voltage 3: AB-phase voltage 4: BC-phase voltage 5: CA-phase voltage
3
MCBrd.25.U_Dd
0.05Un~0.8Un
0.001
V
Voltage threshold of dead check
4
MCBrd.25.U_Lv
0.5Un~Un
0.001
V
Voltage threshold of live check
5
MCBrd.25.K_Usyn
0.20-5.00
6
MCBrd.25.phi_Diff
0~ 89
Compensation
coefficient
for
synchronism voltage 1
3-214
Deg
Phase
difference
limit
of
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check
for
manual
closing 7
MCBrd.25.phi_Comp
0~359
Compensation for phase difference
1
between two synchronous voltages Frequency
8
MCBrd.25.f_Diff
0.02~1.00
0.01
Hz
difference
synchronism
check
limit
for
of
manual
closing Voltage 9
MCBrd.25.U_Diff
0.02Un~0.8Un
0.01
V
difference
synchronism
check
limit for
of
manual
closing 10
MCBrd.25.En_SynChk
0 or 1
11
MCBrd.25.En_DdL_DdB
0 or 1
12
MCBrd.25.En_DdL_LvB
0 or 1
13
MCBrd.25.En_LvL_DdB
0 or 1
14
MCBrd.25.En_NoChk
0 or 1
15
MCBrd.25.df/dt
0.00~3.00
Enable synchronism check Enable dead line and dead bus (DLDB) check Enable dead line and live bus (DLLB) check Enable live line and dead bus (LLDB) check Enable manual closing without any check Threshold of rate of frequency 0.01
Hz/s
change between both sides of CB for synchronism-check. Circuit breaker closing time. It is the
16
MCBrd.25.t_Close_CB
20~1000
1
ms
time
from
receiving
closing
command pulse till the CB is completely closed. From receiving a closing command, this device will continuously check whether between incoming voltage and reference voltage involved in synchronism check (or dead check)
17
MCBrd.25.t_Wait_Chk
5~30
0.001
s
can
meet
the
criteria.
If
the
synchronism check (or dead check) criteria are not met within the duration of this time delay, the failure of
synchronism-check
(or
dead
check) will be confirmed.
3.30 Faulty Phase Selection 3.30.1 General Application Fault phase selection logic can be implemented by the following methods: 1.
Detecting the variation of operating voltage 3-215
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2.
Detecting the phase difference between I0 and I2A
The logic makes the device ideal for single-phase tripping applications.
3.30.2 Function Description 3.30.2.1 Variation of Operating Voltage (Faulty Phase Selection Element 1) 1.
Variation of phase operating voltage
1)
Phase A: ΔUOPA
2)
Phase B: ΔUOPB
3)
Phase C: ΔUOPC
2.
Variation of phase-to-phase operating voltage
1)
Phase AB: ΔUOPAB
2)
Phase BC: ΔUOPBC
3)
Phase CA: ΔUOPCA
ΔUOΦMAX=Max(ΔUOPA, ΔUOPB, ΔUOPC) ΔUOΦΦMAX=Max(ΔUOPAB, ΔUOPBC, ΔUOPCA) If ΔUOΦMAX is several times higher than the variation of operating voltages of other two phases, the single-phase fault is ensured, otherwise, the multi-phase fault is ensured. Table 3.30-1 Relation between ΔUOΦMAX and faulty phase ΔUOΦMAX or ΔUOΦΦMAX
Fault phase
ΔUOPA
Phase A
ΔUOPB
Phase B
ΔUOPC
Phase C
ΔUOPAB
Phase AB
ΔUOPBC
Phase BC
ΔUOPCA
Phase CA
3.30.2.2 I0 and I2A (Faulty Phase Selection Element 2) The phase selection algorithm uses the angle relation between I 0 and I2A of the device. As shown in Figure 3.30-1, there are three faulty phase selection regions.
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Region A 60°
-60°
Region B
Region C
180°
Figure 3.30-1 The region of faulty phase selection
Depended on the phase relation between I0 and I2A, the faulty phase can be determined. 1.
-60º
2.
60º
3.
180º
For single-phase earth fault, I0 and I2 of faulty phase are in-phase and its distance element operates. For phase to phase to earth fault, I0 and I2 of non-faulty phase are in-phase but its distance element does not operate.
3.30.3 Function Block Diagram PhSel PhSA PhSB PhSC GndFlt
3.30.4 I/O Signals Table 3.30-2 I/O signals of faulty phase selection No.
Output Signal
Description
1
PhSA
Phase-A is selected as faulty phase
2
PhSB
Phase-B is selected as faulty phase
3-217
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 3
PhSC
Phase-C is selected as faulty phase
4
GndFlt
Earth fault
3.31 Fault Location 3.31.1 Application The main objective of line protection is fast, selective and reliable operation for faults on a protected line section. Besides this, information on distance to fault is very important for those involved in operation and maintenance. Reliable information on the fault location greatly decreases the outage of the protected lines and increases the total availability of a power system. This fault location function cannot be used for the transmission line with series compensation.
3.31.2 Function Description 3.31.2.1 Fundamental Principle The fault location is an essential function to various line protection devices, after selecting faulty phase, it measures and indicates the distance to the fault with high accuracy. Thus, the fault can be quickly located for repairs. The calculation algorithm considers the effect of load currents, double-end infeed and additional fault resistance. Both double-end fault location and single-end fault location are available in line differential relay, but only single-end fault location is provided in other relays. The calculation equation is:
[km] Where: Dist: The distance of fault location according to the Zcalc (km) Zcalc: The impedance value calculated from the location of protection device to fault point Zl: The impedance value of the whole line + mutual impedance Length: The input length of transmission line (km) 3.31.2.2 Mutual Compensation When an earth fault occurred on a line of parallel lines arrangement, a distance relay at one end of the faulty line will tend to underreach whilst the distance relay at the other end will tend to overreach. Usually the degree of underreach or overreach is acceptable, however, for cases where precise fault location is required for long lines with high mutual coupling, mutual compensation is then required to improve the distance measurement. Practically, the mutual effect between the parallel lines is insignificant to positive and negative sequence and thus the mutual compensation is only for zero sequence
3-218
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory A
Ia
B
ZM k C
Ic
ZS
D (1-k)ZL
kZL
ZL
The principle in the application of mutual compensation is shown as follows with the aid of following sequence network diagram figure. The diagram indicates a parallel lines arrangement with an earth fault at location k on line CD. The equivalent sequence network for an earth fault on a parallel lines arrangement with single source is shown as below. Ia1
ZL1
ZS1 kZL1
(1-k)ZL1
Ic1 Ia2
ZL2
ZS2 kZL2
(1-k)ZL2
Ic2 Ia0
ZL0
ZS0 Z0M kZL0
(1-k)ZL0
Ic0
Figure 3.31-1 Equivalent sequence network
The device at location C without mutual compensation will have voltage U RC and current IRC measured as shown in the expression URC is the voltage of the device at location C.
If the line is fully transposed, ZL1=ZL2, Then
3-219
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory
The impedance presented to the device is:
For an earth fault,
,
With the mutual compensation enabled,
(Actual distance of the fault) The residual current from the parallel line should be added to the device. It should be connected to terminal 08 and star point of the parallel line CT connected to terminal 07 as shown in the following figure. Please note the connection diagram and the terminal numbers are for reference only. The final connection terminals are subject to the device configuration at site.
3-220
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory A B C
P2
S2
P2
S2
P1
S1
P1
S1
02
01
02
01
04
03
04
03
06
05
06
05
08
07
08
07
3.31.3 Function Block Diagram FL Fault_Location
FPS_Fault
Fault_Phase
FD.Pkp
Fault_Phase_Curr Fault_Resid_Curr
3.31.4 I/O Signals Table 3.31-1 I/O signals of fault location No.
Input Signal
Description
1
FPS_Fault
Faulty phase selection
2
FD.Pkp
The device picks up
No. 1
Output Signal Fault_Location
Description The result of fault location 3-221
PCS-931 Line Differential Relay Date: 2014-03-05
3 Operation Theory 2
Faulty_Phase
The selected faulty phase
3
Fault_Phase_Curr
Maximum faulty current
4
Fault_Resid_Curr
Maximum residual current
3-222
PCS-931 Line Differential Relay Date: 2014-03-05
4 Supervision
4 Supervision Table of Contents 4 Supervision ...................................................................................... 4-a 4.1 Overview .......................................................................................................... 4-1 4.2 Supervision Alarms ......................................................................................... 4-1 4.3 Relay Self-supervision.................................................................................... 4-7 4.3.1 Relay Hardware Monitoring................................................................................................ 4-7 4.3.2 Fault Detector Monitoring ................................................................................................... 4-7 4.3.3 Check Setting..................................................................................................................... 4-7
4.4 AC Input Monitoring ........................................................................................ 4-8 4.4.1 Voltage/current Drift Monitoring and Auto-adjustment ........................................................ 4-8 4.4.2 Sampling Monitoring .......................................................................................................... 4-8
4.5 Secondary Circuit Monitoring ........................................................................ 4-8 4.5.1 Opto-coupler Power Supervision ....................................................................................... 4-8 4.5.2 Circuit Breaker Supervision................................................................................................ 4-8
4.6 GOOSE Alarm .................................................................................................. 4-8
List of Tables Table 4.2-1 Alarm description ...................................................................................................4-1 Table 4.2-2 Troubleshooting .....................................................................................................4-5
PCS-931 Line Differential Relay
4-a Date: 2013-09-07
4 Supervision
4-b
PCS-931 Line Differential Relay Date: 2013-09-07
4 Supervision
4.1 Overview Protection system is in quiescent state under normal conditions, and it is required to respond promptly for faults occurred on power system. When the device is in energizing process before the LED “HEALTHY” is on, the device need to be checked to ensure no abnormality. Therefore, the automatic supervision function, which checks the health of the protection system when startup and during normal operation, plays an important role. The numerical relay based on the microprocessor operations is suitable for implementing this automatic supervision function of the protection system. In case a defect is detected during initialization when DC power supply is provided to the device, the device will be blocked with indication and alarm of relay out of service. It is suggested a trial recovery of the device by re-energization. Please contact supplier if the device is still failure. When a failure is detected by the automatic supervision, it is followed by a LCD message, LED indication and alarm contact outputs. The failure alarm is also recorded in event recording report and can be printed If required.
4.2 Supervision Alarms Hardware circuit and operation status of the device are self-supervised continuously. If any abnormal condition is detected, information or report will be displayed and a corresponding alarm will be issued. A minor abnormality may block a certain number of protections functions while the other functions can still work. However, if severe hardware failure or abnormality, such as PWR module failure, DC converter failure and so on, are detected, all protection functions will be blocked and the LED “HEALTHY” will be extinguished and blocking output contacts BO_FAIL will be given. The protective device then can not work normally and maintenance is required to eliminate the failure. All the alarm signals and the corresponding handling suggestions are listed below. Note! If the protective device is blocked or alarm signal is sent during operation, please do find out its reason with the help of self-diagnostic record. If the reason can not be found at site, please notify the factory NR. Please do not simply press button “TARGET RESET” on the protection panel or re-energize on the device. Table 4.2-1 Alarm description No.
Item
Description
Blocking Device
Fail Signals The device fails. 1
Fail_Device
This signal will be pick up if any fail signal picks up and it
Blocked
will drop off when all fail signals drop off. 2
Fail_Setting_OvRange
Set value of any setting is out of scope.
PCS-931 Line Differential Relay
Blocked
4-1 Date: 2013-09-07
4 Supervision This signal will pick up instantaneously and will be latched unless the recommended handling suggestion is adopted. 3
Fail_BoardConfig
Mismatch between the configuration of plug-in modules and the designing drawing of an applied-specific project.
Blocked
After config file is updated, settings of the file and settings saved on the device are not matched. 4
Fail_SettingItem_Chgd
This signal will pick up instantaneously and will be
Blocked
latched unless the recommended handling suggestion is adopted. Error is found during checking memory data. 5
Fail_Memory
This signal will pick up instantaneously and will be latched unless the recommended handling suggestion is
Blocked
adopted. Error is found during checking settings. 6
Fail_Settings
This signal will pick up instantaneously and will be latched unless the recommended handling suggestion is
Blocked
adopted. DSP chip is damaged. 7
Fail_DSP
This signal will pick up instantaneously and will be latched unless the recommended handling suggestion is
Blocked
adopted. Communication between two DSP chips is abnormal 8
Fail_DSP_Comm
This signal will pick up instantaneously and will drop off
Blocked
instantaneously. Software configuation is incorrect. 9
Fail_Config
This signal will pick up instantaneously and will be latched unless the recommended handling suggestion is
Blocked
adopted. AC current and voltage samplings are abnormal. 10
Fail_Sample
This signal will pick up with a time delay of 200ms and will be latched unless the recommended handling
Blocked
suggestion is adopted. 11
MCBrd.Fail_Sample
12
MCBrd.Fail_Settings
For DSP plug-in module for measurement and control in slot 06, AC current and voltage samplings are abnormal Error is found during checking the settings of DSP plug-in module for measurement and control in slot 06.
Blocked
Blocked
Alarm Signals The device is abnormal. 13
Alm_Device
This signal will be pick up if any alarm signal picks up
Unblocked
and it will drop off when all alarm signals drop off. 14
Alm_Insuf_Memory
15
Alm_CommTest
The memory of MON plug-in module is insufficient. The device is in the communication test mode. This signal will pick up instantaneously and will drop off
4-2
Unblocked Unblocked
PCS-931 Line Differential Relay Date: 2013-09-07
4 Supervision instantaneously. The error is found during MON module checking 16
Alm_Settings_MON
settings of device. This signal will pick up with a time delay of 10s and will
Unblocked
be latched unless re-powering or rebooting the device. The error is found during checking the version of 17
Alm_Version
software downloaded to the device. This signal will pick up instantaneously and will drop off
Unblocked
instantaneously. The active group set by settings in device and that set 18
Alm_BI_SettingGrp
by binary input are not matched. This signal will pick up instantaneously and will drop off
Unblocked
instantaneously. Data frame is abnormal between two DSP modules. 19
Alm_DSP_Frame
This signal will pick up instantaneously and will drop off
Unblocked
instantaneously. The power supply of BI plug-in module in slot xx is 20
Bxx.Alm_OptoDC
abnormal. This signal will pick up with a time delay of 10s and will
Unblocked
drop off with a time delay of 10s. Fault detector element operates for longer than 50s. 21
Alm_Pkp_FD
This signal will pick up with a time delay of 50s and will
Unblocked
drop off with a time delay of 10s. Neutral current fault detector element operates for 22
Alm_Pkp_I0
longer than 10s. This signal will pick up with a time delay of 10s and will
Unblocked
drop off with a time delay of 10s. Protection VT circuit fails. 23
VTS.Alm
This signal will pick up with a time delay [VTS.t_DPU]
Unblocked
and will drop off with a time delay [VTS.t_DDO]. Protection VT circuit of neutral point fails. 24
VTNS.Alm
This signal will pick up with a time delay [VTS.t_DPU]
Unblocked
and will drop off with a time delay [VTS.t_DDO]. CT circuit of corresponding circuit breaker fails. 25
CTS.Alm
This signal will pick up with a time delay of 10s and will
Unblocked
drop off with a time delay of 10s. The 26
Alm_52b
auxiliary
normally
closed
contact
(52b)
of
corresponding circuit breaker is abnormal. This signal will pick up with a time delay of 10s and will
Unblocked
drop off with a time delay of 10s. The device is in maintenance state. 27
BI_Maintenance
This signal will pick up with a time delay of 150ms and
Unblocked
will drop off with a time delay of 150ms.
PCS-931 Line Differential Relay
4-3 Date: 2013-09-07
4 Supervision 28
Alm_TimeSyn
Time synchronization abnormality alarm.
Unblocked
Frequency of the system is higher than 65Hz or lower 29
Alm_Freq
than 45Hz. This signal will pick up with a time delay of 100ms and
Unblocked
will drop off with a time delay of 10s.
30
Alm_Sparexx (xx=01~08)
Spare alarm signals The time delay of pickup and dropoff for these alarm
Unblocked
signals can be set by PCS-Explorer. Protection Element Alarm Signals Channel x is abnormal
31
FOx.Alm
This signal will pick up with a time delay of 100ms and
Unblocked
will drop off with a time delay of 1s. Received ID from the remote end is not as same as the 32
FOx.Alm_ID
setting [FOx.RmtID] of the device in local end This signal will pick up with a time delay of 100ms and
Unblocked
will drop off with a time delay of 1s. No valid frame of channel x is received. 33
FOx.Alm_NoValFram
This signal will pick up with a time delay of 100ms and
Unblocked
will drop off with a time delay of 1s. Rate of error code of channel x is larger than 40 error 34
FOx.Alm_CRC
codes per second. This signal will pick up instantaneously and will drop off
Unblocked
with a time delay of 10s. Channelx is out of service due to receive error codes 35
FOx.Alm_Off
after device picking up. This signal will pick up instantaneously and will drop off
Unblocked
instantaneously. Optical fibre of channel x is connected wrongly. 36
FOx.Alm_Connect
This signal will pick up with a time delay of 100ms and
Unblocked
will drop off with a time delay of 1s. 37
27P1.Alm
Stage 1 of undervoltage protection alarms.
Unblocked
38
27P2.Alm
Stage 2 of undervoltage protection alarms.
Unblocked
39
59P1.Alm
Stage 1 of overvoltage protection alarms.
Unblocked
40
59P2.Alm
Stage 2 of overvoltage protection alarms.
Unblocked
41
49-1.Alm
42
49-2.Alm
43
46BC.Alm
44
25.Alm_VTS_UB
Stage 1 of thermal overload protection operates to alarm. Stage 2 of thermal overload protection operates to alarm. Broken-conductor protection operates to alarm.
Unblocked
Unblocked Unblocked
Synchronism voltage circuit is abnormal (UB) This signal will pick up with a time delay of 1.25s and will
Unblocked
drop off with a time delay of 10s. 45
25.Alm_VTS_UL
Synchronism voltage circuit is abnormal (UL)
4-4
Unblocked PCS-931 Line Differential Relay
Date: 2013-09-07
4 Supervision This signal will pick up with a time delay of 1.25s and will drop off with a time delay of 10s. 46
79.Fail_Rcls
Auto-reclosing fails.
Unblocked
47
79.Fail_Chk
Synchrocheck for AR fails.
Unblocked
Input signal of receiving transfer trip is energized for 48
TT.Alm
longer than 4s and it will drop off with a time delay of
Unblocked
10s. Table 4.2-2 Troubleshooting No.
Item
Handling suggestion Fail Signals
1
Fail_Device
The signal is issued with other specific fail signals, and please refer to the handling suggestion other specific alarm signals. Please reset setting values according to the range described in the instruction
2
Fail_Setting_OvRange
manual, then re-power or reboot the device and the device will restore to normal operation state. 1.
Go to the menu “Information→Borad Info”, check the abnormality
information. 3
Fail_BoardConfig
2.
For the abnormality board, if the board is not used, then remove, and if
the board is used, then check whether the board is installed properly and work normally. Please check the settings mentioned in the prompt message on the LCD, and 4
Fail_SettingItem_Chgd
go to the menu “Settings” and select “Confirm_Settings” item to comfirm settings. Then, the device will restore to normal operation stage.
5
Fail_Memory
Please inform the manufacture or the agent for repair.
6
Fail_Settings
Please inform the manufacture or the agent for repair.
7
Fail_DSP
8
Fail_DSP_Comm
9
Fail_Config
10
Fail_Sample
Chips are damaged and please inform the manufacture or the agent replacing the module. Please inform the manufacture or the agent for repair. Please inform configuration engineers to check and confirm visualization functions of the device 1.
Please make the device out of service.
2.
Then check if the analog input modules and wiring connectors
connected to those modules are installed at the position. 3.
Re-power the device and the device will restore to normal operation
state.
11
MCBrd.Fail_Sample
1.
Please make the device out of service.
2.
Then check if analog input modules and wiring connectors connected to
those modules are installed at the position. 3.
Re-power the device and the device will restore to normal operation
state. 12
MCBrd.Fail_Settings
Please inform the manufacturer or the agent for repair. Alarm Signals
13
Alm_Device
The signal is issued with other specific alarm signals, and please refer to the
PCS-931 Line Differential Relay
4-5 Date: 2013-09-07
4 Supervision handling suggestion other specific alarm signals. 14
Alm_Insuf_Memory
15
Alm_CommTest
16
Alm_Settings_MON
Please replace MON plug-in module. No special treatment is needed, and disable the communication test function after the completion of the test. Please inform the manufacture or the agent for repair. Users may pay no attention to the alarm signal in the project commissioning stage, but it is needed to download the latest package file (including correct
17
Alm_Version
version checksum file) provided by R&D engineer to make the alarm signal disappear. Then users get the correct software version. It is not allowed that the alarm signal is issued on the device already has been put into service. the devices having being put into service so that the alarm signal disappears. Please check the value of setting [Active_Grp] and binary input of indiating
18
Alm_BI_SettingGrp
active group, and make them matched. Then the “ALARM” LED will be extinguished and the corresponding alarm message will disappear and the device will restore to normal operation state.
19
20
Alm_DSP_Frame
Bxx.Alm_OptoDC
Please inform the manufacture or the agent for repair. 1.
check whether the binary input module is connected to the power supply.
2.
check whether the voltage of power supply is in the required range.
3.
After the voltage for binary input module restores to normal range, the
“ALARM” LED will be extinguished and the corresponding alarm message will disappear and the device will restore to normal operation state. Please check secondary values and protection settings. If settings are not set 21
Alm_Pkp_FD
reasonable to make fault detectors pick up, please reset settings, and then the alarm message will disappear and the device will restore to normal operation state. Please check secondary values and protection settings. If settings are not set
22
Alm_Pkp_I0
reasonable to make fault detectors pick up, please reset settings, and then the alarm message will disappear and the device will restore to normal operation state.
23
VTS.Alm
24
VTNS.Alm
25
CTS.Alm
26
Alm_52b
Please check the corresponding VT secondary circuit. After the abnormality is eliminated, the device returns to normal operation state. Please check the corresponding VT secondary circuit of neutral point. After the abnormality is eliminated, the device returns to normal operation state. Please check the corresponding CT secondary circuit. After the abnormality is eliminated, the device returns to normal operation state. Please check the auxiliary contact of CB. After the abnormality is eliminated, the device returns to normal operation state. After maintenance is finished, please de-energized the binary input
27
BI_Maintenance
[BI_Maintenance] and then the alarm will disappear and the device restore to normal operation state. 1.
28
Alm_TimeSyn
check whether the selected clock synchronization mode matches the
clock synchronization source; 2.
check whether the wiring connection between the device and the clock
4-6
PCS-931 Line Differential Relay Date: 2013-09-07
4 Supervision synchronization source is correct 3.
check whether the setting for selecting clock synchronization (i.e.
[Opt_TimeSync]) is set correctly. If there is no clock synchronization, please set the setting [Opt_TimeSync] as ”No TimeSync”. 4.
After the abnormality is removed, the “ALARM” LED will be extinguished
and the corresponding alarm message will disappear and the device will restore to normal operation state. 29 30
Alm_Freq
Adjust the system operating mode
Alm_Sparexx
Find the reason according to specific problem. (These signals are
(xx=01~08)
user-defined.) Operation Alarm Signals
31
FOx.Alm
Please check the conncetion of optical fibre channel.
32
FOx.Alm_ID
Please check the conncetion of optical fibre channel.
33
FOx.Alm_NoValFram
Please check the conncetion of optical fibre channel.
34
FOx.Alm_CRC
Please check the conncetion of optical fibre channel.
35
FOx.Alm_Off
Please check the conncetion of optical fibre channel.
36
FOx.Alm_Connect
Please check the conncetion of optical fibre channel. (For example, receiving and sending are inconsistent, or channel 1 and channel 2 are inconsistent) Please check the corresponding binary input secondary circuit. After the
37
TT.Alm
abnormality is eliminated, “ALARM” LED will go off automatically and device returns to normal operation state with a time delay of 10s.
4.3 Relay Self-supervision 4.3.1 Relay Hardware Monitoring All chips on DSP module are monitored to ensure whether they are damaged or having errors. If any one of them is detected damaged or having error, the alarm signal [Fail_DSP] is issued with the device being blocked.
4.3.2 Fault Detector Monitoring When neutral current fault detector picks up and lasts for longer than 10 seconds, an alarm [Alm_Pkp_I0] will be issued without the device blocked. When any fault detector picks up for longer than 50s, an alarm will be issued [Alm_Pkp_FD] without the device blocked.
4.3.3 Check Setting This relay has 10 setting groups, only one Setting group could be activiated (is active) at a time. The settings of active setting group are checked to ensure they are reasonable. If settings are checked to be unreasonable or out of setting scopes, a corresponding alarm signal will be issued, and the device is also blocked.
PCS-931 Line Differential Relay
4-7 Date: 2013-09-07
4 Supervision
4.4 AC Input Monitoring 4.4.1 Voltage/current Drift Monitoring and Auto-adjustment Zero point of voltage and current may drift due to variation of temperature or other environment factors. The device continually traces the drift and adjust it to normal value automatically.
4.4.2 Sampling Monitoring AC current and voltage samplings of protection DSP and fault detector DSP are monitored and if the samples of protection DSP and fault detector DSP are detected to be wrong or inconsistent between them, the alarm signal [Fail_Sample] will be issued and the device will be blocked.
4.5 Secondary Circuit Monitoring 4.5.1 Opto-coupler Power Supervision Positive power supply of opto-coupler is continually monitored. If an error or damage has occurred, an alarm [Bxx.Alm_OptoDC] will be issued.
4.5.2 Circuit Breaker Supervision If 52b of three phases are energized ,which indicates circuit breaker is open and there is no current detected in the line, the line will be considered to be out of service. SOTF protection will be enabled after 50ms. If 52b of three phases are energized that indicates circuit breaker is open but there is still current detected in the line (the measured current is greater than a settable threshold value) or three-phase circuit breaker is in pole disagreement, an alarm signal [Alm_52b] will be issued after 10 seconds.
4.6 GOOSE Alarm No.
Output Signal
Description GOOSE alarm signal indicating that there is a network storm occurring on the
1
GAlm_AStorm_SL
2
GAlm_BStorm_SL
3
GAlm_CfgFile_SL
4
Namexx.GAlm_ADisc_SL_xx
GOOSE alarm signal indicating that network A for Namexx is disconnected.
5
Namexx.GAlm_BDisc_SL_xx
GOOSE alarm signal indicating that network B for Namexx is disconnected.
6
Namexx.GAlm_Cfg_SL_xx
network A. GOOSE alarm signal indicating that there is a network storm occurring on the network B. GOOSE alarm signal indicating that there is an error in the GOOSE configuration file
Between GOOSE control blocks received on network and GOOSE control blocks defined in GOOSE.txt file are unmatched for Namexx.
These are GOOSE alarm reports. When any alarm message is issued, the LED “ALARM” is lit without the device being blocked. After the abnormality is removed, the device will return to normal with the LED “ALARM” being distinguished automatically. 4-8
PCS-931 Line Differential Relay Date: 2013-09-07
4 Supervision No.
Output Signal
Handling suggestion
1
GAlm_AStorm_SL
Please check the related switches
2
GAlm_BStorm_SL
Please check the related switches
3
GAlm_CfgFile_SL
Please check the GOOSE configuration file (i.e. GOOSE.txt)
4
Namexx.GAlm_ADisc_SL_xx
Please check the network
5
Namexx.GAlm_BDisc_SL_xx
Please check the network
6
Namexx.GAlm_Cfg_SL_xx
Please check the GOOSE configuration file and the network
Namexx is the name defined by the setting [Linkxx], xx=01, 02, 03, …, 64
PCS-931 Line Differential Relay
4-9 Date: 2013-09-07
4 Supervision
4-10
PCS-931 Line Differential Relay Date: 2013-09-07
5 Management
5 Management Table of Contents 5 Management ..................................................................................... 5-a 5.1 Measurement ................................................................................................... 5-1 5.1.1 Root-Mean-Square Values ................................................................................................. 5-1 5.1.2 Phase Angle ....................................................................................................................... 5-2 5.1.3 Primary Value ..................................................................................................................... 5-3
5.2 Recording ........................................................................................................ 5-4 5.2.1 Overview ............................................................................................................................ 5-4 5.2.2 Event Recording ................................................................................................................ 5-5 5.2.3 Disturbance Recording ...................................................................................................... 5-5 5.2.4 Present Recording ............................................................................................................. 5-7
PCS-931 Line Differential Relay
5-a Date: 2013-09-07
5 Management
5-b
PCS-931 Line Differential Relay Date: 2013-09-07
5 Management
5.1 Measurement PCS-931 performs continuous measurement of the analogue input quantities. The current full scale of relay is 40 times of rated current, and there is no effect to the performance of IED due to overflowing of current full scale. The device samples 24 points per cycle and calculates the RMS value in each interval and updated the LCD display in every 0.5 second. The measurement data can be displayed on the LCD of the relay front panel or on the local/remote PC via software tool. Navigate the menu to view the sampling value through LCD screen.
5.1.1 Root-Mean-Square Values Access path: MainMenu “Measurements” “Measurements1” “Measurement1” is use to display measured values from protection calculation DSP (displayed in secondary value) MainMenu “Measurements” “Measurements2” “Measurement2” is used to display measured values from fault detector DSP (displayed in secondary value) No.
Symbol
Definition
Resolution
Unit
1
Ia
The secondary value of phase-A current
0.000
A
2
Ib
The secondary value of phase-B current
0.000
A
3
Ic
The secondary value of phase-C current
0.000
A
4
I1
The secondary value of positive-sequence current
0.000
A
5
I2
The secondary value of negative-sequence current
0.000
A
6
3I0
The secondary value of calculated residual current
0.000
A
7
3I0Adj
0.000
A
8
Ua
The secondary value of phase-A protection voltage
0.000
V
9
Ub
The secondary value of phase-B protection voltage
0.000
V
10
Uc
The secondary value of phase-C protection voltage
0.000
V
11
Uab
The secondary value of phase-AB protection voltage
0.000
V
12
Ubc
The secondary value of phase-BC protection voltage
0.000
V
13
Uca
The secondary value of phase-CA protection voltage
0.000
V
14
Usyn
The secondary value of synchronism voltage
0.000
V
15
U1
The secondary value of positive-sequence voltage
0.000
V
16
U2
The secondary value of negative-sequence voltage
0.000
V
17
3U0
The secondary value of calculated residual voltage
0.000
V
18
f
Frequency of protection voltage
0.000
Hz
The secondary value of residual current from parallel line
PCS-931 Line Differential Relay
5-1 Date: 2013-09-07
5 Management 19
25.f_Syn
Frequency of synchronism voltage
20
25.f_Diff
21
25.phi_Diff
22
25.U_Diff
23
87L.FOx.Ia_Rmt
24
87L.FOx.Ib_Rmt
25
87L.FOx.Ic_Rmt
26
87L.FOx.Ida
Frequency difference between protection voltage and synchronism voltages Phase angle difference between protection voltage and synchronism voltages Voltage difference between protection voltage and synchronism voltages The secondary value of phase-A current from the remote end via optical fibre channel x The secondary value of phase-B current from the remote end via optical fibre channel x The secondary value of phase-C current from the remote end via optical fibre channel x
0.000
Hz
0.000
Hz
0
V
0.000
V
0.000
A
0.000
A
0.000
A
0.000
A
0.000
A
0.000
A
The secondary value of phase-A differential current with capacitive current compensation of optical fibre channel x The secondary value of phase-B differential current with 27
87L.FOx.Idb
capacitive current compensation of optical fibre channel x The secondary value of phase-C differential current with
28
87L.FOx.Idc
capacitive current compensation of optical fibre channel x
5.1.2 Phase Angle Access path: MainMenu “Measurements” “Measurements1” “Measurement1” is use to display measured values from protection calculation DSP (displayed in secondary value) MainMenu “Measurements” “Measurements2” “Measurement2” is used to display measured values from fault detector DSP (displayed in secondary value) No.
Symbol
1
Ang (Ua-Ub)
2
Ang (Ub-Uc)
3
Ang (Uc-Ua)
4
Ang (Ua-Ia)
Definition Phase angle between phase-A voltage and phase-B voltage Phase angle between phase-B voltage and phase-C voltage Phase angle between phase-C voltage and phase-A voltage Phase angle between phase-A voltage and
5-2
Resolution
Unit
0
Deg
0
Deg
0
Deg
0
Deg
PCS-931 Line Differential Relay Date: 2013-09-07
5 Management phase-A current Phase angle between phase-B voltage and
5
Ang (Ub-Ib)
6
Ang (Uc-Ic)
7
Ang (Ia-Ib)
8
Ang (Ib-Ic)
9
Ang (Ic-Ia)
10
87L.FOx.Ang (Ia_Loc-Ia_Rmt)
11
87L.FOx.Ang (Ib_Loc-Ib_Rmt)
12
87L.FOx.Ang (Ic_Loc-Ic_Rmt)
phase-B current Phase angle between phase-C voltage and phase-C current Phase angle between phase-A current and phase-B current Phase angle between phase-B current and phase-C current Phase angle between phase-C current and phase-A current Phase angle between local phase-A current and remote phase-A current Phase angle between local phase-B current and remote phase-B current Phase angle between local phase-C current and remote phase-C current
0
Deg
0
Deg
0
Deg
0
Deg
0
Deg
0
Deg
0
Deg
0
Deg
5.1.3 Primary Value Access path: MainMenu “Measurements” “Measurements3” “Measurement3” is used to display measured primary values and other calculated quantities related to the measurement and control. No.
Symbol
Definition
Resolution
Unit
1
Ia
The primary value of phase-A current
0.000
A
2
Ib
The primary value of phase-A current
0.000
A
3
Ic
The primary value of phase-A current
0.000
A
4
I1
The primary value of positive-sequence current
0.000
A
5
I2
The primary value of negative-sequence current
0.000
A
6
3I0
The primary value of calculated residual current
0.000
A
7
3I0Adj
The primary value of residual current from parallel line
0.000
A
8
Ua
The primary value of phase-A voltage
0.000
kV
9
Ub
The primary value of phase-B voltage
0.000
kV
10
Uc
The primary value of phase-C voltage
0.000
kV
11
Uab
The primary value of phase-AB voltage
0.000
kV
12
Ubc
The primary value of phase-BC voltage
0.000
kV
13
Uca
The primary value of phase-CA voltage
0.000
kV
PCS-931 Line Differential Relay
5-3 Date: 2013-09-07
5 Management 14
U1
The primary value of positive-sequence voltage
0.000
kV
15
U2
The primary value of negative-sequence voltage
0.000
kV
16
3U0
The primary value of calculated residual voltage
0.000
kV
17
U_Syn
The primary value of synchronism voltage
0.000
kV
18
f
Frequency of protection voltage
0.000
Hz
19
f_Syn
Frequency of synchronism voltage
0.000
Hz
20
P
The primary value of active power
0.000
MW
21
Q
The primary value of reactive power
0.000
MVar
22
S
The primary value of apparent power
0.000
MVA
23
Cos
The value of power factor
0.000
-
24
Pa
The primary value of phase-A active power
0.000
MW
25
Pb
The primary value of phase-B active power
0.000
MW
26
Pc
The primary value of phase-C active power
0.000
MW
27
Qa
The primary value of phase-A reactive power
0.000
MVar
28
Qb
The primary value of phase-B reactive power
0.000
MVar
29
Qc
The primary value of phase-C reactive power
0.000
MVar
30
Cosa
The value of phase-A power factor
0.000
-
31
Cosb
The value of phase-B power factor
0.000
-
32
Cosc
The value of phase-C power factor
0.000
-
33
f_Diff
0.000
Hz
34
df/dt
0.000
Hz/s
35
phi_Diff
0.00
Deg
36
U_Diff
0.000
kV
37
PHr+_Pri
The primary positive active energy
0.000
MWh
38
PHr-_Pri
The primary negative active energy
0.000
MWh
39
QHr+_Pri
The primary positive reactive energy
0.000
MVAh
40
QHr-_Pri
The primary negative reactive energy
0.000
MVAh
The frequency difference between reference side and incoming side for manual closing synchrocheck The rate of frequency change between reference side and incoming side for manual closing synchrocheck Phase angle difference between reference side and incoming side for manual closing synchrocheck The primary value of voltage difference between reference side and incoming side for manual closing synchrocheck.
5.2 Recording 5.2.1 Overview PCS-931 provides the following recording functions: 1.
Event recording
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PCS-931 Line Differential Relay Date: 2013-09-07
5 Management
2.
Disturbance recording
3.
Present recording
All the recording information except waveform can be viewed on local LCD or by printing. Waveform could only be printed or extracted with PCS-Explorer software tool and a waveform analysis software.
5.2.2 Event Recording 5.2.2.1 Overview The device can store the latest 1024 disturbance records, 1024 binary events, 1024 supervision events, 256 control logs and 1024 device logs. All the records are stored in non-volatile memory, and when the available space is exhausted, the oldest record is automatically overwritten by the latest one. 5.2.2.2 Disturbance Records When any protection element operates or drops off, such as fault detector, distance protection etc., they will be logged in event records. 5.2.2.3 Supervision Events The device is under automatic supervision all the time. If there are any failure or abnormal condition detected, such as, chip damaged, VT circuit failure and so on, it will be logged in event records. 5.2.2.4 Binary Events When there is a binary input is energized or de-energized, i.e., its state has changed from “0” to “1” or from “1” to “0”, it will be logged in event records. 5.2.2.5 Control Logs When the total number of control command records reaches 256, “Control_Logs” memory area will be full. If the device receives a new control command now, the oldest control command record will be deleted, and then the latest control command record will be stored and displayed. 5.2.2.6 Device Logs If an operator implements some operations on the device, such as reboot protective device, modify setting, etc., they will be logged in event records.
5.2.3 Disturbance Recording 5.2.3.1 Application Disturbance records can be used to have a better understanding of the behavior of the power network and related primary and secondary equipment during and after a disturbance. Analysis of the recorded data provides valuable information that can be used to improve existing equipment. This information can also be used when planning for and designing new installations.
PCS-931 Line Differential Relay
5-5 Date: 2013-09-07
5 Management
5.2.3.2 Design A disturbance record consists of fault record and fault waveform. The disturbance record can be initiated by fault detector element, tripping element, reclosing element or configurable signal [BI_TrigDFR]. 5.2.3.3 Capacity and Information of Disturbance Records The device can store up to 32 disturbance records with waveform in non-volatile memory. It is based on first in first out queue that the oldest disturbance record will be overwritten by the latest one. For each disturbance record, the following items are included: 1.
Sequence number
Each operation will be recorded with a sequence number in the record and displayed on LCD screen. 2.
Date and time of fault occurrence
The time resolution is 1ms using the relay internal clock synchronized via clock synchronized device if connected. The date and time is recorded when a system fault is detected. 3.
Relative operating time
An operating time (not including the operating time of output relays) is recorded in the record. 4.
Faulty phase
5.
Fault location
To get accurate result of fault location, the following settings shall be set correctly: 1)
Positive-sequence line reactance [X1L]
2)
Positive-sequence line resistance [R1L]
3)
Zero-sequence line reactance [X0L]
4)
Zero-sequence line resistance [R0L]
5)
Zero-sequence line mutual reactance [X0M]
6)
Zero-sequence line mutual resistance [R0M]
7)
Line positive-sequence sensitive angle [phi1_Reach]
8)
Line zero-sequence sensitive angle [ph0_Reach]
9)
Line length in km [LineLength]
6.
Protection elements
5.2.3.4 Capacity and Information of Fault Waveform MON module can store 32 pieces of fault waveform oscillogram in non-volatile memory. If a new 5-6
PCS-931 Line Differential Relay Date: 2013-09-07
5 Management
fault occurs when 32 fault waveform have been stored, the oldest will be overwritten by the latest one. Each fault record consists of all analog and digital quantities related to protection, such as original current and voltage, differential current, alarm elements, and binary inputs and etc. Each time recording includes 12-cycle pre-fault waveform, and 250 cycles at least and 500 cycles at most can be recorded. Each cycle waveform is high-frequency recording at a rate of 1200Hz (24 poingts per cycle).
5.2.4 Present Recording Present recording is a waveform triggered manually on on the device′s LCD or remotely through PCS-Explorer software. Recording content of present recording is same to that of disturbance recording. Each time recording includes 12-cycle waveform before triggering, and 250 cycles at most can be recorded. Each cycle waveform is high-frequency recording at a rate of 1200Hz (24 poingts per cycle).
PCS-931 Line Differential Relay
5-7 Date: 2013-09-07
5 Management
5-8
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6 Hardware
6 Hardware Table of Contents 6 Hardware .......................................................................................... 6-a 6.1 Overview .......................................................................................................... 6-1 6.2 Typical Wiring .................................................................................................. 6-4 6.2.1 Conventional CT/VT (For reference only) .......................................................................... 6-4 6.2.2 ECT/EVT (For reference only) ........................................................................................... 6-6 6.2.3 CT Requirement ................................................................................................................. 6-8
6.3 Plug-in Module Description ............................................................................ 6-9 6.3.1 PWR Plug-in Module (Power Supply) ................................................................................ 6-9 6.3.2 MON Plug-in Module (Monitor) ........................................................................................ 6-11 6.3.3 AI Plug-in Module (Analog Input) ..................................................................................... 6-13 6.3.4 DSP Plug-in Module (Logic Process) ............................................................................... 6-23 6.3.5 NET-DSP Plug-in Module (GOOSE and SV) ................................................................... 6-24 6.3.6 CH Plug-in Module (Fibre Optical Channel Interface) ...................................................... 6-25 6.3.7 BI Plug-in Module (Binary Input) ...................................................................................... 6-26 6.3.8 BO Plug-in Module (Binary Output) .................................................................................. 6-31 6.3.9 HMI Module...................................................................................................................... 6-33
List of Figures Figure 6.1-1 Rear view of fixed module position ....................................................................6-1 Figure 6.1-2 Hardware diagram ................................................................................................6-2 Figure 6.1-3 Front view of PCS-931 ..........................................................................................6-3 Figure 6.1-4 Typical rear view of PCS-931 ...............................................................................6-4 Figure 6.2-1 Typical wiring of PCS-931 (conventional CT/VT) ...............................................6-5 Figure 6.2-2 Typical wiring of PCS-931 (ECT/EVT) .................................................................6-7 Figure 6.3-1 View of PWR plug-in module .............................................................................6-10 Figure 6.3-2 Output contacts of PWR plug-in module ..........................................................6-10 PCS-931 Line Differential Relay
6-a Date: 2013-09-07
6 Hardware
Figure 6.3-3 View of MON plug-in module .............................................................................6-12 Figure 6.3-4 Connection of communication terminal ...........................................................6-13 Figure 6.3-5 Schematic diagram of CT circuit automatically closed ...................................6-14 Figure 6.3-6 Current connection of AI plug-in module .........................................................6-15 Figure 6.3-7 Voltage connection 1 of AI plug-in module ......................................................6-16 Figure 6.3-8 Voltage connection 2 of AI plug-in module ......................................................6-16 Figure 6.3-9 View of AI plug-in module for one CT group input ..........................................6-17 Figure 6.3-10 Current connection of AI plug-in module .......................................................6-18 Figure 6.3-11 Voltage connection of AI plug-in module........................................................6-19 Figure 6.3-12 View of AI plug-in module for two CT group input ........................................6-19 Figure 6.3-13 Current connection of AI plug-in module .......................................................6-21 Figure 6.3-14 Voltage connection of AI plug-in module .......................................................6-21 Figure 6.3-15 View of AI plug-in module for two CT group input ........................................6-22 Figure 6.3-16 View of DSP plug-in module ............................................................................6-23 Figure 6.3-17 View of NET-DSP plug-in module ....................................................................6-24 Figure 6.3-18 View of CH plug-in module ..............................................................................6-25 Figure 6.3-19 Debouncing technique .....................................................................................6-26 Figure 6.3-20 View of BI plug-in module (NR1503) ...............................................................6-27 Figure 6.3-21 View of BI plug-in module (NR1504) ...............................................................6-28 Figure 6.3-22 View of BO plug-in module (NR1521A) ...........................................................6-31 Figure 6.3-23 View of BO plug-in module (NR1521C) ...........................................................6-32 Figure 6.3-24 View of BO plug-in module (NR1521F) ...........................................................6-33
List of Tables Table 6.3-1 Terminal definition and description of PWR plug-in module ............................6-10 Table 6.3-2 Terminal definition of AI module .........................................................................6-17 Table 6.3-3 Terminal definition of AI module .........................................................................6-20 Table 6.3-4 Terminal definition of AI module .........................................................................6-22
6-b
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware
6.1 Overview PCS-931 adopts 32-bit microchip processor CPU produced by FREESCALE as control core for management and monitoring function, meanwhile, adopts high-speed digital signal processor DSP for all the protection calculation. 24 points are sampled in every cycle and parallel processing of sampled data can be realized in each sampling interval to ensure ultrahigh reliability and safety of the device.
12
13
PWR module
11
BO module
09
BO module
08
BO module
06
BO module
DSP module
05
BI module
CH Module
04
BI module
DSP module
AI module
MON module
PCS-931 is comprised of intelligent plug-in modules, except that few particular plug-in modules’ position cannot be changed in the whole device (gray plug-in modules as shown in Figure 6.1-1), other plug-in modules like AI (analog input) and IO (binary input and binary output) can be flexibly configured in the remaining slot positions.
15
P1
Slot No. 01
02
03
07
10
14
Figure 6.1-1 Rear view of fixed module position
PCS-931 has 16 slots, PWR plug-in module, MON plug-in module, DSP plug-in module and CH plug-in module are assigned at fixed slots. Besides 5 fixed modules are shown in above figure, there are 12 slots can be flexibly configured. AI plug-in module, BI plug-in module and BO plug-in module can be configured at position between slot 02, 03 and 06~15. It should be pay attention that AI plug-in module will occupy two slots. This device is developed on the basis of our latest software and hardware platform, and the new platform major characteristics are of high reliability, networking and great capability in anti-interference. See Figure 6.1-2 for hardware diagram.
PCS-931 Line Differential Relay
6-1 Date: 2013-09-07
A/D
Protection Calculation DSP
A/D
Fault Detector DSP
Output Relay
Conventional CT/VT
External Binary Input
6 Hardware
ECVT Pickup Relay
ECVT ETHERNET LCD Power Supply
Uaux
+E Clock SYN
LED
CPU RJ45
Keypad PRINT
Figure 6.1-2 Hardware diagram
The working process of the device is as shown in above figure: current and voltage from conventional CT/VT are converted into small voltage signal and sent to DSP module after filtered and A/D conversion for protection calculation and fault detector respectively (ECVT signal is sent to the device without small signal and A/D convertion). When DSP module completes all the protection calculation, the result will be recorded in 32-bit CPU on MON module. DSP module carries out fault detector, protection logic calculation, tripping output, and MON module perfomes SOE (sequence of event) record, waveform recording, printing, communication between the device and SAS and communication between HMI and CPU. When fault detector detects a fault and picks up, positive power supply for output relay is provided. The items can be flexibly configured depending on the situations like sampling method of the device (conventional CT/VT or ECT/EVT), and the mode of binary output (conventional binary output or GOOSE binary output). The configurations for PCS-900 series based on microcomputer are classified into standard and optional modules. Table 6.1-1 PCS-931 module configuration No.
ID
1
NR1101/NR1102
Management and monitor module (MON module)
standard
2
NR1401
Analog input module (AI module )
standard
3
NR1161
Protection calculation and fault detector module (DSP module)
standard
4
NR1213
Protection communication channel module (CH module)
standard
5
NR1503/NR1504
Binary input module (BI module)
standard
6
NR1521
Binary output module (BO module)
standard
7
NR1301
Power supply module (PWR module)
standard
Module description
6-2
Remark
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware ID
No.
8
NR1136
9
Module description
Remark
GOOSE and SV from merging unit by IEC61850-9-2 (NET-DSP module) Human machine interface module (HMI module)
option standard
MON module provides functions like communication with SAS, event record, setting management etc.
AI module converts AC current and voltage from current transformers and voltage transformers respectively to small voltage signal.
DSP module performs filtering, sampling, protection calculation and fault detector calculation.
CH module performs information exchange with the remote device through a dedicated optical fibre channel, multiplex optical fibre channel or PLC channel.
BI module provides binary inputs via opto-couplers with rating voltage among 24V/110V/125V/220V/250V (configurable).
BO module provides output contacts for tripping, and signal output contact for annunciation signal, remote signal, fault and disturbance signal, operation abnormal signal etc.
PWR module converts DC 250/220/125/110V into various DC voltage levels for modules of the device.
HMI module is comprised of LCD, keypad, LED indicators and multiplex RJ45 ports for user as human-machine interface.
NET-DSP module receives and sends GOOSE messages, sampled values (SV) from merging unit by IEC61850-9-2 protocol.
PCS-931 series is made of a 4U height 19” chassis for flush mounting. Components mounted on its front include a 320×240 dot matrix LCD, a 9 button keypad, 20 LED indicators and a multiplex RJ45 port. A monolithic micro controller is installed in the equipment for these functions. Following figures show front and rear views of PCS-931 respectively.
ALARM
11
PCS-931
12
LINE DIFFERENTIAL RELAY
13
4
14
5
15
6
16
7
17
8
18
9
19
10
20
GRP
3
HEALTHY
ESC
1 2
ENT
Figure 6.1-3 Front view of PCS-931
PCS-931 Line Differential Relay
6-3 Date: 2013-09-07
6 Hardware
20 LED indicators are, from top to bottom, operation (HEALTHY), self-supervision (ALARM), others are configurable. For the 9-button keypad, “ENT” is “enter”, “GRP” is “group number” and “ESC” is “escape”.
NR1102
NR1401
NR1161
NR1161
NR1213
NR1504
NR1504
NR1521
NR1521
NR1521
NR1521
NR1301 5V OK
ALM
TX BO_ALM BO_FAIL
RX ON TX OFF RX
DANGER 1 BO_COM1 2
BO_FAIL
3
BO_ALM
4
BO_COM2
5
BO_FAIL
6
BO_ALM
7
OPTO+
8
OPTO-
9 10
PWR+
11
PWR-
12
GND
Figure 6.1-4 Typical rear view of PCS-931
6.2 Typical Wiring 6.2.1 Conventional CT/VT (For reference only)
12
13
PWR module
11
NR1521F NR1301
BO module
BO module
06
BO module
05
NR1521A NR1521C NR1521C
BO module
04
NR1504
BI module
NR1161
DSP module
NR1213
CH Module
AI module
NR1161
DSP module
NR1401
MON module
NR1102
15
P1
Slot No. 01
02
03
07
08
09
10
14
The following typical wiring is given based on above hardware configuration
6-4
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware
Power supply supervision
0801
CH-TX
CH-RX
BI_01
or CH-TX CH-RX
Fibre Optic
FC/PC Type (Rear) 0201 Ia
0203 Ib
0204 0205 To parallel line
Ic
0206 0207
From parallel line
IM0
0208
0215 Ub
0216 0217
0221 UL2
0222 0223
Power supply for opto-coupler (24V)
P110
PWR-
P111
OPTO+
P107
OPTO-
P108
BO_ALM
P101
COM
P105
BO_FAIL
P106
BO_ALM
P104
COM
Not used
0815
+
0816
+
0821 0822
1101 BO_01
1102 1103
BO_02
1104
BO_11
1121 1122
1201 BO_01
1202 1203
BO_02
1204
BO_11
1221 1222
1301 BO_01
1302 1303
BO_02
1304 …
BO_FAIL
P103
0814
-
Power Supply
P102
+
BI_13
Signal Binary Output (option)
PWR+
0809
…
External DC power supply
+
BI_12
Signal Binary Output
UB2
0224
0808
…
UB1
0220
Not used
BI_18
Synchronism Voltage
0219
0807
BI_07
Controlled by fault detector element
Uc
0218
+
BI_06
…
Ua
0214
Protection Voltage
0213
0802
…
0202
+
…
*BI plug-in module can be independent common terminal
Dedicated Channel Or Telecom Equipment
BO_11
1321 1322
1501 B
0102
SGND
0103
BO_CtrlOpn1
0104 0101
SYN-
0102
SGND
0103 0104
Clock SYN
SYN+
1502 1503
BO_CtrlCls1
1504 …
Signal Binary Output (option)
0101 COM
To the screen of other coaxial cable with single point earthing
A
1517 BO_CtrlOpn5
1518 1519
BO_CtrlCls5
1520 1521
0105
TXD
0106
SGND
0107
PRINT
PRINTER
RTS
BO_Ctrl Multiplex RJ45 (Front)
1522 P112 0225 Grounding Bus
Figure 6.2-1 Typical wiring of PCS-931 (conventional CT/VT)
PCS-931 Line Differential Relay
6-5 Date: 2013-09-07
6 Hardware PCS-931 (conventional CT/VT and conventional binary input and binary output)
Slot No.
01
04
05
08
09
11
12
13
15
P1
Module ID
NR1102
02
NR1401
03
NR1161
NR1213
06
07
NR1504
NR1504
10
NR1521
NR1521
NR1521
14
NR1521
NR1301
MON
AI
DSP
CH
BI
BI
BO
BO
BO
BO
PWR
08
09
11
12
13
PCS-931 (conventional CT/VT and GOOSE binary input and binary output)
Slot No.
01
04
05
06
Module ID
NR1102
02
NR1401
03
NR1161
NR1213
NR1136
07
NR1504
10
14
15
NR1301
P1
MON
AI
DSP
CH
NETDSP
BI
PWR
6.2.2 ECT/EVT (For reference only)
06
07
08
11
12
NR1301
PWR module
05
BO module
04
NR1521A NR1521C
BO module
BI module
NR1503
NET-DSP Module
NR1136
DSP module
NR1161
CH Module
NR1213
DSP module
NR1161
MON module
NR1102
Slot No. 01
02
03
09
10
13
14
15
P1
The following typical wiring is given based on above hardware configuration
6-6
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware
CH-RX
Dedicated Channel Or Telecom Equipment
or CH-TX CH-RX
Fibre Optic
MU
Phase B
RX
TX
… P111
OPTO+
P107
OPTO-
P108
Power Supply
BO_FAIL
P103
BO_ALM
P101
COM
P105
BO_FAIL
P106
BO_ALM
P104
COM
B
0102
SGND
0103 0104 0101
SYN-
0102
SGND
0103 0104 0105
TXD
0106
SGND
0107
0804
+
0805
-
0806
+
0821
-
0822
1101 1102 1103 BO_02
1104
BO_11
1121 1122
1201 BO_01
1202 1203
BO_02
1204
BO_11
1221 1222
1502 1503
BO_CtrlCls1
1504
1517 BO_CtrlOpn5
1518 1519
BO_CtrlCls5
1520 1521
BO_Ctrl
1522 IRIG-B
PRINT
PRINTER
RTS
-
BO_01
Clock SYN
SYN+
0803
…
0101
+
1501
COM
To the screen of other coaxial cable with single point earthing
A
0802
BO_CtrlOpn1
Signal Binary Output (option)
P102
-
…
PWR-
0801
…
Power supply for opto-coupler (24V)
P110
BI_11
Signal Binary Output
External DC power supply
PWR+
BI_03
Controlled by fault detector element
Phase C
BI_02
+
…
Phase A
FC/PC Type (Rear)
FO interface for SV channel Up to 8 (LC Type)
SV from ECT/EVT
BI_01
*BI plug-in module can be common negative terminal
CH-TX
P112 Multiplex RJ45 (Front)
0225
Grounding Bus
Figure 6.2-2 Typical wiring of PCS-931 (ECT/EVT)
PCS-902 ECT/EVT, GOOSE binary input and binary output
Slot No.
01
04
05
06
Module ID
NR1102
02
03
NR1161
NR1213
NR1136
07
NR1504
08
09
10
11
12
13
14
15
NR1301
P1
MON
DSP
CH
NETDSP
BI
PWR
PCS-902 ECT/EVT, conventional binary input and binary output
Slot No.
01
Module ID
02
03
04
05
06
NR1102
NR1161
NR1213
MON
DSP
CH
07
08
09
NR1136
NR1504
NETDSP
BI
11
12
13
NR1504
NR1521
NR1521
BI
BO
BO
PCS-931 Line Differential Relay
10
14
15
P1
NR1521
NR1521
NR1301
BO
BO
PWR
6-7 Date: 2013-09-07
6 Hardware
In the protection system adopting electronic current and voltage transformer (ECT/EVT), the merging unit will merge the sample data from ECT/EVT, and then send it to the device through multi-mode optical fibre. DSP module receives the data from merging unit through the optical-fibre interface to complete the protection calculation and fault detector. The difference between the hardware platform based on ECT/EVT and the hardware platform based on conventional CT/VT lies in the receiving module of sampled values only, and the device receives the sampled value from merging unit through multi-mode optical fibre.
6.2.3 CT Requirement -Rated primary current Ipn: According to the rated current or maximum load current of primary apparatus. -Rated continuous thermal current Icth: According to the maximum load current. -Rated short-time thermal current Ith and rated dynamic current Idyn: According to the maximum fault current. -Rated secondary current Isn -Accuracy limit factor Kalf: Ipn
Rated primary current (amps)
Icth
Rated continuous thermal current (amps)
Ith
Rated short-time thermal current (amps)
Idyn
Rated dynamic current (amps)
Isn
Rated secondary current (amps)
Kalf
Accuracy limit factor ()Kalf=Ipal/Ipn
IPal
Rated accuracy limit primary current (amps)
Performance verification Esl > Esl′ Esl
Rated secondary limiting e.m.f (volts) Esl = kalf×Isn×(Rct+Rbn)
Kalf
Accuracy limit factor (Kalf=Ipal/Ipn)
IPal
Rated accuracy limit primary current (amps)
Ipn
Rated primary current (amps)
Isn
Rated secondary current (amps)
Rct
Current transformer secondary winding resistance. (ohms)
Rbn
Rated resistance burden (ohms) Rbn=Sbn/Isn2
Sbn
Rated burden (VAs)
Esl′
Required secondary limiting e.m.f (volts)
6-8
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware Esl′ = k×Ipcf ×Isn×(Rct+Rb)/Ipn k Ipcf
stability factor = 2 Protective checking factor current (amps) Same as the maximum prospective fault current
Isn
Rated secondary current (amps)
Rct
Current transformer secondary winding resistance. (ohms)
Rb
Real resistance burden (ohms) Rb=Rr+2×RL+Rc
Rc
Contact resistance, 0.05-0.1 ohm (ohms)
RL
Resistance of a single lead from relay to current transformer (ohms)
Rr
Impedance of relay phase current input (ohms)
Ipn
Rated primary current (amps)
For example: 1.
Kalf=30, Isn=5A, Rct=1ohm, Sbn=60VA
Esl = kalf×Isn×(Rct+Rbn) = kalf×Isn×(Rct+ Sbn/Isn2) = 30×5×(1+60/25)=510V 2.
Ipcf=40000A, RL=0.5ohm, Rr=0.1ohm, Rc=0.1ohm, Ipn=2000A
Esl′ = 2×Ipcf×Isn×(Rct+Rb)/Ipn = 2×Ipcf ×Isn×(Rct+(Rr+2×RL+Rc))/Ipn = 2×40000×5×(1+(0.1+2×0.5+0.1))/2000=440V Thus, Esl > Esl′
6.3 Plug-in Module Description The device consists of PWR plug-in module, MON plug-in module, DSP plug-in module, AI plug-in module, BI plug-in module, BO plug-in module, CH plug-in module and NET-DSP plug-in module. Terminal definitions and application of each plug-in module are introduced as follows.
6.3.1 PWR Plug-in Module (Power Supply) PWR module is a DC/DC converter with electrical insulation between input and output. It has an input voltage range as described in Chapter 2 “Technical Data”. The standardized output voltages are +5V and +24V DC. The tolerances of the output voltages are continuously monitored. The +5V DC output provides power supply for all the electrical elements that need +5V DC power supply in this device. The use of an external miniature circuit breaker is recommended. The miniature circuit breaker must be in the on position when the device is in operation and in the off position when the device is in cold reserve. A 12-pin connector is fixed on PWR module. The terminal definition of the connector is described
PCS-931 Line Differential Relay
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6 Hardware
as below.
NR1301 5V OK
ALM
BO_ALM BO_FAIL
ON OFF
1
BO_COM1
2
BO_FAIL
3
BO_ALM
4
BO_COM2
5
BO_FAIL
6
BO_ALM
7
OPTO+
8
OPTO-
9 10 PWR+ 11 PWR12 GND
Figure 6.3-1 View of PWR plug-in module
The power switch in the dotted box of above figure maybe is not existed. 01 BO_FAIL 02 BO_ALM 03 04 BO_FAIL 05 BO_ALM 06
Figure 6.3-2 Output contacts of PWR plug-in module
Terminal definition and description is shown as follows: Table 6.3-1 Terminal definition and description of PWR plug-in module Terminal No.
Symbol
Description
01
BO_COM1
Common terminal 1
02
BO_FAIL
Device failure output 1 (01-02, NC)
03
BO_ALM
Device abnormality alarm output 1 (01-03, NO)
04
BO_COM2
Common terminal 2
05
BO_FAIL
Device failure output 2 (04-05, NC)
6-10
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware Terminal No.
Symbol
Description
06
BO_ALM
Device abnormality alarm output 2 (04-06, NO)
07
OPTO+
Positive power supply for BI module (24V)
08
OPTO-
Negative power supply for BI module (24V)
09
Blank
Not used
10
PWR+
Positive input of power supply for the device (250V/220V/125V/110V)
11
PWR-
Negative input of power supply for the device (250V/220V/125V/110V)
12
GND
Grounded connection of the power supply
Note!
The standard rated voltage of PWR module is self-adaptive to 88~300 Vdc. If input voltage is out of range, an alarm signal (Fail_Device) will be issued. For non-standard rated voltage power supply module please specify when place order, and check if the rated voltage of power supply module is the same as the voltage of power source before the device being put into service. PWR module provides terminal 12 and grounding screw for device grounding. Terminal 12 shall be connected to grounding screw and then connected to the earth copper bar of panel via dedicated grounding wire. Effective grounding is the most important measure for a device to prevent EMI, so effective grounding must be ensured before the device is put into service. PCS-931, like almost all electronic relays, contains electrolytic capacitors. These capacitors are well known to be subject to deterioration over time if voltage is not applied periodically. Deterioration can be avoided by powering the relays up once a year.
6.3.2 MON Plug-in Module (Monitor) MON module consists of high-performance built-in processor, FLASH, SRAM, SDRAM, Ethernet controller and other peripherals. Its functions include management of the complete device, human machine interface, communication and waveform recording etc. MON module uses the internal bus to receive the data from other modules of the device. It communicates with the LCD module by RS-485 bus. This module comprises 100BaseT Ethernet interfaces, RS-485 communication interfaces that exchange information with above system by using IEC 61850, PPS/IRIG-B differential time synchronization interface and RS-232 printing interface. Modules with various combinations of memory and interface are available as shown in the table below.
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6 Hardware
NR1102D
NR1102I
NR1101E
TX ETHERNET
ETHERNET
RX TX RX ETHERNET
Figure 6.3-3 View of MON plug-in module Module ID
Memory
Interface
Terminal No.
4 RJ45 Ethernet
RS-485 NR1102D
128M DDR
128M DDR
Physical Layer
To SCADA 01
SYN+
02
SYN-
To
03
SGND
synchronization
clock
Twisted pair wire
04
RS-232
NR1102I
Usage
05
RTS
06
TXD
07
SGND
To printer
Cable
2 RJ45 Ethernet
To SCADA
Twisted pair wire
2 FO Ethernet
To SCADA
Optical fibre ST
RS-485
01
SYN+
02
SYN-
To
03
SGND
synchronization
clock
Twisted pair wire
04
RS-232
05
RTS
06
TXD
07
SGND
2 RJ45 Ethernet NR1101E
128M DDR
RS-485
To printer
Cable
To SCADA 01
A
02
B
03
SGND
6-12
To SCADA
Twisted pair wire
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware 04
RS-485
05
A
06
B
07
SGND
To SCADA
08
RS-485
09
SYN+
10
SYN-
To
SGND
synchronization
11
clock
12
RS-232
13
RTS
14
TXD
15
SGND
To printer
Cable
16
The correct connection is shown in Figure 6.3-4. Generally, the shielded cable with two pairs of twisted pairs inside shall be applied. One pair of the twisted pairs are respectively used to connect the “+” and “–” terminals of difference signal. The other pair of twisted pairs are used to connect the signal ground of the communication interface. The module reserves a free terminal for all the communication ports. The free terminal has no connection with any signal of the device, and it is used to connect the external shields of the cable when connecting multiple devices in series. The external shield of the cable shall be grounded at one of the ends only. Twisted pair wire 01
B
02
SGND
03
COM
A
To the screen of other coaxial cable with single point earthing
04
Twisted pair wire 01
SYN-
02
SGND
03
Clock SYN
SYN+
04
Cable 05
TXD
06
SGND
07
PRINT
RTS
Figure 6.3-4 Connection of communication terminal
6.3.3 AI Plug-in Module (Analog Input) AI module is applicable for power plant or substation with conventional VT and CT. It is assigned to slot numbers 02 and 03. However, the module is not required if the device is used with ECT/EVT. For AI module, if the plug is not put in the socket, external CT circuit is closed itself. Just shown as below.
PCS-931 Line Differential Relay
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6 Hardware
Socket
Plug
In
Out
plug is not put in the socket
In
Out
Put the plug in the socket
Figure 6.3-5 Schematic diagram of CT circuit automatically closed
There are two types of AI module with rating 5 A or 1 A. Please declare which kind of AI module is needed before ordering. Maximum linear range of the current converter is 40In. 1.
One CT group input without synchronism voltage switchover
For one CT group input, three phase currents (Ia, Ib and Ic) and residual current from parallel line (for mutual compensation) are input to AI module separately. Terminal 01, 03, 05 and 07 are polarity marks. It is assumed that polarity mark of CT installed on line is at line side. Three phase voltages (Ua, Ub, and Uc) for protection calculation and one synchronism voltage are input to AI module. The synchronism voltage could be any phase-to-ground voltage or phase-to-phase voltage. If the auto-reclosing is enabled but synchronism check is not required, the synchronism voltage should be disconnected.
6-14
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware A B C
P2
S2
P2
S2
P1
S1
P1
S1
02
01
02
01
04
03
04
03
06
05
06
05
08
07
08
07
Figure 6.3-6 Current connection of AI plug-in module
In order to accurately locate the fault for parallel lines arrangement, residual current from parallel line is required to be connected to the device to eliminate the mutual effect between the parallel lines. Otherwise, residual current from parallel line is not necessary. Relevant description about parallel line to refer to section “Fault Location”.
PCS-931 Line Differential Relay
6-15 Date: 2013-09-07
6 Hardware A B C
13
14
15
16
17
18
19
20
Figure 6.3-7 Voltage connection 1 of AI plug-in module A B C
13
14
15
16
17
18
19
20
Figure 6.3-8 Voltage connection 2 of AI plug-in module
6-16
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware Ia
01
Ian
02
Ib
03
Ibn
04
Ic
05
Icn
06
IM0
07
IM0n
08
NR1401
09
10
11
12
Ua
13
Uan
14
Ub
15
Ubn
16
Uc
17
Ucn
18
Us
19
Usn
20
21
22
23
24
Figure 6.3-9 View of AI plug-in module for one CT group input
Table 6.3-2 lists the terminal number and definition of AI module. Table 6.3-2 Terminal definition of AI module Terminal No.
Definition
Definition
01
Ia
The current of A-phase (Polarity mark)
02
Ian
The current of A-phase
03
Ib
The current of B-phase (Polarity mark)
04
Ibn
The current of B-phase
05
Ic
The current of C-phase (Polarity mark)
06
Icn
The current of C-phase
07
IM0
Residual current of parallel line (Polarity mark)
08
IM0n
Residual current of parallel line
09
Reserve
10
Reserve
11
Reserve
12
Reserve
13
Ua
The voltage of A-phase (Polarity mark)
14
Uan
The voltage of A-phase
15
Ub
The voltage of B-phase (Polarity mark)
16
Ubn
The voltage of B-phase
17
Uc
The voltage of C-phase (Polarity mark)
18
Ucn
The voltage of C-phase
19
Us
Synchronism voltage (Polarity mark)
20
Usn
Synchronism voltage
PCS-931 Line Differential Relay
6-17 Date: 2013-09-07
6 Hardware Terminal No.
2.
Definition
21
Reserve
22
Reserve
23
Reserve
24
Reserve
25
GND
Definition
Ground
Two CT groups input with synchronism voltage switchover
For two circuit breakers configuration with two CT groups input, three phase currents corresponding to CB1 and CB2 respectively (Ia1, Ib1, Ic1 and Ia2, Ib2, Ic2) are input to AI module. Terminal 01, 03, 05, 07, 09 and 11 are polarity marks. It is assumed that polarity mark of CT installed on line is at line side. Three phase voltages (Ua, Ub, and Uc) are input to AI module. UB1, UB2 and UL2 are the synchronism voltage from bus VT and line VT used for synchrocheck, it could be any phase-to-ground voltage or phase-to-phase voltage. The device can automatically switch synchronism voltage according to auxiliary contact of CB position or DS position. If the auto-reclosing is enabled but synchronism check is not required, the synchronism voltage should be disconnected. P2
P1
P1
P2
S1
S2
A B
S2
S1
02
01
04
03
06
05
08
07
10
09
12
11
C
Figure 6.3-10 Current connection of AI plug-in module
6-18
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware A
B
C
A
13
14
15
16
17
18
19
20
21
22
23
24
B
C
Figure 6.3-11 Voltage connection of AI plug-in module
Ia1
01
Ia1n
02
Ib1
03
Ib1n
04
Ic1
05
Ic1n
06
Ia2
07
Ia2n
08
Ib2
09
Ib2n
10
Ic2
11
Ic2n
12
Ua
13
Uan
14
Ub
15
Ubn
16
Uc
17
Ucn
18
UB1
19
UB1n
20
UL2
21
UL2n
22
UB2
23
UB2n
24
NR1401
Figure 6.3-12 View of AI plug-in module for two CT group input
PCS-931 Line Differential Relay
6-19 Date: 2013-09-07
6 Hardware
Table 6.3-3 lists the terminal number and definition of AI module. Table 6.3-3 Terminal definition of AI module Terminal No.
3.
Definition
Definition
01
Ia1
The current of A-phase (Polarity mark)
02
Ia1n
The current of A-phase
03
Ib1
The current of B-phase (Polarity mark)
04
Ib1n
The current of B-phase
05
Ic1
The current of C-phase (Polarity mark)
06
Ic1n
The current of C-phase
07
Ia2
The current of A-phase (Polarity mark)
08
Ia2n
The current of A-phase
09
Ib2
The current of B-phase (Polarity mark)
10
Ib2n
The current of B-phase
11
Ic2
The current of C-phase (Polarity mark)
12
Ic2n
The current of C-phase
13
Ua
The voltage of A-phase (Polarity mark)
14
Uan
The voltage of A-phase
15
Ub
The voltage of B-phase (Polarity mark)
16
Ubn
The voltage of B-phase
17
Uc
The voltage of C-phase (Polarity mark)
18
Ucn
The voltage of C-phase
19
UB1
The voltage of bus 1 (Polarity mark)
20
UB1n
The voltage of bus 1
21
UL2
The voltage of line 2 (Polarity mark)
22
UL2n
The voltage of line 2
23
UB2
The voltage of bus 2 (Polarity mark)
24
UB2n
The voltage of bus 2
25
GND
Ground
Two CT groups input without synchronism voltage switchover
For two circuit breakers configuration with two CT groups input, three phase currents corresponding to CB1 and CB2 respectively (Ia1, Ib1, Ic1 and Ia2, Ib2, Ic2), and residual current from parallel line (for mutual compensation) are input to AI module. Terminal 01, 03, 05, 07, 09, 11 and 13 are polarity marks. It is assumed that polarity mark of CT installed on line is at line side. Three phase voltages (Ua, Ub, and Uc) for protection calculation and one synchronism voltage are input to AI module. The synchronism voltage could be any phase-to-ground voltage or phase-to-phase voltage. If the auto-reclosing is enabled but synchronism check is not required, the synchronism voltage should be disconnected.
6-20
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware P2
P1
P1
P2
S1
S2
A B
S2
S1
02
01
04
03
06
05
08
07
10
09
12
11
14
13
C
To parallel line From parallel line
Figure 6.3-13 Current connection of AI plug-in module A
B
C
A
15
16
17
18
19
20
21
22
23
24
B
C
Figure 6.3-14 Voltage connection of AI plug-in module
PCS-931 Line Differential Relay
6-21 Date: 2013-09-07
6 Hardware Ia1
01
Ia1n
02
Ib1
03
Ib1n
04
Ic1
05
Ic1n
06
Ia2
07
Ia2n
08
Ib2
09
Ib2n
10
Ic2
11
Ic2n
12
IM0
13
IM0n
14
Ua
15
Uan
16
Ub
17
Ubn
18
Uc
19
Ucn
20
Us
21
Usn
22
NR1401
23
24
Figure 6.3-15 View of AI plug-in module for two CT group input
Table 6.3-4 lists the terminal number and definition of AI module. Table 6.3-4 Terminal definition of AI module Terminal No.
Definition
Definition
01
Ia1
The current of A-phase (Polarity mark)
02
Ia1n
The current of A-phase
03
Ib1
The current of B-phase (Polarity mark)
04
Ib1n
The current of B-phase
05
Ic1
The current of C-phase (Polarity mark)
06
Ic1n
The current of C-phase
07
Ia2
The current of A-phase (Polarity mark)
08
Ia2n
The current of A-phase
09
Ib2
The current of B-phase (Polarity mark)
10
Ib2n
The current of B-phase
11
Ic2
The current of C-phase (Polarity mark)
12
Ic2n
The current of C-phase
13
IM0
Residual current of parallel line (Polarity mark)
14
IM0n
Residual current of parallel line
15
Ua
The voltage of A-phase (Polarity mark)
16
Uan
The voltage of A-phase
17
Ub
The voltage of B-phase (Polarity mark)
18
Ubn
The voltage of B-phase
19
Uc
The voltage of C-phase (Polarity mark)
20
Ucn
The voltage of C-phase
6-22
PCS-931 Line Differential Relay Date: 2013-09-07
6 Hardware Terminal No.
Definition
Definition
21
Us
Synchronism voltage (Polarity mark)
22
Usn
Synchronism voltage
23
Reserve
24
Reserve
25
GND
Ground
6.3.4 DSP Plug-in Module (Logic Process)
NR1161
Figure 6.3-16 View of DSP plug-in module
This device can be equipped with 2 DSP plug-in modules at most and 1 DSP plug-in module at least. The default DSP plug-in module is necessary, which mainly is responsible for protection function including fault detector and protection calculation. The default module consists of high-performance double DSP (digital signal processor),16-digit high-accuracy ADC that can perform synchronous sampling and manage other peripherals. One of double DSP is responsible for protection calculation, and can fulfill analog data acquisition, protection logic calculation and tripping output. The other is responsible for fault detector, and can fulfill analog data acquisition, fault detector and providing power supply to output relay. When the module is connected with conventional CT/VT, it can perform the synchronous data acquisition through AI plug-in module. When the module is connected with ECT/EVT, it can receive the real-time synchronous sampled value from merging unit through NET-DSP plug-in module. The other module is optional and it is not required unless control and manual closing with
PCS-931 Line Differential Relay
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6 Hardware
synchronism check are equppied with this device. The default DSP plug-in module is fixed at slot 04 and the option DSP plug-in module is fixed at slot 06.
6.3.5 NET-DSP Plug-in Module (GOOSE and SV)
NR1136A
NR1136C
RX
Figure 6.3-17 View of NET-DSP plug-in module
This module consists of high-performance DSP (digital signal processor), 2~8 100Mbit/s optical-fibre interface (LC type) and selectable IRIG-B interface (ST type). It supports GOOSE and SV by IEC 61850-9-2 protocols. It can receive and send GOOSE messages to intelligent control device, and receive SV from MU (merging unit). This module supports IEEE1588 network time protocol, E2E and P2P defined in IEEE1588 protocol can be selected.This module supports Ethernet IEEE802.3 time adjustment message format, UDP time adjustment message format and GMRP.
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PCS-931 Line Differential Relay Date: 2013-09-07
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6.3.6 CH Plug-in Module (Fibre Optical Channel Interface)
NR1213
NR1213
NR1213
NR1213
NR1214
TX
TX
TX
TX
RX
RX
RX
RX
TX
TX
RX
RX
NR1214
TX1
TX1
RX1
RX1
TX1
RX1
NR1213A
NR1213A-100
NR1213B
NR1213B-100
NR1214A
NR1214B
Figure 6.3-18 View of CH plug-in module Type
Wavelength
Application
NR1213A
1310nm
Single-mode, single channel, transmission distance <40 km
NR1213A-100
1550nm
Single-mode, single channel, transmission distance <100 km
NR1213B
1310nm
Single-mode, dual channels, transmission distance <40 km
NR1213B-100
1550nm
Single-mode, dual channels, transmission distance <100 km
NR1214A
830nm
Multi-mode, single channel, transmission distance <2 km
NR1214B
830nm
Multi-mode, dual channels, transmission distance <2 km
PCS-931 series can exchange information with the device at the remote end through a dedicated optical fibre channel or multiplex channel. The module transmits and receives optical signal using FC/PC or ST optical connector. The parameters are shown as follows: Item
Type1
Type2
Type3
Fiber Optic
Single mode, Rec.G652
Single mode, Rec.G652
Multi mode, Rec.G652
Wavelength
1310nm
1550nm
830nm
Transmission power
-13.0±3.0 dBm
-5.0 dBm±3.0 dBm
-12dBm~-20 dBm
Receiving sensitivity
Min.-37 dBm
Min.-36 dBm
Min.-30 dBm
Transmission distance
Max.40 km
Max.100 km
Max.2 km
Optical overload point
Min.-3 dBm
Min.-3 dBm
Min.-8 dBm
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6 Hardware
Note!
When using dedicated optical fibre channel, if the transmission distance is longer than 50km, the transmitted power may be enchanced to ensure received power larger than receiving sensitivity. Please notify supplier before ordering and it will be considered as special project using 1550nm laser diode. When using multiplex channel, the sending power of the device is fixed. When using channel multiplexing equipment, the parameters are shown as follows: 1.
Channel type: digital optical fibre or digital microwave.
2.
Interface standard: 2048kbit/s E1
The device′s requirements on the channel are shown as follows: 1.
The routine of both direction shall be same to each other, so the time delays of both direction are the same.
2.
The maximum one-way channel propagation delay shall be less than 15 ms.
6.3.7 BI Plug-in Module (Binary Input) There are two kinds of BI modules available, NR1503 and NR1504. Up to 3 BI modules can be equipped with one device. The rated voltage can be selected to be 110V/125V, 220V/250V. The well-designed debouncing technique is adopted in this device, and the state change of binary input within “Debouncing time” will be ignored. As shown in Figure 6.3-19.
Figure 6.3-19 Debouncing technique
Each BI module is with a 22-pin connector for 11 binary inputs (NR1503) or 18 binary inputs (NR1504). For NR1503, each binary input has independent negative power input of opto-coupler, and can be 6-26
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6 Hardware
configurable. The terminal definition of the connector of BI plug-in module is described as below. [BI_n] (n=01, 02,…,11 can be configured as a specified binary input by PCS-Explorer software.)
NR1503
BI_01
01
Opto01-
02
BI_02
03
Opto02-
04
BI_03
05
Opto03-
06
BI_04
07
Opto04-
08
BI_05
09
Opto05-
10
BI_06
11
Opto06-
12
BI_07
13
Opto07-
14
BI_08
15
Opto08-
16
BI_09
17
Opto09-
18
BI_10
19
Opto10-
20
BI_11
21
Opto11-
22
Figure 6.3-20 View of BI plug-in module (NR1503)
Terminal description for NR 1503 is shown as follows. Terminal No.
Symbol
Description
01
BI_01
Configurable binary input 1
02
Opto01-
Negative supply of configurable binary input 1
03
BI_02
Configurable binary input 2
04
Opto02-
Negative supply of configurable binary input 2
05
BI_03
Configurable binary input 3
06
Opto03-
Negative supply of configurable binary input 3
07
BI_04
Configurable binary input 4
08
Opto04-
Negative supply of configurable binary input 4
09
BI_05
Configurable binary input 5
10
Opto05-
Negative supply of configurable binary input 5
11
BI_06
Configurable binary input 6
12
Opto06-
Negative supply of configurable binary input 6
13
BI_07
Configurable binary input 7
14
Opto07-
Negative supply of configurable binary input 7
15
BI_08
Configurable binary input 8
16
Opto08-
Negative supply of configurable binary input 8
17
BI_09
Configurable binary input 9
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6 Hardware Terminal No.
Symbol
Description
18
Opto09-
Negative supply of configurable binary input 9
19
BI_10
Configurable binary input 10
20
Opto10-
Negative supply of configurable binary input 10
21
BI_11
Configurable binary input 11
22
Opto11-
Negative supply of configurable binary input 11
For NR1504, all binary inputs share one common negative power input, and is configurable. The terminal definition of the connector of BI plug-in module is described as below. [BI_n] (n=01, 02,…,18 can be configured as a specified binary input by PCS-Explorer software.)
NR1504
Opto+
01
BI_01
02
BI_02
03
BI_03
04
BI_04
05
BI_05
06
BI_06
07 08
BI_07
09
BI_08
10
BI_09
11
BI_10
12
BI_11
13
BI_12
14 15
BI_13
16
BI_14
17
BI_15
18
BI_16
19
BI_17
20
BI_18
21
COM-
22
Figure 6.3-21 View of BI plug-in module (NR1504)
Terminal description for NR1504 is shown as follows. Terminal No.
Symbol
Description
01
Opto+
Positive supply of power supply of the module
02
BI_01
Configurable binary input 1
03
BI_02
Configurable binary input 2
04
BI_03
Configurable binary input 3
05
BI_04
Configurable binary input 4
06
BI_05
Configurable binary input 5
07
BI_06
Configurable binary input 6
08
Blank
Not used
09
BI_07
Configurable binary input 7
10
BI_08
Configurable binary input 8
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6 Hardware Terminal No.
Symbol
Description
11
BI_09
Configurable binary input 9
12
BI_10
Configurable binary input 10
13
BI_11
Configurable binary input 11
14
BI_12
Configurable binary input 12
15
Blank
Not used
16
BI_13
Configurable binary input 13
17
BI_14
Configurable binary input 14
18
BI_15
Configurable binary input 15
19
BI_16
Configurable binary input 16
20
BI_17
Configurable binary input 17
21
BI_18
Configurable binary input 18
22
COM-
Common terminal of negative supply of binary inputs
First four binary signals (BI_01, BI_02, BI_03, BI_04) in first BI plug-in module are fixed, they are [BI_TimeSyn], [BI_Print], [BI_Maintenance] and [BI_RstTarg] respectively. 1.
Binary input: [BI_TimeSyn]
It is used to receive clock synchronization signal from clock synchronization device, the binary input [BI_TimeSyn] will change from “0” to “1” once pulse signal is received. When the device adopts “Conventional” mode as clock synchronization mode (refer to section “Communication Settings”), the device can receives PPM (pulse per minute) and PPS (pulse per second). If the setting [Opt_TimeSyn] is set as other values, this binary input is invalid. 2.
Binary input: [BI_Print]
It is used to manually trigger printing latest report when the equipment is configured as manual printing mode by logic setting [En_AutoPrint]=0. The printer button is located on the panel usually. If the equipment is configured as automatic printing mode ([En_AutoPrint]=1), report will be printed automatically as soon as it is formed. 3.
Binary input: [BI_Maintenance]
It is used to block communication export when this binary input is energized. During device maintenance or testing, this binary input is then energized not to send reports via communication port, local display and printing still work as usual. This binary input should be de-energized when the device is restored back to normal. The application of the binary input [BI_Maintenance] for digital substation communication adopting IEC61850 protocol is given as follows. 1)
Processing mechanism for MMS (Manufacturing Message Specification) message a)
The protection device should send the state of this binary input to client.
b)
When this binary input is energized, the bit “Test” of quality (Q) in the sent message changes to “1”.
c)
When this binary input is energized, the client cannot control the isolator link and circuit
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6 Hardware
breaker, modify settings and switch setting group remotely. d)
2)
3)
4.
According to the value of the bit “Test” of quality (Q) in the message sent, the client discriminate whether this message is maintenance message, and then deal with it correspondingly. If the message is the maintenance message, the content of the message will not be displayed on real-time message window, audio alarm not issued, but the picture is refreshed so as to ensure that the state of the picture is in step with the actual state. The maintenance message will be stored, and can be inquired, in independent window.
Processing mechanism for GOOSE message a)
When this binary input is energized, the bit “Test” in the GOOSE message sent by the protection device changes to “1”.
b)
For the receiving end of GOOSE message, it will compare the value of the bit “Test” in the GOOSE message received by it with the state of its own binary input (i..e [BI_Maintenance]), the message will be thought as invalid unless they are conformable.
Processing mechanism for SV (Sampling Value) message a)
When this binary input of merging unit is energized, the bit “Test” of quality (Q) of sampling data in the SV message sent change “1”.
b)
For the receiving end of SV message, if the value of bit “Test” of quality (Q) of sampling data in the SV message received is “1”, the relevant protection functions will be disabled, but under maintenance state, the protection device should calculate and display the magnitude of sampling data.
c)
For duplicated protection function configurations, all merging units of control module configured to receive sampling should be also duplicated. Both dual protection devices and dual merging units should be fully independent each other, and one of them is in maintenance state will not affect the normal operation of the other.
Binary input: [BI_RstTarg]
It is used to reset latching signal relay and LCD displaying. The reset is done by pressing a button on the panel.
Note!
The rated voltage of binary input is optional: 110V, 125V, 220V or 250V, which must be specified when placed order. It is necessary to check whether the rated voltage of BI module complies with site DC supply rating before put the relay in service. There three binary signals are fixed for measurement functions, they are [BI_Rmt/Loc], [BI_ManSynCls] and [BI_ManOpen] respectively. 5.
Binary input: [BI_Rmt/Loc]
It is used to select the remote control or the local control. 6-30
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“1”: the remote control, all the binary outputs can only be remotely controlled by SCADA or control centers. “0” the local control, each binary output can only be applied to open/close CB/DS/ES locally. Each binary output can also be applied issue a signal locally. 6.
Binary input: [BI_ManSynCls]
When the device is under local control condition (i.e. [BI_Rmt/Loc] is de-energized), the manual synchronism check for closing circuit breaker will be initiated if it is energized. 7.
Binary input: [BI_ManOpen]
When the device is under local control condition (i.e. [BI_Rmt/Loc] is de-energized), the manual control for open circuit breaker will be initiated if it is energized.
6.3.8 BO Plug-in Module (Binary Output) Three standard binary output modules, NR1521A and NR1521C, and one optional binary output module, NR1521F, can be selected. The contacts provided by NR1521A, NR1521C and NR1521F are all normally open (NO) contacts. Output contact can be configured as a specified tripping output contact and a signal output contact respectively by PCS-Explorer software according to user requirement. NR1521A can provide 11 output contacts controlled by fault detector.
BO_01 NR1521A
BO_02
BO_03
BO_04
BO_05
BO_06
BO_07
BO_08
BO_09
BO_10
BO_11
01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22
Figure 6.3-22 View of BO plug-in module (NR1521A)
NR1521C can provide 11 output contacts without controlled by fault detector.
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BO_01 NR1521C
BO_02
BO_03
BO_04
BO_05
BO_06
BO_07
BO_08
BO_09
BO_10
BO_11
01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22
Figure 6.3-23 View of BO plug-in module (NR1521C)
BO plug-in module (NR1521F) is dedicatedly for remote/manual open or closing to circuit breaker, disconnector and earth switch. 5 pairs of binary outputs (one for open and the other for closing) can be provided by this BO plug-in module configured in slot 15 if measurement and control function is equipped with the device. Up to 10 pairs of binary outputs can be provided by two BO plug-in modules that can be configured in slot 14 and 15 respectively. (BO plug-in module configured in slot 14 is optional if open or closing contacts is not enough) A normally open contact is presented via terminal 21-22 designated as ROS (i.e. remote operation signal). Whenever any of binary output contacts for open or closing is closed, ROS contact will close to issue a signal indicating that this device is undergoing a remote operation. BO plug-in module (NR1521F) is displayed as shown in the following figure.
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6 Hardware
BO_CtrlOpn01 NR1521F
BO_CtrlCls01
BO_CtrlOpn02
BO_CtrlCls02
BO_CtrlOpn03
BO_CtrlCls03
BO_CtrlOpn04
BO_CtrlCls04
BO_CtrlOpn05
BO_CtrlCls05
BO_Ctrl
01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22
Figure 6.3-24 View of BO plug-in module (NR1521F)
6.3.9 HMI Module The display panel consists of liquid crystal display module, keyboard, LED and ARM processor. The functions of ARM processor include display control of the liquid crystal display module, keyboard processing, and exchanging data with the CPU through LAN port etc. The liquid crystal display module is a high-performance grand liquid crystal panel with soft back lighting, which has a user-friendly interface and an extensive display range.
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7 Settings
7 Settings Table of Contents 7 Settings .............................................................................................. 7-a 7.1 Communication Settings ................................................................................ 7-1 7.1.1 Setting Description............................................................................................................... 7-2 7.1.2 Access Path ......................................................................................................................... 7-6
7.2 System Settings .............................................................................................. 7-6 7.2.1 Setting Description............................................................................................................... 7-6 7.2.2 Access Path ......................................................................................................................... 7-7
7.3 Device Settings ............................................................................................... 7-7 7.3.1 Setting Description............................................................................................................... 7-7 7.3.2 Access Path ......................................................................................................................... 7-8
7.4 Protection Settings ......................................................................................... 7-8 7.4.1 Setting Description............................................................................................................... 7-8 7.4.2 Access Path ....................................................................................................................... 7-28
7.5 Logic Link Settings ....................................................................................... 7-28 7.5.1 Setting Description............................................................................................................. 7-29 7.5.2 Access Path ....................................................................................................................... 7-29
7.6 Measurement and Control Settings ............................................................. 7-29 7.6.1 Setting Description............................................................................................................. 7-29 7.6.2 Access Path ....................................................................................................................... 7-31
List of Tables Table 7.1-1 Communication settings ......................................................................................... 7-1 Table 7.2-1 System settings ....................................................................................................... 7-6 Table 7.3-1 Device settings......................................................................................................... 7-7
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7-b
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7 Settings
The device has some setting groups for protection to coordinate with the mode of power system operation, one of which is assigned to be active. However, communication settings, system settings, device settings, logic link settings and measurement and control settings are common for all protection setting groups. Note! All current settings in this chapter are secondary current converted from primary current by CT ratio. Zero-sequence current or voltage setting is configured according to 3I0 or 3U0 and negative sequence current setting according to I2 or U2.
7.1 Communication Settings Table 7.1-1 Communication settings No.
Item
Range
1
IP_LAN1
000.000.000.000~255.255.255.255
2
Mask_LAN1
000.000.000.000~255.255.255.255
3
IP_LAN2
000.000.000.000~255.255.255.255
4
Mask_LAN2
000.000.000.000~255.255.255.255
5
En_LAN2
0 or 1
6
IP_LAN3
000.000.000.000~255.255.255.255
7
Mask_LAN3
000.000.000.000~255.255.255.255
8
En_LAN3
0 or 1
9
IP_LAN4
000.000.000.000~255.255.255.255
10
Mask_LAN4
000.000.000.000~255.255.255.255
11
En_LAN4
0 or 1
12
Gateway
000.000.000.000~255.255.255.255
13
En_Broadcast
0 or 1
14
Addr_RS485A
0~255
15
Baud_RS485A
4800,9600,19200,38400,57600,115200 (bps)
16
Protocol_RS485A
0, 1 or 2
17
Addr_RS485B
0~255
18
Baud_RS485B
4800,9600,19200,38400,57600,115200 (bps)
19
Protocol_RS485B
0, 1 or 2
20
Threshold_Measmt
0~100%
21
Period_Measmt
0~65535s
22
Format_Measmt
0, 1
23
Baud_Printer
4800,9600,19200,38400,57600,115200 (bps)
24
En_AutoPrint
0 or 1
25
Opt_TimeSyn
Conventional, SAS, Advanced or NoTImeSyn
26
IP_Server_SNTP
000.000.000.000~255.255.255.255
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7 Settings No.
Item
Range
27
IP_StandbyServer_SNTP
000.000.000.000~255.255.255.255
28
OffsetHour_UTC
-12~+12 (hrs)
29
OffsetMinute_UTC
0~60 (min)
30
Opt_Display_Status
PriValue, SecValue
31
t_Dly_Net_DNP
0~10000 (ms)
32
Fmt_Setting_DNP
0, 1, 2
7.1.1 Setting Description 1.
IP_LAN1, IP_LAN2, IP_LAN3, IP_LAN4
IP address of Ethernet port 1, Ethernet port 2, Ethernet port 3 and Ethernet port 4 2.
Mask_LAN1, Mask_LAN2, Mask_LAN3, Mask_LAN4
Subnet mask of Ethernet port 1, Ethernet port 2, Ethernet port 3 and Ethernet port 4 3.
En_LAN2, En_LAN3, En_LAN4
Put Ethernet port 2, Ethernet port 3 and Ethernet port 4 in service They are used for Ethernet communication based on the IEC 60870-5-103 protocol. When the IEC 61850 protocol is applied, the IP address of Ethernet A will be GOOSE source MAC address. Ethernet port 1 is always in service by default.
4.
Gateway
IP address of Gateway (router)
5.
En_Broadcast
This setting is only used only for IEC 60870-5-103 protocol. If NR network IEC 60870-5-103 protocol is used, the setting must be set as “1”. 0: the device does not send UDP messages through network 1: the device sends UDP messages through network 6.
Addr_RS485A, Addr_RS485B
They are the device′s communication address used to communicate with the SCADA or RTU via serial ports (port A and port B). 7.
Baud_RS485A, Baud_RS485B
Baud rate of rear RS-485 serial port A or B 8.
Protocol_RS485A, Protocol_RS485B
Communication protocol of rear RS-485 serial port A or B 0: IEC 60870-5-103 protocol
7-2
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7 Settings
1: Modbus Protocol 2: Reserved Note! Above table listed all the communication settings, the device delivered to the user maybe only show some settings of them according to the communication interface configuration. If only the Ethernet ports are applied, the settings about the serial ports (port A and port B) are not listed in this submenu. And the settings about the Ethernet ports only listed in this submenu according to the actual number of Ethernet ports. The standard arrangement of the Ethernet port is two, at most four (predetermined when ordering). Set the IP address according to actual arrangement of Ethernet numbers and the un-useful port/ports need not be configured. If PCS-Explorer configuration tool auxiliary software is connected with this device through the Ethernet, the IP address of PCS-Explorer must be set as one of the available IP address of this device.
9.
Threshold_Measmt
Threshold value of sending measurement values to SCADA through IEC 60870-5-103 or IEC61850 protocol. Default value: “1%”
10. Period_Measmt The time period for equipment sends measurement data to SCADA through IEC 60870-5-103 protocol. Default value: “60”
11. Format_Measmt The setting is used to select the format of measurement data sent to SCADA through IEC 60870-5-103 protocol. 0: GDD data type through IEC103 protocol is 12 1: GDD data type through IEC103 protocol is 7, i.e. 754 short real number of IEEE standard 12. Baud_Printer Baud rate of printer port 13. En_AutoPrint If automatic print is required for fault report after protection operating, it is set as “1”. Otherwise, it should be set to “0”. 14. Opt_TimeSyn There are four selections for clock synchronization of device shown as follow.
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Conventional
PPS (RS-485): Pulse per second (PPS) via RS-485 differential level IRIG-B (RS-485): IRIG-B via RS-485 differential level PPM (DIN): Pulse per minute (PPM) via the binary input [BI_TimeSyn] PPS (DIN): Pulse per second (PPS) via the binary input [BI_TimeSyn]
SAS
SNTP (PTP): Unicast (point-to-point) SNTP mode via Ethernet network SNTP (BC): Broadcast SNTP mode via Ethernet network Message (IEC103): Clock messages through IEC103 protocol
Advanced
IEEE1588: Clock message via IEEE1588 IRIG-B (Fiber): IRIG-B via optical-fibre interface PPS (Fiber) PPS: Pulse per second (PPS) via optical-fibre interface
NoTimeSync
When no time synchronization signal is connected to the device, please select this option and the alarm message [Alm_TimeSyn] will not be issued anymore. “Conventional” mode and “SAS” mode are always be supported by the device, but “Advanced” mode is only supported when NET-DSP module is equipped. The alarm signal [Alm_TimeSyn] may be issued to remind user loss of time synchronization signals. 1)
When “SAS” is selected, if there is no conventional clock synchronization signal, the device will not send the alarm signal [Alm_TimeSyn]. When “Conventional” mode is selected, if there is no conventional clock synchronization signal, “SAS” mode will be enabled automatically with the alarm signal [Alm_TimeSyn] issued simultaneously.
2)
When “Advanced” mode is selected, if there is no conventional clock synchronization signal connected to NET-DSP module, “SAS” mode is enabled automatically with the alarm signal [Alm_TimeSyn] issued simultaneously.
3)
When “NoTimeSyn” mode is selected, the device will not send alarm signals without time synchronization signal. But the device can be still synchronized if receiving time synchronization signal. Note! The clock message via IEC 60870-5-103 protocol is invalid when the device receives the IRIG-B signal through RCS-485 port.
15. IP_Server_SNTP 7-4
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7 Settings
It is the address of the SNTP time synchronization server which sends SNTP timing messages to the relay or BCU. 16. IP_StandbyServer_SNTP Both [IP_Server_SNTP] and [IP_StandbyServer_SNTP] are inefffective unless SNTP clock synchronization is valid. When both [IP_Server_SNTP] and [IP_StandbyServer_SNTP] are set as “000.000.000.000”, the deivce receives broadcast SNTP synchronization message. When either [IP_Server_SNTP] or [IP_StandbyServer_SNTP] is set as “000.000.000.000”, the deivce adopt the setting whose value is not equal to “000.000.000.000” as SNTP server address and the deivce receives unicast SNTP synchronization message. When neither [IP_Server_SNTP] nor [IP_StandbyServer_SNTP] are set as “000.000.000.000”, the deivce adopt the setting [IP_Server_SNTP] as SNTP server address to receive unicast SNTP synchronization message. If the device does not receive the server responses after 30s, the deivce adopt the setting [IP_StandbyServer_SNTP] as SNTP server address to receive unicast SNTP synchronization message. The device will switch between [IP_Server_SNTP] and [IP_StandbyServer_SNTP] repeatedly if the device always can not receive the server responses waiting 30s 17. OffsetHour_UTC, OffsetMinute_UTC If the IEC61850 protocol is adopted in substations, the time tags of communication messages are required according to UTC (Universal Time Coordinated) time. The setting [OffsetHour_UTC] is used to set the hour offset of the current time zone to the GMT (Greenwich Mean Time) zone; for example, if a relay is applied in China, the time zone of China is east 8th time zone, so this setting is set as “8”. The setting [OffsetMinute_UTC] is used to set the minute offset of the current time zone to the GMT zone. Time zone Setting Time zone Setting Time zone Setting Time zone Setting
st
GMT zone
East 1
0
1 th
2 th
East 6
East 7
6
7 th
West 1
12/-12
-1
East 8
West 2
East 9
rd
West 3 -3
th
th
East 4 4
th
9 nd
-2 th
rd
East 3 3
th
8 st
East/West 12 th
nd
East 2
5 th
East 10
East 11th
10
11 th
West 4 -4
th
th
East 5
th
West 5 -5
th
th
West 6
West 7
West 8
West 9
West 10
West 11
-6
-7
-8
-9
-10
-11
18. Opt_Display_Status This setting is used to set display mode of current and voltage in fault records, primary value or secondary value. The sampled values of current and voltage are displayed as secondary value by default. When it is set as primary value, both secondary voltage and secondary current are converted into primary voltage and primary current according to rated secondary and primary value of VT and CT respectively.
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19. t_Dly_Net_DNP The setting is used to set transmission time delay for transmitting multi-frame messages during DNP process (the setting is valid only if network DNP3.0 protocol is configured) 20. Format_Setting_DNP The setting is used to set settings uploading format during DNP process (this setting is valid only if network or serial port DNP3.0 protocol is configured). 0: not upload settings 1: uploading settings adopts the mode of analog output 2: uploading settings adopts the mode of analog input
7.1.2 Access Path MainMenu“Settings”“Device Setup”“Comm Settings”
7.2 System Settings Table 7.2-1 System settings No.
Item
Unit
Range
1
Active_Grp
1~10
2
Opt_SysFreq
50 or 60
3
PrimaryEquip_Name
Maximum 12 character
4
U1n
33~65500
kV
5
U2n
80~220
V
6
I1n
100~65500
A
7
I2n
1 or 5
A
8
f_High_FreqAlm
50~65
Hz
9
f_Low_FreqAlm
45~60
Hz
Hz
7.2.1 Setting Description 1.
Active_Grp
The number of active setting group, 10 setting groups can be configured for protection settings, and only one is active at a time 2.
PrimaryEquip_Name
It is recognized by the device automatically. Such setting is used for printing messages 3.
Opt_SysFreq
It is option of system frequency, and can be set as 50Hz or 60Hz 4.
Un1
7-6
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Primary rated voltage of VT 5.
Un2
Secondary rated voltage of VT 6.
In1
Primary rated current of CT 7.
In2
Secondary rated current of CT 8.
f_High_FreqAlm
It is frequency upper limit setting.The device will issue an alarm [Alm_Freq], when system frequency is higher than the setting. 9.
f_Low_FreqAlm
It is frequency lower limit setting.The device will issue an alarm [Alm_Freq], when system frequency is lower than the setting.
7.2.2 Access Path MainMenu“Settings”“System Settings”
7.3 Device Settings Table 7.3-1 Device settings No.
Item
Range
1
HDR_EncodeMode
GB18030, UTF-8
2
Opt_Caption_103
0, 1 or 2
3
Bxx.Un_BinaryInput
24V, 30V, 48V, 110V, 125V, 220V
7.3.1 Setting Description 1.
HDR_EncodeMode
Select encoding format of header (HDR) file COMTRADE recording file Default value is “UTF-8”. 2.
Opt_Caption_103
Select the caption language sent to SAS via IEC103 protocol 0: Current language 1: Fixed Chinese 2: Fixed English Default value of [Opt_Caption_103] is 0 (i.e. current language), and please set it to 1 (i.e. Fixed PCS-931 Line Differential Relay
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7 Settings
Chinese) if the SAS is supplied by China Manufacturer. 3.
Bxx.Un_BinaryInput
This setting is used to set voltage level of binary input module. If low-voltage BI module is equipped, 24V, 30V or 48V can be set according to the actual requirement, and if high-voltage BI module is equipped, 110V, 125V or 220V can be set according to the actual requirement. Bxx: this plug-in module is inserted in slot xx.
7.3.2 Access Path MainMenu“Settings”“Device Setup”“Device Settings”
7.4 Protection Settings All protection settings are based on secondary ratings of VT and CT. Unn: rated secondary phase-to-phase voltage Un: rated secondary phase-to-ground voltage In: rated secondary current
7.4.1 Setting Description 7.4.1.1 Line Parameters No.
Item
Remark
Range
1
X1L
Positive sequence reactance of the line
(0.000~4Unn)/In (ohm)
2
R1L
Positive sequence resistance of the line
(0.000~4Unn)/In (ohm)
3
X0L
Zero-sequence reactance of the line
(0.000~4Unn)/In (ohm)
4
R0L
Zero-sequence resistance of the line
(0.000~4Unn)/In (ohm)
5
X0M
Line mutual zero-sequence reactance
(0.000~4Unn)/In (ohm)
6
R0M
Line mutual zero-sequence resistance
(0.000~4Unn)/In (ohm)
7
LineLength
Total length of the line
0.00~655.35 (km)
8
phi1_Reach
Phase angle of line positive sequence impedance
30.00~89.00 (Deg)
9
Real_K0
10
Imag_K0
Resistive
component
of
zero-sequence
of
zero-sequence
compensation coefficient Imaginary
component
compensation coefficient
-4.000~4.000
-4.000~4.000
7.4.1.2 Fault Detector Settings (FD) No.
Item
Remark
Range
1
FD.DPFC.I_Set
Current setting of DPFC current FD element
(0.050~30.000)×In (A)
2
FD.ROC.3I0_Set
Current setting of neutral current FD element
(0.050~30.000)×In (A)
7-8
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings
7.4.1.3 Auxiliary Element (Aux.E) No.
Item
1
AuxE.OCD.t_DDO
2
AuxE.OCD.En
3
AuxE.ROC1.3I0_Set
4
AuxE.ROC1.En
5
AuxE.ROC2.3I0_Set
6
AuxE.ROC2.En
7
AuxE.ROC3.3I0_Set
8
AuxE.ROC3.En
9
AuxE.OC1.I_Set
Remark
Range
Dropp-off time delay of current change auxiliary element Enable current change auxiliary element
0 or 1
Current setting of stage 1 residual current auxiliary element Enable stage 1 residual current auxiliary element Current setting of stage 2 residual current
0.000~10.000 (s)
auxiliary
element Enable stage 2 residual current auxiliary element Current setting of stage 3 residual current auxiliary element Enable stage 3 residual current auxiliary element Current setting of stage 1 phase current auxiliary element Enable stage 1 phase current auxiliary element
(0.050~30.000)×In (A) 0 or 1 (0.050~30.000)×In (A) 0 or 1 (0.050~30.000)×In (A) 0 or 1 (0.050~30.000)×In (A)
10
AuxE.OC1.En
11
AuxE.OC2.I_Set
12
AuxE.OC2.En
13
AuxE.OC3.I_Set
14
AuxE.OC3.En
Enable stage 3 phase current auxiliary element
0 or 1
15
AuxE.UVD.U_Set
Voltage setting for voltage change auxiliary element
0~Un (V)
16
AuxE.UVD.t_DDO
17
AuxE.UVD.En
18
AuxE.UVG.U_Set
19
AuxE.UVG.En
20
AuxE.UVS.U_Set
21
AuxE.UVS.En
22
AuxE.ROV.3U0_Set
Voltage setting for residual voltage auxiliary element
0~Un (V)
23
AuxE.ROV.En
Enable residual voltage auxiliary element
0 or 1
Current setting of stage 2 phase current auxiliary element Enable stage 2 phase current auxiliary element Current setting of stage 3 phase current auxiliary element
Drop-off time delay of voltage change auxiliary element Enable voltage change auxiliary element Voltage setting for phase-to-ground under voltage auxiliary element Enable phase-to-ground under voltage auxiliary element Voltage setting for phase-to-phase under voltage auxiliary element Enable phase-to-phase under voltage auxiliary element
0 or 1 (0.050~30.000)×In (A) 0 or 1 (0.050~30.000)×In (A)
0.000~10.000 (s) 0 or 1 0~Un (V)
0 or 1
0~Unn (V)
0 or 1
7.4.1.4 DPFC Distance Protection Settings (21D) No.
Item
Remark
Range
1
21D.Z_DPFC
Impedance setting of DPFC distance protection
(0.000~4Unn)/In (ohm)
2
21D.En_DPFC
Enable DPFC distance protection
0 or 1
PCS-931 Line Differential Relay
7-9 Date: 2014-02-24
7 Settings
7.4.1.5 Load Encroachment Settings (LoadEnch) No.
Item
1
LoadEnch.phi_Blinder
Remark
Range
Angle setting of load trapezoid characteristic, it should be set according to the maximum load area angle 0~45 (Deg) (φLoad_Max), φLoad_Max+5°is recommended. Resistance setting of load trapezoid characteristic, it 2
LoadEnch.R_Blinder
should be set according to the minimum load resistance, 70%~90% minimum load resistance is
(0.05~200)/In (ohm)
recommended. 3
LoadEnch.En
Enable load trapezoid characteristic
0 or 1
7.4.1.6 Distance Protection Settings with Mho Characteristic (21M) No.
Item
1
21M.ZG.phi_Shift
2
21M.ZP.phi_Shift
3
21M.ZG1.Z_Set
4
21M.ZG1.t_Op
5
21M.ZG1.En
6
21M.ZG1.En_BlkAR
7
21M.ZP1.Z_Set
8
21M.ZP1.t_Op
9
21M.ZP1.En
10
21M.ZP1.En_BlkAR
11
21M.ZG2.Z_Set
12
21M.ZG2.t_Op
13
21M.ZG2.t_ShortDly
14
21M.ZG2.En
15
21M.ZG2.En_BlkAR
16
21M.ZP2.Z_Set
Remark
Range
Phase shift of zone 1, 2 of phase-to-ground distance protection Phase shift of zone 1, 2 of phase-to-phase distance protection Impedance setting of zone 1 of phase-to-ground distance protection Time delay of zone 1 of phase-to-ground distance protection
0, 15 or 30 (Deg)
0, 15 or 30 (Deg)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
Enable zone 1 of phase-to-ground distance protection 0 or 1 Enable phase-to-ground zone 1 of distance protection operation to block AR Impedance setting of zone 1 of phase-to-phase distance protection Time delay of zone 1 of phase-to-phase distance protection
0 or 1
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
Enable zone 1 of phase-to-phase distance protection 0 or 1 Enable phase-to-phase zone 1 of distance protection operation to block AR Impedance setting of zone 2 of phase-to-ground distance protection Time delay of zone 2 of phase-to-ground distance protection Short time delay of zone 2 of phase-to-ground distance protection
0 or 1
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
0.000~10.000 (s)
Enable zone 2 of phase-to-ground distance protection 0 or 1 Enable phase-to-ground zone 2 of distance protection operation to block AR Impedance setting of zone 2 of phase-to-phase distance protection
7-10
0 or 1
(0.000~4Unn)/In (ohm)
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings Time delay of zone 2 of phase-to-phase distance
17
21M.ZP2.t_Op
18
21M.ZP2.t_ShortDly
19
21M.ZP2.En
20
21M.ZP2.En_BlkAR
21
21M.Z2.En_ShortDly
22
21M.ZG3.Z_Set
23
21M.ZG3.t_Op
24
21M.ZG3.t_ShortDly
25
21M.ZG3.En
26
21M.ZG3.En_BlkAR
27
21M.ZP3.Z_Set
28
21M.ZP3.t_Op
29
21M.ZP3.t_ShortDly
30
21M.ZP3.En
31
21M.ZP3.En_BlkAR
32
21M.Z3.En_ShortDly
33
21M.Z4.Z_Fwd
34
21M.Z4.Z_Rev
35
21M.Z4.t_Op
Time delay of zone 4 of distance protection
0.000~10.000 (s)
36
21M.ZG4.En
Enable zone 4 of phase-to-ground distance element
0 or 1
37
21M.ZG4.En_BlkAR
38
21M.ZP4.En
39
21M.ZP4.En_BlkAR
protection Short time delay of zone 2 of phase-to-phase distance protection
0.000~10.000 (s)
0.000~10.000 (s)
Enable zone 2 of phase-to-phase distance protection 0 or 1 Enable phase-to-phase zone 2 of distance protection operation to block AR
0 or 1
Enable fixed accelerate zone 2 of distance protection 0 or 1 Impedance setting of zone 3 of phase-to-ground distance protection Time delay of zone 3 of phase-to-ground distance protection Short time delay of zone 3 of phase-to-ground distance protection
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
0.000~10.000 (s)
Enable zone 3 of phase-to-ground distance protection 0 or 1 Enable phase-to-ground zone 3 of distance protection operation to block AR Impedance setting of zone 3 of phase-to-phase distance protection Time delay of zone 3 of phase-to-phase distance protection Short time delay of zone 3 of phase-to-phase distance protection
0 or 1
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
0.000~10.000 (s)
Enable zone 3 of phase-to-phase distance protection 0 or 1 Enable phase-to-phase zone 3 of distance protection operation to block AR
0 or 1
Enable fixed accelerate zone 3 of distance protection 0 or 1 Impedance setting of zone 4 of pilot positive distance protection Impedance setting of zone 4 of pilot reversal distance protection
Enable phase-to-ground zone 4 of distance protection operation to block AR
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0 or 1
Enable zone 4 of phase-to-phase distance protection 0 or 1 Enable phase-to-phase zone 4 of distance protection operation to block AR
0 or 1
7.4.1.7 Distance Protection Settings with Quad Characteristic (21Q) No. 1
Item 21Q.ZG1.RCA
Remark Downward offset angle of the reactance line for zone 1 of phase-to-ground distance protection
PCS-931 Line Differential Relay
Range 0~45 (Deg)
7-11 Date: 2014-02-24
7 Settings 2
21Q.ZG1.Z_Set
3
21Q.ZG1.R_Set
4
21Q.ZG1.t_Op
5
21Q.ZG1.En
6
21Q.ZG1.En_BlkAR
7
21Q.ZP1. RCA
8
21Q.ZP1.Z_Set
9
21Q.ZP1.R_Set
10
21Q.ZP1.t_Op
11
21Q.ZP1.En
12
21Q.ZP1.En_BlkAR
13
21Q.ZG2.RCA
14
21Q.ZG2.Z_Set
15
21Q.ZG2.R_Set
16
21Q.ZG2.t_Op
17
21Q.ZG2.t_ShortDly
18
21Q.ZG2.En
19
21Q.ZG2.En_BlkAR
20
21Q.ZP2. RCA
21
21Q.ZP2.Z_Set
22
21Q.ZP2.R_Set
23
21Q.ZP2.t_Op
24
21Q.ZP2.t_ShortDly
Impedance setting of zone 1 of phase-to-ground distance protection Resistance setting of zone 1 of phase-to-ground distance protection Time delay of zone 1 of phase-to-ground distance protection
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
Enable zone 1 of phase-to-ground distance protection 0 or 1 Enable phase-to-ground zone 1 of distance protection operation to block AR Downward offset angle of the reactance line for zone 1 of phase-to-phase distance protection Impedance setting of zone 1 of phase-to-phase distance protection Resistance setting of zone 1 of phase-to-phase distance protection Time delay of zone 1 of phase-to-phase distance protection
0 or 1
0~45 (Deg)
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
Enable zone 1 of phase-to-phase distance protection 0 or 1 Enable phase-to-phase zone 1 of distance protection operation to block AR Downward offset angle of the reactance line for zone 2 of phase-to-ground distance protection Impedance setting of zone 2 of phase-to-ground distance protection Resistance setting of zone 2 of phase-to-ground distance protection Time delay of zone 2 of phase-to-ground distance protection Short time delay of zone 2 of phase-to-ground distance protection
0 or 1
0~45 (Deg)
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
0.000~10.000 (s)
Enable zone 2 of phase-to-ground distance protection 0 or 1 Enable phase-to-ground zone 2 of distance protection operation to block AR Downward offset angle of the reactance line for zone 2 of phase-to-phase distance protection Impedance setting of zone 2 of phase-to-phase distance protection Resistance setting of zone 2 of phase-to-phase distance protection Time delay of zone 2 of phase-to-phase distance protection Short time delay of zone 2 of phase-to-phase distance protection
7-12
0 or 1
0~45 (Deg)
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
0.000~10.000 (s)
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings 25
21Q.ZP2.En
26
21Q.ZP2.En_BlkAR
27
21Q.Z2.En_ShortDly
28
21Q.ZG3.RCA
29
21Q.ZG3.Z_Set
30
21Q.ZG3.R_Set
31
21Q.ZG3.t_Op
32
21Q.ZG3.t_ShortDly
33
21Q.ZG3.En
34
21Q.ZG3.En_BlkAR
35
21Q.ZP3. RCA
36
21Q.ZP3.Z_Set
37
21Q.ZP3.R_Set
38
21Q.ZP3.t_Op
39
21Q.ZP3.t_ShortDly
40
21Q.ZP3.En
41
21Q.ZP3.En_BlkAR
42
21Q.Z3.En_ShortDly
43
21Q.ZG4.RCA
44
21Q.ZG4.Z_Set
45
21Q.ZG4.R_Set
46
21Q.ZG4.t_Op
47
21Q.ZG4.En
48
21Q.ZG4.En_BlkAR
Enable zone 2 of phase-to-phase distance protection 0 or 1 Enable phase-to-phase zone 2 of distance protection operation to block AR
0 or 1
Enable fixed accelerate zone 2 of distance protection 0 or 1 Downward offset angle of the reactance line for zone 3 of phase-to-ground distance protection Impedance setting of zone 3 of phase-to-ground distance protection Resistance setting of zone 3 of phase-to-ground distance protection Time delay of zone 3 of phase-to-ground distance protection Short time delay of zone 3 of phase-to-ground distance protection
0~45 (Deg)
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
0.000~10.000 (s)
Enable zone 3 of phase-to-ground distance protection 0 or 1 Enable phase-to-ground zone 3 of distance protection operation to block AR Downward offset angle of the reactance line for zone 3 of phase-to-phase distance protection Impedance setting of zone 3 of phase-to-phase distance element Resistance setting of zone 3 of phase-to-phase distance protection Time delay of zone 3 of phase-to-phase distance protection Short time delay of zone 3 of phase-to-phase distance protection
0 or 1
0~45 (Deg)
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
0.000~10.000 (s)
Enable zone 3 of phase-to-phase distance protection 0 or 1 Enable phase-to-phase zone 3 of distance protection operation to block AR
0 or 1
Enable fixed accelerate zone 3 of distance protection 0 or 1 Downward offset angle of the reactance line for zone 4 of phase-to-ground distance protection Impedance setting of zone 4 of phase-to-ground distance protection Resistance setting of zone 4 of phase-to-ground distance protection Time delay of zone 4 of phase-to-ground distance protection
0~45 (Deg)
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
Enable zone 4 of phase-to-ground distance protection 0 or 1 Enable phase-to-ground zone 4 of distance protection operation to block AR
PCS-931 Line Differential Relay
0 or 1
7-13 Date: 2014-02-24
7 Settings 49
21Q.ZP4. RCA
50
21Q.ZP4.Z_Set
51
21Q.ZP4.R_Set
52
21Q.ZP4.t_Op
53
21Q.ZP4.En
54
21Q.ZP4.En_BlkAR
Downward offset angle of the reactance line for zone 4 of phase-to-phase distance protection Impedance setting of zone 4 of phase-to-phase distance protection Resistance setting of zone 4 of phase-to-phase distance protection Time delay of zone 4 of phase-to-phase distance protection
0~45 (Deg)
(0.000~4Unn)/In (ohm)
(0.000~4Unn)/In (ohm)
0.000~10.000 (s)
Enable zone 4 of phase-to-phase distance protection 0 or 1 Enable phase-to-phase zone 4 of distance protection operation to block AR
0 or 1
7.4.1.8 Power Swing Detection Settings (68) No. 1
Item 68.En
Remark
Range
Enable power swing detection
0 or 1
7.4.1.9 Power Swing Blocking Releasing Settings (PSBR) No.
Item
1
21M.Z1.En_PSBR
2
21Q.Z1.En_PSBR
3
21M.Z2.En_PSBR
4
21Q.Z2.En_PSBR
5
21M.Z3.En_PSBR
6
21Q.Z3.En_PSBR
7
21M.I_PSBR
8
21Q.I_PSBR
Remark
Range
Enable PSBR for zone 1 of distance element (Mho Characteristic) Enable PSBR for zone 1 of distance element (Quad Characteristic) Enable PSBR for zone 2 of distance element (Mho Characteristic) Enable PSBR for zone 2 of distance element (Quad Characteristic) Enable PSBR for zone 3 of distance element (Mho Characteristic) Enable PSBR for zone 3 of distance element (Quad Characteristic) Current setting of PSBR (Mho Characteristic)
0 or 1
0 or 1
0 or 1
0 or 1
0 or 1
0 or 1 (0.050~30.000)×In (A)
Current setting for power swing blocking (Quad Characteristic)
(0.050~30.000)×In (A)
7.4.1.10 Distance SOTF Protection Settings (21SOTF) No. 1
Item 21SOTF.En
Remark
Range
Enable accelerating distance protection to trip
0 or 1
Enable stage 2 of accelerating distance protection 2
21SOTF.Z2.En_ManCls
to trip when manual closing or auto-reclosing onto 0 or 1 an existing fault Enable stage 3 of accelerating distance protection
3
21SOTF.Z3.En_ManCls
to trip when manual closing or auto-reclosing onto 0 or 1 an existing fault
7-14
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings Enable stage 4 of accelerating distance protection 4
21SOTF.Z4.En_ManCls
to trip when manual closing or auto-reclosing onto 0 or 1 an existing fault
5
21SOTF.Z2.En_3PAR
Enable 3-pole auto-reclosing mode for zone 2
0 or 1
6
21SOTF.Z3.En_3PAR
Enable 3-pole auto-reclosing mode for zone 3
0 or 1
7
21SOTF.Z4.En_3PAR
Enable 3-pole auto-reclosing mode for zone 4
0 or 1
8
21SOTF.Z2.En_PSBR
Enable PSBR for zone 2 of distance element
0 or 1
9
21SOTF.Z3.En_PSBR
Enable PSBR for zone 3 of distance element
0 or 1
10
21SOTF.Z4.En_PSBR
Enable PSBR for zone 4 of distance element
0 or 1
Enable accelerating distance protection to trip 11
21SOTF.En_PDF
when fault occurs on healthy phase under pole 0 or 1 discrepancy situation Time delay of accelerating distance protection to
12
21SOTF.t_PDF
trip when fault occurs on healthy phase under pole 0.000~10.000 (s) discrepancy situation
13
SOTF.Opt_Mode_ManCls
Option of manual SOTF mode
0, 1 or 2
7.4.1.11 Optical Pilot Channel Settings No.
Item
Remark
Range
1
FO.LocID
Indentity code of the device at local end
0-65535
2
FO.RmtID
Indentity code of the device at remote end
0-65535
3
FO.Protocol
It is used to select protocol type, G.703 or C37.94 G.703 or C37.94
4
FO.BaudRate
Baud rate of optical pilot channel
64 or 2048
5
FOx.En_IntClock
Option of internal clock or external clock
0 or 1
6
FOx.En
Enable channel x
0 or 1
7.4.1.12 Current Differential Protection Settings (87) No.
Item
Remark Minimum
pickup
current
Range setting
of
current
1
87L.I_Pkp
2
87L.K_Cr_CT
3
87L.I_Pkp_CTS
4
87L.XC1L
5
87L.XC0L
Zero-sequence capacitive impedance of the line
(40~65535)/In (ohm)
6
87L.Z_LocReac
Impedance setting of reactor of local line
(40~65535)/In (ohm)
7
87L.Z_LocGndReac
Impedance setting of ground reactor of local line
(40~65535)/In (ohm)
8
87L.Z_RmtReac
Impedance setting of reactor of remote line
(40~65535)/In (ohm)
9
87L.Z_RmtGndReac
10
87L.En
differential protection Current ratio factor of CT Current setting of differential protection when CT circuit failure Positive-sequence capacitive impedance of the line
Impedance setting of ground reactor of remote line Enable differential protection
PCS-931 Line Differential Relay
(0.050~30.000)×In (A) 0.200~10.000 (0.050~30.000)×In (A)
(40~65535)/In (ohm)
(40~65535)/In (ohm) 0 or 1
7-15 Date: 2014-02-24
7 Settings Enable stage 1 of DPFC current differential
11
87L.En_DPFC1
12
87L.En_DPFC2
13
87L.En_Biased1
14
87L.En_Biased2
15
87L.En_Neutral
Enable neutral current differential element
0 or 1
16
87L.En_InterTrp
Enable inter-tripping element
0 or 1
element Enable stage 2 of DPFC current differential element Enable stage 1 of steady-state current differential element Enable stage 2 of steady-state current differential element
0 or 1
0 or 1
0 or 1
0 or 1
Enable local independent current differential 17
87L.En_LocDiff
protection
(independent
current
differential
protection
means
current
differential 0 or 1
local
protection can operate without permissive signal from remote end) 18
87L.En_CapCurrComp
19
87L.En_CTS_Blk
Enable capacitive current compensation
0 or 1
Enable current differential protection blocked during CT circuit failure
0 or 1
7.4.1.13 Current Direction Settings No.
Item
Remark
Range
The characteristic angle of directional phase
1
RCA_OC
2
RCA_ROC
3
RCA_NegOC
4
Z0_Comp
5
Z2_Comp
overcurrent element The characteristic angle of directional earth fault element The
characteristic
angle
of
directional
negative-sequence overcurrent element Zero-sequence compensation impedance setting Negative-sequence
compensation
impedance
setting
30.00~89.00 (Deg)
30.00~89.00 (Deg)
30.00~89.00 (Deg) (0.000~4Unn)/In (ohm) (0.000~4Unn)/In (ohm)
7.4.1.14 Phase Overcurrent Protection (50/51P) No.
Item
1
50/51P.K_Hm2
2
50/51P1.I_Set
3
50/51P1.t_Op
4
50/51P1.En
5
50/51P1.En_BlkAR
Remark
Range
Setting of second harmonic component for blocking phase overcurrent elements Current setting for stage 1 of phase overcurrent protection Time delay for stage 1 of phase overcurrent protection Enable stage 1 of phase overcurrent protection Enable auto-reclosing blocked when stage 1 of phase overcurrent protection operates
7-16
0.000~1.000
(0.050~30.000)×In (A)
0.000~20.000 (s) 0 or 1 0 or 1
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings 6
50/51P1.Opt_Dir
7
50/51P1.En_Hm2_Blk
8
50/51P1.Opt_Curve
9
50/51P1.TMS
10
50/51P1.tmin
Direction option for stage 1 of phase overcurrent protection Enable second harmonic blocking for stage 1 of phase overcurrent protection Option of characteristic curve for stage 1 of phase overcurrent protection Time multiplier setting for stage 1 of inverse-time phase overcurrent protection Minimum
50/51P1.Alpha
time
for
stage
1
of
inverse-time phase overcurrent protection Constant
11
operating “α”
for
stage
inverse-time characteristic
1
of
0, 1 or 2
0 or 1
0~13
0.010~200.000
0.000~20.000 (s)
customized
phase overcurrent 0.010~5.000
protection Constant 12
50/51P1.C
“C”
for
stage
inverse-time characteristic
1
of
customized
phase overcurrent 0.000~200.000
protection Constant 13
50/51P1.K
“K”
for
stage
inverse-time characteristic
1
of
customized
phase overcurrent 0.050~20.000
protection 14
50/51P2.I_Set
15
50/51P2.t_Op
16
50/51P2.En
17
50/51P2.En_BlkAR
18
50/51P2.Opt_Dir
19
50/51P2.En_Hm2_Blk
20
50/51P2.Opt_Curve
21
50/51P2.TMS
22
50/51P2.tmin
23
50/51P3.I_Set
24
50/51P3.t_Op
25
50/51P3.En
26
50/51P3.En_BlkAR
Current setting for stage 2 of phase overcurrent protection Time delay for stage 2 of phase overcurrent protection Enable stage 2 of phase overcurrent protection
phase overcurrent protection operates Direction option for stage 2 of phase overcurrent protection Enable second harmonic blocking for stage 2 of phase overcurrent protection Option of characteristic curve for stage 2 of phase overcurrent protection Time multiplier setting for stage 2 of inverse-time phase overcurrent protection. operating
time
for
stage
2
of
inverse-time phase overcurrent protection Current setting for stage 3 of phase overcurrent protection Time delay for stage 3 of phase overcurrent protection Enable stage 3 of phase overcurrent protection Enable auto-reclosing blocked when stage 3 of phase overcurrent protection operates
PCS-931 Line Differential Relay
0.000~20.000 (s) 0 or 1
Enable auto-reclosing blocked when stage 2 of
Minimum
(0.050~30.000)×In (A)
0 or 1
0, 1 or 2
0 or 1
0~12
0.010~200.000
0.000~20.000 (s)
(0.050~30.000)×In (A)
0.000~20.000 (s) 0 or 1 0 or 1
7-17 Date: 2014-02-24
7 Settings 27
50/51P3.Opt_Dir
28
50/51P3.En_Hm2_Blk
29
50/51P3.Opt_Curve
30
50/51P3.TMS
31
50/51P3.tmin
32
50/51P4.I_Set
33
50/51P4.t_Op
34
50/51P4.En
35
50/51P4.En_BlkAR
36
50/51P4.Opt_Dir
37
50/51P4.En_Hm2_Blk
38
50/51P4.Opt_Curve
39
50/51P4.TMS
40
50/51P4.tmin
Direction option for stage 3 of phase overcurrent protection Enable second harmonic blocking for stage 3 of phase overcurrent protection Option of characteristic curve for stage 3 of phase overcurrent protection Time multiplier setting for stage 3 of inverse-time phase overcurrent protection. Minimum
operating
time
for
stage
3
of
inverse-time phase overcurrent protection Current setting for stage 4 of phase overcurrent protection Time delay for stage 4 of phase overcurrent protection Enable stage 4 of phase overcurrent protection
phase overcurrent protection operates Direction option for stage 4 of phase overcurrent protection Enable second harmonic blocking for stage 4 of phase overcurrent protection Option of characteristic curve for stage 4 of phase overcurrent protection Time multiplier setting for stage 4 of inverse-time phase overcurrent protection. operating
time
for
stage
4
0 or 1
0~12
0.010~200.000
0.000~20.000 (s)
(0.050~30.000)×In (A)
0.000~20.000 (s) 0 or 1
Enable auto-reclosing blocked when stage 4 of
Minimum
0, 1 or 2
of
inverse-time phase overcurrent protection
0 or 1
0, 1 or 2
0 or 1
0~12
0.010~200.000
0.010~20.000 (s)
7.4.1.15 Direction Earth Fault Protection Settings (50/51G) No.
Item
Remark
Range
Setting of second harmonic component for
1
50/51G.K_Hm2
2
50/51G1.3I0_Set
Current setting for stage 1 of earth fault protection (0.050~30.000)×In (A)
3
50/51G1.t_Op
Time delay for stage 1 of earth fault protection
0.000~20.000 (s)
4
50/51G1.En
Enable stage 1 of earth fault protection
0 or 1
5
50/51G1.En_BlkAR
6
50/51G1.Opt_Dir
7
50/51G1.En_Hm2_Blk
8
50/51G1.En_Abnor_Blk
blocking earth fault elements
Enable auto-reclosing blocked when stage 1 of earth fault protection operates Direction option for stage 1 of earth fault protection Enable second harmonic blocking for stage 1 of earth fault protection Enable blocking for stage 1 of earth fault protection under abnormal conditions
7-18
0.000~1.000
0 or 1
0, 1 or 2
0 or 1
0 or 1
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings 9
50/51G1.En_CTS_Blk
Enable blocking for stage 1 of earth fault protection under CT failure conditions Option of characteristic curve for stage 1 of earth
0 or 1
10
50/51G1.Opt_Curve
11
50/51G1.TMS
12
50/51G1.tmin
13
50/51G1.Alpha
14
50/51G1.C
15
50/51G1.K
16
50/51G2.3I0_Set
Current setting for stage 2 of earth fault protection (0.050~30.000)×In (A)
17
50/51G2.t_Op
Time delay for stage 2 of earth fault protection
0.000~20.000 (s)
18
50/51G2.En
Enable stage 2 of earth fault protection
0 or 1
19
50/51G2.En_BlkAR
20
50/51G2.Opt_Dir
21
50/51G2.En_Hm2_Blk
22
50/51G2.En_Abnor_Blk
23
50/51G2.En_CTS_Blk
24
50/51G2.Opt_Curve
25
50/51G2.TMS
26
50/51G2.tmin
27
50/51G3.3I0_Set
Current setting for stage 3 of earth fault protection (0.050~30.000)×In (A)
28
50/51G3.t_Op
Time delay for stage 3 of earth fault protection
0.000~20.000 (s)
29
50/51G3.En
Enable stage 3 of earth fault protection
0, 1 or 2
30
50/51G3.En_BlkAR
31
50/51G3.Opt_Dir
32
50/51G3.En_Hm2_Blk
fault protection Time multiplier setting for stage 1 of inverse-time earth fault protection Minimum
operating
time
for
stage
1
of
inverse-time earth fault protection Constant
“α”
for
stage
1
of
customized
inverse-time characteristic earth fault protection Constant
“C”
for
stage
1
of
customized
inverse-time characteristic earth fault protection Constant
“K”
for
stage
1
of
customized
inverse-time characteristic earth fault protection
Enable auto-reclosing blocked when stage 2 of earth fault protection operates Direction option for stage 2 of earth fault protection Enable second harmonic blocking for stage 2 of earth fault protection Enable blocking for stage 2 of earth fault protection under abnormal conditions Enable blocking for stage 2 of earth faultv protection under CT failure conditions Option of characteristic curve for stage 2 of earth fault protection Time multiplier setting for stage 2 of inverse-time earth fault protection Minimum
operating
time
for
stage
2
of
inverse-time earth fault protection
Enable auto-reclosing blocked when stage 3 of earth fault protection operates Direction option for stage 3 of earth fault protection Enable second harmonic blocking for stage 3 of earth fault protection
PCS-931 Line Differential Relay
0~13
0.010~200.000
0.050~20.000 (t)
0.010~5.000
0.000~20.000
0.050~20.000
0 or 1
0, 1 or 2
0 or 1
0 or 1
0 or 1
0~12
0.010~200.000
0.050~20.000 (s)
0 or 1
0 or 1
0 or 1
7-19 Date: 2014-02-24
7 Settings Enable blocking for stage 3 of earth fault
33
50/51G3.En_Abnor_Blk
34
50/51G3.En_CTS_Blk
35
50/51G3.Opt_Curve
36
50/51G3.TMS
37
50/51G3.tmin
38
50/51G4.3I0_Set
Current setting for stage 4 of earth fault protection (0.050~30.000)×In (A)
39
50/51G4.t_Op
Time delay for stage 4 of earth fault protection
0.000~20.000 (s)
40
50/51G4.En
Enable stage 4 of earth fault protection
0, 1 or 2
41
50/51G4.En_BlkAR
42
50/51G4.Opt_Dir
43
50/51G4.En_Hm2_Blk
44
50/51G4.En_Abnor_Blk
45
50/51G4.En_CTS_Blk
46
50/51G4.Opt_Curve
47
50/51G4.TMS
48
50/51G4.tmin
protection under abnormal conditions Enable blocking for stage 3 of earth fault protection under CT failure conditions Option of characteristic curve for stage 3 of earth fault protection Time multiplier setting for stage 3 of inverse-time earth fault protection Minimum
operating
time
for
stage
3
of
inverse-time earth fault protection
Enable auto-reclosing blocked when stage 4 of earth fault protection operates Direction option for stage 4 of earth fault protection Enable second harmonic blocking for stage 4 of earth fault protection Enable blocking for stage 4 of earth fault protection under abnormal conditions Enable blocking for stage 4 of earth fault protection under CT failure conditions Option of characteristic curve for stage 4 of earth fault protection Time multiplier setting for stage 4 of inverse-time earth fault protection Minimum
operating
time
for
stage
4
of
inverse-time earth fault protection
0 or 1
0 or 1
0~12
0.010~200.000
0.050~20.000 (s)
0 or 1
0 or 1
0 or 1
0 or 1
0 or 1
0~12
0.010~200.000
0.050~20.000 (s)
7.4.1.16 Overcurrent Protection Settings for VT Circuit Failure (50PVT/50GVT) No.
Item
1
50PVT.I_Set
2
50PVT.t_Op
3
50PVT.En
4
50GVT.3I0_Set
5
50GVT.t_Op
6
50GVT.En
Remark
Range
Current setting of phase overcurrent protection when VT circuit failure Time delay of phase overcurrent protection when VT circuit failure Enable phase overcurrent protection when VT circuit failure Current setting of ground overcurrent protection when VT circuit failure Time delay of ground overcurrent protection when VT circuit failure Enable ground overcurrent protection when VT
7-20
(0.050~30.000)×In (A)
0.000~10.000 (s)
0 or 1
(0.050~30.000)×In (A)
0.000~10.000 (s) 0 or 1
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings circuit failure
7.4.1.17 Residual Current SOTF Protection Settings (50GSOTF) No.
Item
1
50GSOTF.3I0_Set
2
50GSOTF.En_3I0
Remark Current
setting
of
Range
residual
current
SOTF
protection Enable residual current SOTF protection
(0.050~30.000)×In (A) 0 or 1
7.4.1.18 Overvoltage Protection Settings (59P) No.
Item
Remark
Range
1
59P1.U_Set
Voltage setting for stage 1 of overvoltage protection
Un~2Unn (V)
2
59P1.t_Op
Time delay for stage 1 of overvoltage protection
0.000~30.000 (s)
3
59P1.En
Enable stage 1 of overvoltage protection
0 or 1
4
59P1.Opt_1P/3P
Option of 1-out-of-3 mode or 3-out-of-3 mode
0 or 1
5
59P1.Opt_Up/Upp
Option of phase-to-phase voltage or phase voltage
0 or 1
6
59P1.En_Alm
7
59P1.En_52b_TT
8
59P1.En_TT
9
59P1.Opt_Curve
Enable stage 1 of overvoltage protection for alarm purpose Enable transfer trip controlled by CB open position for stage 1 of overvoltage protection Enable stage 1 of overvoltage protection operate to initiate transfer trip Option of characteristic curve for stage 1 of overvoltage protection Time multiplier setting for stage 1 of inverse-time
0 or 1
0 or 1
0 or 1
0~12
10
59P1.TMS
11
59P1.tmin
12
59P2.U_Set
Voltage setting for stage 2 of overvoltage protection
Un~2Unn (V)
13
59P2.t_Op
Time delay for stage 2 of overvoltage protection
0.000~30.000 (s)
14
59P2.En
Enable stage 2 of overvoltage protection
0 or 1
15
59P2.Opt_1P/3P
Option of 1-out-of-3 mode or 3-out-of-3 mode
0 or 1
16
59P2.Opt_Up/Upp
Option of phase-to-phase voltage or phase voltage
0 or 1
17
59P2.En_Alm
18
59P2.En_52b_TT
19
59P2.En_TT
20
59P2.Opt_Curve
21
59P2.TMS
overvoltage protection Minimum
delay
for
stage
1
of
inverse-time
overvoltage protection
Enable stage 2 of overvoltage protection for alarm purpose Enable transfer trip controlled by CB open position for stage 2 of overvoltage protection Enable stage 2 of overvoltage protection operate to initiate transfer trip Option of characteristic curve for stage 2 of overvoltage protection Time multiplier setting for stage 2 of inverse-time overvoltage protection
PCS-931 Line Differential Relay
0.010~200.000
0.050~20.000 (s)
0 or 1
0 or 1
0 or 1
0~12
0.010~200.000
7-21 Date: 2014-02-24
7 Settings 22
Minimum
59P2.tmin
delay
for
stage
2
of
inverse-time
overvoltage protection
0.050~20.000 (s)
7.4.1.19 Undervoltage Protection Settings (27P) No.
Item
Remark
Range
1
27P1.U_Set
Voltage setting for stage 1 of undervoltage protection
0~Unn (V)
2
27P1.t_Op
Time delay for stage 1 of undervoltage protection
0.000~30.000 (s)
3
27P1.En
Enable stage 1 of undervoltage protection
0 or 1
4
27P1.Opt_1P/3P
Option of 1-out-of-3 mode or 3-out-of-3 mode
0 or 1
5
27P1.Opt_Up/Upp
6
27P1.En_Alm
7
27P1.Opt_Curve
8
27P1.TMS
9
27P1.tmin
Option of voltage criterion adopting phase-to-phase voltage or phase voltage Enable stage 1 of undervoltage protection operate to alarm Option of characteristic curve for stage 1 of undervoltage protection Time multiplier setting for stage 1 of inverse-time undervoltage protection Minimum
delay
for
stage
1
of
inverse-time
undervoltage protection
0 or 1
0 or 1
0~12
0.010~200.000
0.050~20.000 (s)
10
27P2.U_Set
Voltage setting for stage 2 of undervoltage protection 0~Unn (V)
11
27P2.t_Op
Time delay for stage 2 of undervoltage protection
0.000~30.000 (s)
12
27P2.En
Enable stage 2 of undervoltage protection
0 or 1
13
27P2.Opt_1P/3P
Option of 1-out-of-3 mode or 3-out-of-3 mode
0 or 1
14
27P2.Opt_Up/Upp
15
27P2.En_Alm
16
27P2.Opt_Curve
17
27P2.TMS
18
27P2.tmin
Option of voltage criterion adopting phase-to-phase voltage or phase voltage Enable stage 2 of undervoltage protection operate to alarm Option of characteristic curve for stage 2 of undervoltage protection Time multiplier setting for stage 2 of inverse-time undervoltage protection Minimum
delay
for
stage
2
of
inverse-time
undervoltage protection
0 or 1
0 or 1
0~12
0.010~200.000
0.050~20.000 (s)
7.4.1.20 Frequency Protection Settings (81U and 81O) No.
Item
1
81U.f_Pkp
2
81U.df/dt_Blk
3
81U.UF1.f_Set
4
81U.UF1.t_Op
Remark Frequency
pickup
setting
Range for
underfrequency
protection Rate
of
frequency
change
for
blocking
underfrequency protection Frequency setting for stage 1 of underfrequency protection Time delay for stage 1 of underfrequency protection
7-22
45.000~60.000 (Hz)
0.200~20.000 (Hz/s)
45.000~60.000 (Hz) 0.050~30.000 (s)
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings 5
81U.UF1.En
Enable stage 1 of underfrequency protection
0 or 1
6
81U.UF1.En_df/dt_Blk
7
81U.UF2.f_Set
8
81U.UF2.t_Op
Time delay for stage 2 of underfrequency protection
0.050~30.000 (s)
9
81U.UF2.En
Enable stage 2 of underfrequency protection
0 or 1
Enable rate of frequency change to block stage 1 of underfrequency protection Frequency setting for stage 2 of underfrequency protection
Enable rate of frequency change to block stage 2 of
0 or 1
45.000~60.000 (Hz)
10
81U.UF2.En_df/dt_Blk
11
81U.UF3.f_Set
12
81U.UF3.t_Op
Time delay for stage 3 of underfrequency protection
0.050~30.000 (s)
13
81U.UF3.En
Enable stage 3 of underfrequency protection
0 or 1
14
81U.UF3.En_df/dt_Blk
15
81U.UF4.f_Set
16
81U.UF4.t_Op
Time delay for stage 4 of underfrequency protection
0.050~30.000 (s)
17
81U.UF4.En
Enable stage 4 of underfrequency protection
0 or 1
18
81U.UF4.En_df/dt_Blk
19
81O.f_Pkp
20
81O.OF1.f_Set
21
81O.OF1.t_Op
Time delay for stage 1 of overfrequency protection
0.050~20.000 (s)
22
81O.OF1.En
Enable stage 1 of overfrequency protection
0 or 1
23
81O.OF2.f_Set
24
81O.OF2.t_Op
Time delay for stage 2 of overfrequency protection
0.050~20.000 (s)
25
81O.OF2.En
Enable stage 2 of overfrequency protection
0 or 1
26
81O.OF3.f_Set
27
81O.OF3.t_Op
Time delay for stage 3 of overfrequency protection
0.050~20.000 (s)
28
81O.OF3.En
Enable stage 3 of overfrequency protection
0 or 1
29
81O.OF4.f_Set
30
81O.OF4.t_Op
Time delay for stage 4 of overfrequency protection
0.050~20.000 (s)
31
81O.OF4.En
Enable stage 4 of overfrequency protection
0 or 1
underfrequency protection Frequency setting for stage 3 of underfrequency protection
Enable rate of frequency change to block stage 3 of underfrequency protection Frequency setting for stage 4 of underfrequency protection
Enable rate of frequency change to block stage 4 of underfrequency protection
0 or 1
45.000~60.000 (Hz)
0 or 1
45.000~60.000 (Hz)
0 or 1
Frequency pickup setting for overfrequency protection 50.000~65.000 (Hz) Frequency setting for stage 1 of overfrequency protection
Frequency setting for stage 2 of overfrequency protection
Frequency setting for stage 3 of overfrequency protection
Frequency setting for stage 4 of overfrequency protection
50.000~65.000 (Hz)
50.000~65.000 (Hz)
50.000~65.000 (Hz)
50.000~65.000 (Hz)
7.4.1.21 Breaker Failure Protection Settings (50BF) No. 1
Item 50BF.I_Set
Remark
Range
Current setting of phase current criterion for BFP
(0.050~30.000 )×In (A)
PCS-931 Line Differential Relay
7-23 Date: 2014-02-24
7 Settings 2
50BF.3I0_Set
Current setting of zero-sequence current criterion (0.050~30.000 )×In (A) for BFP
3
50BF.I2_Set
Current setting of negative-sequence current (0.050~30.000 )×In (A) criterion for BFP
4
50BF.t_ReTrp
Time delay of re-tripping for BFP
0.000~10.000 (s)
5
50BF.t1_Op
Time delay of stage 1 for BFP
0.000~10.000 (s)
6
50BF.t2_Op
Time delay of stage 2 for BFP
0.000~10.000 (s)
7
50BF.En
Enable breaker failure protection
0 or 1
8
50BF.En_ReTrp
Enable re-trip function for BFP
0 or 1
9
50BF.En_3I0_1P
Enable zero-sequence current criterion for BFP 0 or 1 initiated by single-phase tripping contact
10
50BF.En_3I0_3P
Enable zero-sequence current criterion for BFP 0 or 1 initiated by three-phase tripping contact
11
50BF.En_I2_3P
Enable negative-sequence current criterion for 0 or 1 BFP initiated by three-phase tripping contact
12
50BF.En_CB_Ctrl
Enable breaker failure protection can be initiated 0 or 1 by normally closed contact of circuit breaker
7.4.1.22 Thermal Overload Protection (49) No.
Item
Remark
Range
The factor setting for stage 1 of thermal overload protection which is associated to the thermal 1.000~3.000 state formula The factor setting for stage 2 of thermal overload protection which is associated to the thermal 1.000~3.000 state formula
1
49-1.K
2
49-2.K
3
49.Ib_Set
4
49.Tau
5
49-1.En_Alm
6
49-1.En_Trp
7
49-2.En_Alm
8
49-2.En_Trp
The reference current setting of the thermal overload protection The time constant setting of the IDMT overload protection Enable stage 1 of thermal overload protection for alarm purpose Enable stage 1 of thermal overload protection for trip purpose
(0.050~30.000 )×In (A) 0.100~100.000 (min) 0 or 1 0 or 1
Enable stage 2 of thermal overload protection for 0 or 1 alarm purpose Enable stage 2 of thermal overload protection for 0 or 1 trip purpose
7.4.1.23 Stub Overcurrent Protection (50STB) No.
Name
Remark
Range
1
50STB.I_Set
Current setting of stub overcurrent protection
(0.050~30.000)×In (A)
2
50STB.t_Op
Time delay of stub overcurrent protection
0.000~10.000 (s)
3
50STB.En
Enable stub overcurrent protection
0 or 1
7-24
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings
7.4.1.24 Dead Zone Protection (50DZ) No.
Name
Remark
Range
1
50DZ.I_Set
Current setting of dead zone protection
(0.050~30.000)×In (A)
2
50DZ.t_Op
Time delay of dead zone protection
0.000~10.000 (s)
3
50DZ.En
Enable dead zone protection
0 or 1
7.4.1.25 Pole Discrepancy Protection Settings (62PD) No.
Item
Remark
Range
Current setting of residual current criterion for pole
1
62PD.3I0_Set
2
62PD.I2_Set
3
62PD.t_Op
Time delay of pole discrepancy protection
0.000~600.000 (s)
4
62PD.En
Enable pole discrepancy protection
0 or 1
discrepancy protection Current
setting
62PD.En_3I0/I2_Ctrl
negative-sequence
current
criterion for pole discrepancy protection
Enable 5
of
residual
negative-sequence
current current
criterion
criterion
for
(0.050~30.000 )×In (A)
(0.050~30.000 )×In (A)
and pole 0 or 1
discrepancy protection
7.4.1.26 Broken Conductor Protection (46BC) No.
Item
Remark Ratio
1
46BC.I2/I1_Set
setting
(negative-sequence
Range current
to
positive-sequence current) of broken conductor 0.20~1.00 protection
2
46BC.t_Op
3
46BC.I_Min
4
46BC.En_Trp
5
46BC.En_Alm
Time delay of broken conductor protection
0.000~600.000 (s)
Minimum operation current of broken conductor (0.050~30.000)×In (A)
protection Enable broken conductor protection to operate to
0 or 1
trip Enable broken conductor protection to operate to
0 or 1
alarm
7.4.1.27 Reverse Power Protection (32R) No.
Item
Remark
Range
Power setting of stage 1 of reverse power
1
32R1.P_Set
2
32R1.t_Alm
3
32R1.t_Trp
4
32R1.En_Trp
(0.100~50.000)×In (W)
protection Time delay of stage 1 of reverse power protection for alarm purpose
0.100~3000.000 (s)
Time delay of stage 1 of reverse power protection for tripping purpose
0.100~3000.000 (s)
Enable stage 1 of reverse power protection to 0 or 1
operate to trip
PCS-931 Line Differential Relay
7-25 Date: 2014-02-24
7 Settings Enable stage 1 of reverse power protection to
5
32R1.En_Alm
6
32R2.P_Set
7
32R2.t_Trp
8
32R2.En_Trp
9
32R.Opt_Dir
0 or 1
operate to alarm Power setting of stage 2 of reverse power
(0.100~50.000)×In (W)
protection
Time delay of stage 2 of reverse power protection 0.100~3000.000 (s) Enable stage 2 of reverse power protection to 0 or 1
operate to alarm The
directionality
option
of
reverse
power 0: forward direction
protection
1: reverse direction
7.4.1.28 Synchrocheck Settings (25) No.
Item
Remark
Range
1
25.Opt_Source_UL
Voltage selecting mode of line
0~5
2
25.Opt_Source_UB
Voltage selecting mode of bus
0~5
3
25.U_Dd
Voltage threshold of dead check
0.05Un~0.8Un (V)
4
25.U_Lv
Voltage threshold of live check
0.5Un~Un (V)
5
25.K_Usyn
Compensation coefficient for synchronism voltage
0.20-5.00
6
25.phi_Diff
Phase difference limit of synchronism check for AR
0~ 89 (Deg)
7
25.phi_Comp
8
25.f_Diff
9
25.U_Diff
Voltage difference limit of synchronism check for AR
0.02Un~0.8Un (V)
10
25.t_DdChk
Time delay to confirm dead check condition
0.010~25.000 (s)
11
25.t_SynChk
Time delay to confirm synchronism check condition
0.010~25.000 (s)
12
25.En_fDiffChk
Enable frequency difference check
0 or 1
13
25.En_SynChk
Enable synchronism check
0 or 1
14
25.En_DdL_DdB
Enable dead line and dead bus (DLDB) check
0 or 1
15
25.En_DdL_LvB
Enable dead line and live bus (DLLB) check
0 or 1
16
25.En_LvL_DdB
Enable live line and dead bus (LLDB) check
0 or 1
17
25.En_NoChk
Enable AR without any check
0 or 1
Compensation for phase difference between two synchronous voltages Frequency difference limit of synchronism check for AR
0~359 (Deg)
0.02~1.00 (Hz)
7.4.1.29 Auto-reclosing Settings (79) No.
Item
Remark
Range
1
79.N_Rcls
Maximum number of reclosing attempts
1~4
2
79.t_Dd_1PS1
Dead time of first shot 1-pole reclosing
0.000~600.000 (s)
3
79.t_Dd_3PS1
Dead time of first shot 3-pole reclosing
0.000~600.000 (s)
4
79.t_Dd_3PS2
Dead time of second shot 3-pole reclosing
0.000~600.000 (s)
5
79.t_Dd_3PS3
Dead time of third shot 3-pole reclosing
0.000~600.000 (s)
6
79.t_Dd_3PS4
Dead time of fourth shot 3-pole reclosing
0.000~600.000 (s)
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PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings 7
79.t_CBClsd
Time delay of circuit breaker in closed position before reclosing
0.000~600.000 (s)
Time delay to wait for CB healthy, and begin to timing 8
79.t_CBReady
when
the
input
signal
[79.CB_Healthy]
is
de-energized and if it is not energized within this time
0.000~600.000 (s)
delay, AR will be blocked. 9
79.t_Wait_Chk
Maximum wait time for synchronism check Time delay allow for CB status change to conform
0.000~600.000 (s)
10
79.t_Fail
11
79.t_PW_AR
Pulse width of AR closing signal
0.000~600.000 (s)
12
79.t_Reclaim
Reclaim time of AR
0.000~600.000 (s)
13
79.t_PersistTrp
reclosing successful
Time delay of excessive trip signal to block auto-reclosing
0.000~600.000 (s)
0.000~600.000 (s)
Drop-off time delay of blocking AR, when blocking 14
79.t_DDO_BlkAR
signal for AR disappears, AR blocking condition drops 0.000~600.000 (s) off after this time delay
15
79.t_AddDly
16
79.t_WaitMaster
Additional time delay for auto-reclosing Maximum wait time for reclosing permissive signal from master AR
0.000~600.000 (s) 0.000~600.000 (s)
Time delay of discriminating another fault, and begin to times after 1-pole AR initiated, 3-pole AR will be 17
79.t_SecFault
initiated if another fault happens during this time 0.000~600.000 (s) delay. AR will be blocked if another fault happens after that. Enable auto-reclosing blocked when a fault occurs
18
79.En_PDF_Blk
19
79.En_AddDly
20
79.En_CutPulse
21
79.En_FailCheck
22
79.En
23
79.En_ExtCtrl
24
79.En_CBInit
Enable AR be initiated by open state of circuit breaker 0 or 1
25
79.Opt_Priority
Option of AR priority
None, High or Low
26
79.SetOpt
Control option of AR mode
0 or 1
27
79.En_1PAR
Enable 1-pole AR mode
0 or 1
28
79.En_3PAR
Enable 3-pole AR mode
0 or 1
29
79.En_1P/3PAR
Enable 1/3-pole AR mode
0 or 1
under pole disagreement condition Enable auto-reclosing with an additional dead time delay Enable adjust the length of reclosing pulse Enable confirm whether AR is successful by checking CB state Enable auto-reclosing Enable AR by external input signal besides logic setting [79.En]
PCS-931 Line Differential Relay
0 or 1
0 or 1 0 or 1 0 or 1 0 or 1 0 or 1
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7 Settings
7.4.1.30 Transfer Trip Settings (TT) No.
Item
Remark
Range
1
TT.t_Op
Time delay of transfer trip
0.000~600.000 (s)
2
TT.En_FD_Ctrl
Enable transfer trip controlled by local fault detector
0 or 1
7.4.1.31 Tripping Logic Settings No.
Item
1
En_MPF_Blk_AR
2
En_3PF_Blk_AR
3
En_PhSF_Blk_AR
4
En_Trp3P
5
t_Dwell_Trp
Remark
Range
Enable auto-reclosing blocked when multi-phase fault happens Enable auto-reclosing blocked when three-phase fault happens Enable auto-reclosing blocked when selection of faulty phase fails Enable three-phase tripping mode for any fault conditions The dwell time of tripping command, empirical value is 0.04
0 or 1
0 or 1
0 or 1
0 or 1
0.000~10.000 (s)
7.4.1.32 VTS Settings (VTS) No.
Item
Remark
Range
1
VTS.t_DPU
Pickup time delay of VT circuit supervision
0.200~100.000
2
VTS.t_DDO
Dropoff time delay of VT circuit supervision
0.200~100.000
3
VTS.En_Out_VT
VT is not connected to the protection device
0 or 1
If
three-phase
voltage
used
for
protection
measurement comes from line side (for example, 3/2 4
VTS.En_LineVT
breaker), it should be set as “1”. If three-phase 0 or 1 voltage comes from busbar side, it should be set as “0”.
5
VTS.En
Enable alarm function of VT circuit supervision
0 or 1
7.4.2 Access Path MainMenu“Settings”“Prot Settings”
7.5 Logic Link Settings The logic link settings are used to determine whether the relevant function of this device is enabled or disabled. If this device supports the logic link function, it will have a corresponding submenu in the submenu “Logic Links” for the logic link settings. Each logic link settings is an “AND” condition of enabling the relevant function with the corresponding binary input and logic setting. Through SAS or RTU, logic link settings can be set as “1” or “0”; and it means that the relevant function can be in service or out of service through remote command. It provides convenience for operation management.
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7 Settings
7.5.1 Setting Description 7.5.1.1 Spare Link Settings The spare link settings are used for future application. It can be defined according to project specification through the configuration tool, PCS-Explorer. No.
Item
Remark
Range
1
Link_01
Spare link setting 01
0 or 1
2
Link_02
Spare link setting 02
0 or 1
3
Link_03
Spare link setting 03
0 or 1
4
Link_04
Spare link setting 04
0 or 1
5
Link_05
Spare link setting 05
0 or 1
6
Link_06
Spare link setting 06
0 or 1
7
Link_07
Spare link setting 07
0 or 1
8
Link_08
Spare link setting 08
0 or 1
7.5.2 Access Path MainMenu“Settings”“Logic Links”
7.6 Measurement and Control Settings 7.6.1 Setting Description 7.6.1.1 Synchronism Settings No.
Item
Remark
1
MCBrd.25.Opt_Source_UL
Voltage selecting mode of line
0~5
2
MCBrd.25.Opt_Source_UB
Voltage selecting mode of bus
0~5
3
MCBrd.25.U_Dd
Voltage threshold of dead check
1.000~100.000 (V)
4
MCBrd.25.U_Lv
Voltage threshold of live check
1.000~100.000 (V)
5
MCBrd.25.K_Usyn
Compensation coefficient for synchronism voltage
0.20-5.00
6
MCBrd.25.phi_Diff
7
MCBrd.25.phi_Comp
8
MCBrd.25.f_Diff
9
MCBrd.25.U_Diff
Phase difference limit of synchronism check for manual closing Compensation for phase difference between two synchronous voltages Frequency difference limit of synchronism check for manual closing Voltage difference limit of synchronism check for manual closing
Range
0.10~ 180.00 (Deg)
0~360 (Deg)
0.00~3.00 (Hz)
1.000~100.000 (V)
10
MCBrd.25.En_SynChk
Enable synchronism check
0 or 1
11
MCBrd.25.En_DdL_DdB
Enable dead line and dead bus (DLDB) check
0 or 1
12
MCBrd.25.En_DdL_LvB
Enable dead line and live bus (DLLB) check
0 or 1
13
MCBrd.25.En_LvL_DdB
Enable live line and dead bus (LLDB) check
0 or 1
14
MCBrd.25.En_NoChk
Enable manual closing without any check
0 or 1
PCS-931 Line Differential Relay
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7 Settings 15
MCBrd.25.df/dt
Threshold of rate of frequency change between both sides of CB for synchronism-check.
0.10~5.00 (Hz/s)
Circuit breaker closing time. It is the time from 16
MCBrd.25.t_Close_CB
receiving closing command pulse till the CB is 0~1000 (ms) completely closed. From receiving a closing command, this device will continuously check whether between incoming voltage
17
MCBrd.25.t_Wait_Chk
and
reference
voltage
involved
in
synchronism check (or dead check) can meet the criteria. If the synchronism check (or dead check)
5.000~30.000 (s)
criteria are not met within the duration of this time delay, the failure of synchronism-check (or dead check) will be confirmed.
7.6.1.2 Dual Point Binary Input Settings Thses settings are applied to configure the status change confirmation time for No.xx double point binary inputs. Up to 10 virtual double point binary inputs are provided in this device. If a double point binary input changes from normal status to invalid status, i.e.: double point error occurs, [CSWIxx.t_DPU_DPS] will be applied as the debouncing time for No.xx double point binary input. No.
Name
Remark
Range
These settings are applied to configure the 1
CSWIxx.t_DPU_DPS
debouncing time. “DPU” is the abbreviation of
0~60000 (ms)
“Delay Pick Up”. (xx=01, 02….10)
7.6.1.3 Control Settings No.
Name
Remark
Range
No.xx holding time of a normal open contact of 1
CSWIxx.t_PW_Opn
remote opening CB, disconnector or for signaling purpose.
0~60000 (ms)
(xx=01, 02….10) No.xx closing time of a normal open contact of 2
CSWIxx.t_PW_Cls
remote closing CB, disconnector or for signaling purpose.
0~60000 (ms)
(xx=01, 02….10)
7.6.1.4 Interlock Settings No.
Name
Remark
Range
Enable No.xx open output of the BO module be 1
CSWIxx.En_Opn_Blk
controlled by the interlocking logic
0 or 1
(xx=01, 02….10) 2
CSWIxx.En_Cls_Blk
Enable No.xx closing output of the BO module be
7-30
0 or 1
PCS-931 Line Differential Relay Date: 2014-02-24
7 Settings No.
Name
Remark
Range
controlled by the interlocking logic (xx=01, 02….10)
7.6.2 Access Path MainMenu“Settings”“BCU Settings”
PCS-931 Line Differential Relay
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7 Settings
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PCS-931 Line Differential Relay Date: 2014-02-24
8 Human Machine Interface
8 Human Machine Interface Table of Contents 8 Human Machine Interface ............................................................... 8-a 8.1 Overview .......................................................................................................... 8-1 8.1.1 Keypad Operation .............................................................................................................. 8-2 8.1.2 LED Indications .................................................................................................................. 8-3 8.1.3 Front Communication Port ................................................................................................. 8-3 8.1.4 Ethernet Port Setup ........................................................................................................... 8-4
8.2 Menu Tree ........................................................................................................ 8-5 8.2.1 Overview ............................................................................................................................ 8-5 8.2.2 Main Menus ....................................................................................................................... 8-6 8.2.3 Sub Menus ......................................................................................................................... 8-7
8.3 LCD Display ................................................................................................... 8-27 8.3.1 Overview .......................................................................................................................... 8-27 8.3.2 Normal Display................................................................................................................. 8-27 8.3.3 Display Disturbance Records ........................................................................................... 8-28 8.3.4 Display Supervision Event ............................................................................................... 8-30 8.3.5 Display IO Events ............................................................................................................ 8-31 8.3.6 Display Device Logs ........................................................................................................ 8-31
8.4 Keypad Operation ......................................................................................... 8-32 8.4.1 View Device Measurements ............................................................................................. 8-32 8.4.2 View Device Status .......................................................................................................... 8-33 8.4.3 View Device Records ....................................................................................................... 8-33 8.4.4 Print Device Records ....................................................................................................... 8-33 8.4.5 View Device Setting ......................................................................................................... 8-34 8.4.6 Modify Device Setting ...................................................................................................... 8-35 8.4.7 Copy Device Setting ........................................................................................................ 8-38
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8-a Date: 2013-12-27
8 Human Machine Interface
8.4.8 Switch Setting Group ....................................................................................................... 8-38 8.4.9 Delete Device Records .................................................................................................... 8-39 8.4.10 Remote Control .............................................................................................................. 8-40 8.4.11 Modify Device Clock ....................................................................................................... 8-43 8.4.12 View Module Information................................................................................................ 8-44 8.4.13 Check Software Version ................................................................................................. 8-44 8.4.14 Communication Test....................................................................................................... 8-44 8.4.15 Select Language ............................................................................................................ 8-45
List of Figures Figure 8.1-1 Front panel ............................................................................................................8-1 Figure 8.1-2 Keypad buttons ....................................................................................................8-2 Figure 8.1-3 LED indications ....................................................................................................8-3 Figure 8.1-4 Corresponding cable of the RJ45 port in the front panel ..................................8-4 Figure 8.1-5 Rear view and terminal definition of NR1102C...................................................8-5 Figure 8.2-1 Menu tree ..............................................................................................................8-7
List of Tables Table 8.1-1 Definition of the 8-core cable ................................................................................8-4 Table 8.3-1 Tripping report messages....................................................................................8-30 Table 8.3-2 User operating event list......................................................................................8-32
8-b
PCS-931 Line Differential Relay Date: 2013-12-27
8 Human Machine Interface
The operator can access the protective device from the front panel. Local communication with the protective device is possible using a computer via a multiplex RJ45 port on the front panel. Furthermore, remote communication is also possible using a PC with the substation automation system via rear RS485 port or rear Ethernet port. The operator is able to check the protective device status at any time. This chapter describes human machine interface (HMI), and give operator an instruction about how to display or print event report, setting and so on through HMI menu tree and display metering value, including r.m.s. current, voltage and frequency etc. through LCD. Procedures to change active setting group or a settable parameter value through keypad is also described in details.
Note!
About three measurements in menu “Measurements”, please refer to the following description: “Measurements1” is use to display measured values from protection calculation DSP (displayed in secondary value) “Measurements2” is used to display measured values from fault detector DSP (displayed in secondary value) “Measurements3” is used to display measured primary values and other calculated quantities
8.1 Overview The human-machine interface consists of a human-machine interface (HMI) module which allows a communication to be as simple as possible for the user. The HMI module helps to draw your attention to something that has occurred which may activate a LED or a report displayed on the LCD. Operator can locate the data of interest by navigating the keypad.
5 11
PCS-931
12
ALARM
3
LINE DIFFERENTIAL RELAY
13
4
14
5
15
6
16
7
17
8
18
9
19
10
20
GRP
2
HEALTHY
ESC
1
ENT
1
3 4
2
Figure 8.1-1 Front panel
The function of HMI module: PCS-931 Line Differential Relay
8-1 Date: 2013-12-27
8 Human Machine Interface No.
Item
Description A 320×240 dot matrix backlight LCD display is visible in dim lighting
1
LCD
conditions. The corresponding messages are displayed when there is operation implemented. 20 status indication LEDs, 2 LEDs are fixed as the signals of “HEALTHY”
2
LED
(green) and “ALARM” (yellow), 18 LEDs are configurable with selectable color among green, yellow and red.
3
Keypad
Navigation keypad and command keys for full access to device
4
Communication port
a multiplex RJ45 port for local communication with a PC
5
Logo
Type and designation and manufacturer of device
GR P
8.1.1 Keypad Operation
ENT
ESC
Figure 8.1-2 Keypad buttons
1.
2.
3.
“ESC”:
Cancel the operation
Quit the current menu
“ENT”:
Execute the operation
Confirm the interface
“GRP”
4.
5.
6.
Activate the switching interface of setting group
leftward and rightward direction keys (“◄” and “►”):
Move the cursor horizontally
Enter the next menu or return to the previous menu
upward and downward direction keys (“▲” and “▼”)
Move the cursor vertically
Select command menu within the same level of menu
plus and minus sign keys (“+” and “-”)
Modify the value
8-2
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8 Human Machine Interface
Modify and display the message number
Page up/down
8.1.2 LED Indications HEALTHY ALARM
Figure 8.1-3 LED indications
A brief explanation has been made as bellow. LED
Display Off
HEALTHY Steady Green Off
Description When the equipment is out of service or any hardware error is defected during self-check. Lit when the equipment is in service and ready for operation. When equipment in normal operating condition.
ALARM Steady Yellow
Lit when VT circuit failure, CT circuit failure or other abnormal alarm is issued.
Note!
“HEALTHY” LED can only be turned on by energizing the device and no abnormality detected. “ALARM” LED is turned on when abnormalities of device occurs like above mentioned and can be turned off after abnormalities are removed except alarm report [CTS.Alm] which can only be reset only when the failure is removed and the device is rebooted or re-energized. Other LED indicators with no labels are configurable and user can configure them to be lit by signals of operation element, alarm element and binary output contact according to requirement through PCS-Explorer software, but as drawn in figure, 2 LEDs are fixed as the signals of “HEALTHY” (green) and “ALARM” (yellow), 18 LEDs are configurable with selectable color among green, yellow and red.
8.1.3 Front Communication Port There is a multiplex RJ45 port on the front panel. This port can be used as an RS-232 serial port PCS-931 Line Differential Relay
8-3 Date: 2013-12-27
8 Human Machine Interface
as well as a twisted-pair ethernet port. As shown in the following figure, a customized cable is applied for debugging via this multiplex RJ45 port.
Figure 8.1-4 Corresponding cable of the RJ45 port in the front panel
In the above figure and the following table: P1: To connect the multiplex RJ45 port. An 8-core cable is applied here. P2: To connect the twisted-pair ethernet port of the computer. P3: To connect the RS-232 serial port of the computer. The definition of the 8-core cable in the above figure is introduced in the following table. Table 8.1-1 Definition of the 8-core cable Terminal No.
Core color
Function
Device side
Computer side
(Left)
(Right)
1
Orange
TX+ of the ethernet port
P1-1
P2-1
2
Orange & white
TX- of the ethernet port
P1-2
P2-2
3
Green & white
RX+ of the ethernet port
P1-3
P2-3
4
Blue
TXD of the RS-232 serial port
P1-4
P3-2
5
Brown & white
RXD of the RS-232 serial port
P1-5
P3-3
6
Green
RX- for the ethernet port
P1-6
P2-6
7
Blue & white
The ground connection of the RS-232 port.
P1-7
P3-5
8.1.4 Ethernet Port Setup MON plug-in module is equipped with two or four 100Base-TX Ethernet interface, take NR1102C as an example, as shown in Figure 8.1-5. Its rear view and the definition of terminals. The Ethernet port can be used to communication with PC via auxiliary software (PCS-Explorer) after connecting the protection device with PC, so as to fulfill on-line function (please refer to the instruction manual of PCS-Explorer). At first, the connection between the protection device and PC must be established. Through setting the IP address and subnet mask of corresponding Ethernet interface in the menu “Settings→Device Setup→Comm Settings”, it should be ensured that the protection device and PC are in the same network segment. For example, setting the IP address and subnet mask of network A. (using network A to connect with PC)
8-4
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8 Human Machine Interface
PC: IP address is set as “198.87.96.102”, subnet mask is set as “255.255.255.0” The IP address and subnet mask of protection device should be [IP_LAN1]= 198.87.96.XXX, [Mask_LAN1]=255.255.255.0, [En_LAN1]=1. (XXX can be any value from 0 to 255 except 102) If the logic setting [En_LAN1] is non-available, it means that network A is always enabled.
NR1102C
ETHERNET
Network A
Network B
SYN+ SYNSGND GND RTS TXD SGND
Figure 8.1-5 Rear view and terminal definition of NR1102C
Note! If using other Ethernet port, for example, Ethernet B, the logic setting [En_LAN2] must be set as “1”.
8.2 Menu Tree 8.2.1 Overview Press “▲” of any running interface and enter the main menu. Select different submenu by “▲” and “▼”. Enter the selected submenu by pressing “ENT” or “►”. Press “◄” and return to the previous menu. Press “ESC” back to main menu directly. For sake of entering the command menu again, a command menu will be recorded in the quick menu after its execution. Five latest command menus can be recorded in the quick menu. When five command menus are recorded, the latest command menu will cover the earliest one, adopting the “first in first out” principle. It is arranged from top to bottom and in accordance with the execution order of command menus. Press “▲” to enter the main menu with the interface as shown in the following diagram:
PCS-931 Line Differential Relay
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8 Human Machine Interface
MainMenu
Language Clock Quick Menu
For the first powered device, there is no record in quick menu. Press “▲” to enter the main menu with the interface as shown in the following diagram:
Measurements Status Records Settings Print Local Cmd Information Test Clock Language
The descriptions about menu are based on the maximized configuration, for a specific project, if some function is not available, the corresponding submenu will hidden.
8.2.2 Main Menus The menu of PCS-931 is organized into main menu and submenus, much like a PC directory structure. The menu of PCS-931 is divided into 10 sections:
8-6
PCS-931 Line Differential Relay Date: 2013-12-27
8 Human Machine Interface Main Menu
Measurements
Status
Records
Settings
Print
Local Cmd
Information
Test
Clock
Language
Figure 8.2-1 Menu tree
Under main interface, press “▲” to enter main menu, and select submenu by pressing “▲”, “▼” and “ENT”. The command menu adopts a tree shaped content structure. The above diagram provides the integral structure and all main menus (first-level menus) under menu tree of the device.
8.2.3 Sub Menus 8.2.3.1 Measurements Main Menu
Measurements
Measurements1 Measurements2 Measurements3
This menu is used to display real-time measured values, including AC voltage, AC current, phase angle and calculated quantities. These data can help users to acquaint the device′s status. This menu comprises following submenus. Please refer to section “Measurement” about the detailed measured values.
PCS-931 Line Differential Relay
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8 Human Machine Interface No.
Item
1
Measurements1
2
Measurements2
3
Measurements3
Function description Display measured values from protection calculation DSP (Displayed in secondary value) Display measured values from fault detector DSP (Displayed in secondary value) Display measured primary values and other calculated quantities
8.2.3.2 Status Main Menu
Status
Inputs Outputs Superv State
This menu is used to display real time input signals, output signals and alarm signals of the device. These data can help users to acquaint the device′s status. This menu comprises following submenus. Please respectively refer to section “Signal List” about the detailed introduction of input signals and output signals, and section “Supervision Alarms” about the detailed introduction of alarm signals. No.
Item
Function description
1
Inputs
Display all input signal states
2
Outputs
Display all output signal states
3
Superv State
Display supervision alarm states
The submenu “Inputs” comprises the following command menus. Main Menu
Status
Inputs
Contact Inputs GOOSE Inputs Prot Ch Inputs
No. 1
Item Contact Inputs
Function description Display states of binary inputs derived from opto-isolated channels
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8 Human Machine Interface 2
GOOSE Inputs
Display states of GOOSE binary inputs.
3
Prot Ch Inputs
Display states of binary inputs received from protection channel.
The submenu “Outputs” comprises the following command menus. Main Menu
Status
Outputs
Contact Outputs GOOSE Outputs Interlock Status Prot Ch Outputs
No.
Item
Function description
1
Contact Outputs
Display states of contact binary outputs
2
GOOSE Outputs
Display states of GOOSE binary outputs
3
Interlock Status
Display states of interlock result of each remote control.
4
Prot Ch Outputs
Display states of channel outputs
The submenu “Superv State” comprises the following command menus. Main Menu
Status
Superv State
Prot Superv FD Superv GOOSE Superv SV Superv
No.
Item
Function description
1
Prot Superv
Display states of self-supervision signals from protection calculation DSP
2
FD Superv
Display states of self-supervision signals from fault detector DSP
3
GOOSE Superv
Display states of GOOSE self-supervision signals
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8 Human Machine Interface 4
SV Superv
Display states of SV self-supervision signals
8.2.3.3 Records Main Menu
Records
Disturb Records Superv Events IO Events Device Logs Control Logs Clear Records
This menu is used to display all kinds of records, including the disturbance records, supervision events, binary events and device logs, so that the operator can load to view and use as the reference of analyzing accidents and repairing the device. All records are stored in non-volatile memory, it can still record them even if it loses its power. This menu comprises the following submenus. No.
Item
Function description
1
Disturb Records
Display disturbance records of the device
2
Superv Events
Display supervision events of the device
3
IO Events
Display binary events of the device
4
Device Logs
Display device logs of the device
5
Control Logs
Display control logs of the device
6
Clear Records
Clear all records.
8.2.3.4 Settings Main Menu
Settings
System Settings Prot Settings BCU Settings Logic Links Device Setup
This menu is used to check the device setup, system parameters, protection settings and logic
8-10
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8 Human Machine Interface
links settings, as well as modifying any of the above setting items. Moreover, it can also execute the setting copy between different setting groups. This menu comprises the following submenus. No.
Item
Function description
1
System Settings
Check or modify the system parameters
2
Prot Settings
Check or modify the protection settings
3
BCU Settings
Check or modify the measurement and control settings
4
Logic Links
5
Device Setup
Check or modify the logic links settings, including function links, SV links, GOOSE links and spare links Check or modify the device setup
The submenu “Prot Settings” includes the following command menus.
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8 Human Machine Interface Main Menu
Settings
Prot Settings
Line Settings FD Settings AuxE Settings Direction Settings DiffP Settings Rmt CommCh Settings DPFC Dist Settings LoadEnch Settings Mho Dist Settings Quad Dist Settings ROC Settings SOTF Settings OC Settings VTF OC Settings BRC Settings RevPower Settings BFP Settings Deadzone Settings OV Settings UV Settings ThOvld Settings PD Settings Stub Settings FreqProt Settings MiscProt Settings VTS/CTS Settings Trip Logic Settings AR/Syn Settings Copy Settings
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8 Human Machine Interface
No.
Item
Function description
1
Line Settings
Check or modify line parameters
2
FD Settings
Check or modify fault detector element settings
3
AuxE Settings
Check or modify auxiliary element settings
4
Direction Settings
Check or modify direction control element settings
5
DiffP Settings
Check or modify current differential protection settings
6
Rmt CommCh Settings
Check or modify optical pilot channel settings
7
DPFC Dist Settings
Check or modify DPFC distance protection settings
8
LoadEnch Settings
Check or modify load encroachment settings
9
Mho Dist Settings
Check or modify distance protection with mho characteristic settings
10
Quad Dist Settings
Check or modify distance protection with Quad characteristic settings
11
ROC Settings
Check or modify directional earth-fault protection settings
12
SOTF Settings
Check or modify SOTF distance and overcurrent protection settings
13
OC Settings
Check or modify phase overcurrent protection settings
14
VTF OC Settings
Check or modify overcurrent protection settings for VT circuit failure
15
BRC Settings
Check or modify broken conductor protection settings
16
RevPower Settings
Check or modify reverse power protection settings
17
BFP Settings
Check or modify breaker failure protection settings
18
Deadzone Settings
Check or modify dead zone settings
19
OV Settings
Check or modify overvoltage protection settings
20
UV Settings
Check or modify undervoltage protection settings
21
ThOvld Settings
Check or modify thermal overload protection settings
22
PD Settings
Check or modify pole discrepancy protection settings
23
Stub Settings
Check or modify stub overcurrent protection settings
24
FreqProt Settings
Check or modify frequency protection settings
25
MiscProt Settings
Check or modify miscellaneous settings
26
VTS/CTS Settings
Check or modify VT circuit supervision and CT circuit supervision settings
27
Trip Logic Settings
Check or modify trippling logic settings
28
AR/Syn Settings
Check or modify synchronism check and auto-reclosing settings
29
Copy Settings
Copy setting between different setting groups
The submenu “BCU Settings” includes the following command menus.
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Settings
BCU Settings
Syn Settings BI Settings Control Settings Interlock Settings
No.
Item
Function description
1
Syn Settings
Check or modify manual sysnchronism check settings
2
BI Settings
Check or modify binary input settings
3
Control Settings
Check or modify control settings
4
Interlock Settings
Check or modify interlock settings
The submenu “Logic Links” comprises the following command menus. Main Menu
Settings
Logic Links
Function Links GOOSE Links SV Links Spare Links
No.
Item
Function description
1
Function Links
Check or modify function links settings
2
GOOSE Links
Check or modify GOOSE links settings
3
SV Links
Check or modify SV links settings
4
Spare Links
Check or modify spare links settings (used for programmable logic)
The submenu “GOOSE Links” includes the following command menus.
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Settings
Logic Links
GOOSE Links
GOOSE Send Links GOOSE Recv Links
No.
Item
Function description
1
GOOSE Send Links
Check or modify GOOSE sending links settings
2
GOOSE Recv Links
Check or modify GOOSE receiving links settings
The submenu “Device Setup” comprises the following command menus. Main Menu
Settings
Device Setup
Device Settings Comm Settings Label Settings
No.
Item
Function description
1
Device Settings
Check or modify the device settings.
2
Comm Settings
Check or modify the communication settings.
3
Label Settings
Check or modify the label settings of each protection element.
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8.2.3.5 Print Main Menu
Print
Device Info Settings Disturb Records Superv Events IO Events Prot Ch Superv Prot Ch Statistics Device Status Waveforms IEC103 Info Cancel Print
This menu is used to print device description, settings, all kinds of records, waveforms, information related with IEC60870-5-103 protocol, channel state and channel statistic. This menu comprises the following submenus. No. 1
Item Device Info
Function description Print the description information of the device, including software version. Print device setup, system parameters, protection settings and logic
2
Settings
links settings. It can print by different classifications as well as printing all settings of the device. Besides, it can also print the latest modified settings.
3
Disturb Records
Print the disturbance records
4
Superv Events
Print the supervision events
5
IO Events
Print the binary events Print the self-check information of optical fibre channel, which is made of
6
Prot Ch Superv
some hexadecimal characters and used to developer analyze channel state
7
Prot Ch Statistics
8
Device Status
Print the statistic report of optical fibre channel, which is formed A.M. 9:00 every day Print the current state of the device, including the sampled value of voltage and current, the state of binary inputs, setting and so on
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Waveforms
Print the recorded waveforms
10
IEC103 Info
Print 103 Protocol information, including function type (FUN), information serial number (INF), general classification service group number, and channel number (ACC) 11
Cancel Print
Cancel the print command
The submenu “Settings” comprises the following submenus. Main Menu
Print
Settings
System Settings Prot Settings BCU Settings Logic Links Device Setup All Settings Latest Chgd Settings
No.
Item
Function description
1
System Settings
Print the system parameters
2
Prot Settings
Print the protection settings
3
BCU Settings
Print the measurement and control settings
4
Logic Links
Print the logic links settings
5
Device Setup
Print the settings related to device setup
6
All Settings
7
Latest Chgd Settings
Print all settings including device setup, system parameters, protection settings and logic links settings Print the setting latest modified
The submenu “Prot Settings” comprises the following command menus.
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Print
Settings
Prot Settings
Line Settings FD Settings AuxE Settings Direction Settings DiffP Settings Rmt CommCh Settings DPFC Dist Settings LoadEnch Settings Mho Dist Settings Quad Dist Settings ROC Settings SOTF Settings OC Settings VTF OC Settings BRC Settings RevPower Settings BFP Settings Deadzone Settings OV Settings UV Settings ThOvld Settings PD Settings Stub Settings FreqProt Settings MiscProt Settings VTS/CTS Settings Trip Logic Settings AR/Syn Settings All Settings
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No.
Item
Function description
1
Line Settings
Print line parameters
2
FD Settings
Print fault detector element settings
3
AuxE Settings
Print auxiliary element settings
4
Direction Settings
Print direction control element settings
5
DiffP Settings
Print current differential protection settings
6
Rmt CommCh Settings
Print optical pilot channel settings
7
DPFC Dist Settings
Print y DPFC distance protection settings
8
LoadEnch Settings
Print load encroachment settings
9
Mho Dist Settings
Print distance protection with mho characteristic settings
10
Quad Dist Settings
Print distance protection with Quad characteristic settings
11
ROC Settings
Print directional earth-fault protection settings
12
SOTF Settings
Print SOTF distance and overcurrent protection settings
13
OC Settings
Print phase overcurrent protection settings
14
VTF OC Settings
Print overcurrent protection settings for VT circuit failure
15
BRC Settings
Print broken conductor protection settings
16
RevPower Settings
Print reverse power protection settings
17
BFP Settings
Print breaker failure protection settings
18
Deadzone Settings
Print dead zone settings
19
OV Settings
Print overvoltage protection settings
20
UV Settings
Print undervoltage protection settings
21
ThOvld Settings
Print thermal overload protection settings
22
PD Settings
Print pole discrepancy protection settings
23
Stub Settings
Print stub overcurrent protection settings
24
FreqProt Settings
Print frequency protection settings
25
MiscProt Settings
Print miscellaneous settings
26
VTS/CTS Settings
Print VT circuit supervision and CT circuit supervision settings
27
Trip Logic Settings
Print trippling logic settings
28
AR/Syn Settings
Print synchronism check and auto-reclosing settings
29
All Settings
Print all settings included in “Prot Settings” submenu
The submenu “BCU Settings” includes the following command menus.
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Print
Settings
BCU Settings
Syn Settings BI Settings Control Settings Interlock Settings All Settings
No.
Item
Function description
1
Syn Settings
Print manual sysnchronism check settings
2
BI Settings
Print binary input settings
3
Control Settings
Print control settings
4
Interlock Settings
Print interlock settings
5
All Settings
Print all settings included in “BCU Settings” submenu
The submenu “Logic Links” comprises the following command menus. Main Menu
Print
Settings
Logic Links
Function Links GOOSE Links SV Links Spare Links All Settings
No. 1
Item Function Links
Function description Print function links settings
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GOOSE Links
Print GOOSE links settings
3
SV Links
Print SV links settings
4
Spare Links
Print spare links settings (used for programmable logic)
5
All Settings
Print all settings included in “Logic Links” submenu
The submenu “GOOSE Links” comprises the following command menus. Main Menu
Print
Settings
Logic Links
GOOSE Links
GOOSE Send Links GOOSE Recv Links
No.
Item
Function description
1
GOOSE Send Links
Print GOOSE sending links settings
2
GOOSE Recv Links
Print GOOSE receiving links settings
The submenu “Device Setup” comprises the following command menus. Main Menu
Print
Settings
Device Setup
Device Settings Comm Settings Label Settings All Settings
No.
Item
Function description
1
Device Settings
Print the device settings.
2
Comm Settings
Print the communication settings.
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Label Settings
Print the label settings of each protection element.
4
All Settings
Print all settings included in “Device Setup” submenu
The submenu “Prot Ch Superv” comprises the following command menus. Main Menu
Print
Prot Ch Superv
Channel 1 Channel 2
No.
Item
1
Channel 1
2
Channel 2
Function description Print the self-check information of optical fibre channel 1, which is made of some hexadecimal characters and used to developer analyze channel state Print the self-check information of optical fibre channel 2, which is made of some hexadecimal characters and used to developer analyze channel state
The submenu “Prot Ch Statistics” includes the following command menus. Main Menu
Print
Prot Ch Statistics
Channel 1 Channel 2
No.
Item
1
Channel 1
2
Channel 2
Function description Print the statistic report of optical fibre channel 1, which is formed A.M. 9:00 every day Print the statistic report of optical fibre channel 2, which is formed A.M. 9:00 every day
The submenu “Waveforms” includes the following command menus.
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Print
Waveforms
Wave
No. 1
Item
Function description
Wave
Print the recorded current and voltage waveforms
8.2.3.6 Local Cmd Main Menu
Local Cmd
Reset Target Trig Oscillograph Control Download Clear Counter Clear AR Counter Clear Energy Counter
This menu is used to reset the tripping relay with latch, indicator LED, LCD display, and as same as the reset function of binary inputs. This menu provides a method of manually recording the current waveform data of the device under normal condition for printing and uploading SAS. Besides, it can send out the request of program download, clear statistic information about GOOSE, SV, AR, FO channel and energy. This menu comprises the following submenus. No.
Item
Function description
1
Reset Target
Reset the local signal, indicator LED, LCD display and so on
2
Trig Oscillograph
Trigger waveform recording
3
Control
Manually operating to trip, close output or for signaling purpose
4
Download
Send out the request of downloading program
5
Clear Counter
Clear GOOSE, SV and FO channel statistic data
6
Clear AR Counter
Clear AR statistic data
7
Clear Energy Counter
Clear all energy metering values (i.e., PHr+_Pri, PHr-_Pri, Qr+_Pri,
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8.2.3.7 Information Main Menu
Information
Version Info Board Info
In this menu, LCD can display software information of all kinds of intelligent plug-in modules, which consists of version, creating time of software, CRC codes and management sequence number. Besides, plug-in module information can also be viewed. This menu comprises the following command menus. No.
Item
Function description Display software information of DSP module, MON module and HMI module,
1
Version Info
which consists of version, creating time of software, CRC codes and management sequence number.
2
Board Info
Monitor the current working state of each intelligent module.
8.2.3.8 Test Main Menu
Test
Prot Ch Counter GOOSE Comm Counter SV Comm Counter Device Test AR Counter
This menu is mainly used for developers to debug the program and for engineers to maintain the device. It can be used to fulfill the communication test function. It is also used to generate all kinds of reports or events to transmit to the SAS without any external input, so as to debug the communication on site. Besides, it can also display statistic information about GOOSE, SV, AR and FO channel. This menu comprises the following submenus.
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Item
Function description
1
Prot Ch Counter
Check communication statistics data of protection FO channel
2
GOOSE Counter
Check communication statistics data of GOOSE
3
SV Counter
Check communication statistics data of SV (Sampled Values) Automatically generate all kinds of reports or events to transmit to SCADA,
4
Device Test
including disturbance records, self-supervision events and binary events. It can realize the report uploading by different classification, as well as the uploading of all kinds of reports
5
AR Counter
Check AR counters
The submenu “Prot Ch Counter” comprises the following command menus. Main Menu
Test
Prot Ch Counter
Ch1 Counter Ch2 Counter
No.
Item
Function description
1
Ch1 Counter
Check communication statistic information of channel 1
2
Ch2 Counter
Check communication statistic information of channel 2
The submenu “Device Test” comprises the following submenus. Main Menu
Test
Device Test
Disturb Events Superv Events IO Events
No. 1
Item Disturb Events
Function description View the relevant information about disturbance records (only used for debugging persons)
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Superv Events
3
IO Events
View the relevant information about supervision events (only used for debugging persons) View the relevant information about binary events (only used for debugging persons)
Users can respectively execute the test automatically or manually by selecting commands “All Test” or “Select Test”. The submenu “Disturb Events” comprises the following command menus. Main Menu
Test
Device Test
Disturb Events
All Test Select Test
No.
Item
Description
1
All Test
Ordinal test of all protection elements
2
Select Test
Selective test of corresponding classification
The submenu “Superv Events” comprises the following command menus. Main Menu
Test
Device Test
Superv Events
All Test Select Test
No.
Item
Description
1
All Test
Ordinal test of all self-supervisions
2
Select Test
Selective test of corresponding classification
The submenu “IO Events” comprises the following command menus. 8-26
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Test
Device Test
IO Events
All Test Select Test
No.
Item
Description
1
All Test
Ordinal test of change of all binary inputs
2
Select Test
Selective test of corresponding classification
8.2.3.9 Clock The current time of internal clock can be viewed here. The time is displayed in the form YY-MM-DD and hh:mm:ss. All values are presented with digits and can be modified. 8.2.3.10 Language This menu is mainly used to set LCD display language.
8.3 LCD Display 8.3.1 Overview There are some kinds of LCD display, SLD (single line diagram) display, disturbance records, supervison events, IO events, control logs and device logs. Disturbance records and supervison events will not disappear until them are acknowledged by pressing the “RESET” button in the protection panel (i.e. energizing the binary input [BI_RstTarg]). If any event is detected, the corresponding event display will pop up automatically, and user can keep pressing “ENT” and then press “ESC” to switch between normal display and event display. IO events will be displayed for 5s and then it will return to the previous display interface automatically. Device logs will not pop up and can only be viewed by navigating the corresponding menu.
8.3.2 Normal Display After the device is powered and entered into the initiating interface, it takes tens of seconds to complete the initialization of the device. During the initialization of the device, the “HEALTHY” indicator lamp of the device goes out. The device can display single line diagram (SLD) and primary operation information, it can support wiring configuration function. LCD configuration file can be downloaded via the network. Remote control operation through single line diagram is also supported.
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Under normal condition, LCD will display the following interface. LCD adopts white color as its backlight that is activated if once there is any keyboard operation, moreover, the backlight will be extinguished automatically if no keyboard operation is detected for a duration.
S
2010-06-08 10:10:00 Ia
0.00A
Ib
0.00A
Ic
0.00A
3I0
0.00A
Ua
0.02V
Ub
0.00V
Uc
0.00V
3U0
0.02V
U_Syn
0.00V
f
50.00Hz Addr 24343
Group 01
The content displayed on the screen contains: the current date and time of the device (with a format of yyyy-mm-dd hh:mm:ss:), the active setting group number, three-phase current sampling value, residual current sampling value, three-phase voltage sampling value, residual voltage sampling value, the synchronism voltage sampling value, line frequency and the address relevant to IP address of Ethernet A. If all the sampling values of the voltage and the current can’t be fully displayed within one screen, they will be scrolling-displayed automatically from the top to the bottom. If IP address of Ethernet A is “xxx.xxx.a.b”, the displayed address equals to (a×256+b). For example, If IP address of Ethernet A is “198.087.095.023”, the displayed address will be “95× 256+23=24343”. If the device has detected any abnormal state, it′ll display the self-check alarm information. “S” indicates that device clock is synchronized. If “S” disappears, it means that device clock is not synchronized.
8.3.3 Display Disturbance Records This device can store up to 32 groups of disturbance records with fault waveform. Each group consists of disturbance records of operation elements and corresponding fault detector elements. Up to 1024 disturbance records can be stored in this device. If there is protection element operation, LCD will automatically display the latest group of disturbance records, and two kinds of LCD display interfaces will be available depending on whether there are supervision events or not. For the situation that the disturbance records and the supervision events coexist, the upper half part is the disturbance record, and the lower half part is the supervision event. The following items 8-28
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are listed in the upper half part: record No., record name, generation time of the disturbance record. If there is protection element operation, faulty phase and relative operation time (with reference to the corresponding fault detector element) will be displayed. If the disturbance records can not be displayed in one page, they will be displayed in several pages alternately. If there is no supervision event, disturbance records will be displayed as shown in the following figure.
2013-01-15 13:22:23:669
NO.001 0000ms
Disturb
FD.DPFC.Pkp
0024ms
AB
21Q.Z1.Op
If the device has the supervision event, the display interface will show the disturbance record and the supervision event at the same time.
2013-01-15 13:22:23:669
NO.001 0000ms
Disturb
FD.DPFC.Pkp
0024ms
AB
21Q.Z1.Op
Superv Events Alm_Device
NO.001
shows the SOE No. of the disturbance record.
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shows the time of the disturbance record, the format is “yyyy-mm-dd hh:mm:ss:fff”.
Disturb
shows the title of the disturbance record.
0000ms FD.DPFC.Pkp
shows fault detector element and its operation time (set as “0000ms” fixedly).
0024ms
shows operation element and its relative operation time (with reference to the corresponding fault detector element).
AB
21Q.Z1.Op
All the protection elements have been listed in chapter “Operation Theory”, and please refer to each protection element for details. The reports related to oscillography function are showed in the following table. Table 8.3-1 Tripping report messages No.
Message
Description
1
TrigDFR_Man
Oscillography function is triggered manually.
2
TrigDFR_Rmt
Oscillography function is triggered remotely. Oscillography function is triggered by binary input [BI_TrigDFR]. The
3
TrigDFR_BI
binary input [BI_TrigDFR] is configurable, and it can be designated to internal signal or external input.
8.3.4 Display Supervision Event This device can store 1024 pieces of supervision events. During the running of the device, the supervision event of hardware self-check errors or system running abnormity will be displayed immediately.
S
Superv Events
Alm_Device Alm_Version
S
indicates that device clock is synchronized. If “S” disappears, it means that device clock is not synchronized.
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Superv Events
shows the title of the supervision events.
Alm_Device
shows the contents of supervision events.
Alm_Version
8.3.5 Display IO Events This device can store 1024 pieces of binary events. During the running of the device, the binary input will be displayed once its state has changed, i.e. from “0” to “1” or from “1” to “0”.
NO.001
2013-01-15 13:31:23:669
BI_Maintenance
IO Chg 0
1
NO.001
shows the No. of the binary event.
2013-01-15 13:31:23:669
shows date and time when the report occurred, the format is “yyyy-mm-dd hh:mm:ss:fff”.
IO Chg
shows the title of the binary event.
BI_Maintenance
0→1
shows the state change of binary input, including binary input name, original state and final state.
8.3.6 Display Device Logs This device can store 1024 pieces of device logs. Please refer to section 8.4.3 for LCD operation
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4. Device Logs NO.4 2008-11-28 10:18:47:569ms Reboot
Device Logs NO. 4
shows the title and the number of the device log
2008-11-28 10:18:47:569
shows date and time when the report occurred, the format is year–month-date and hour:minute:second:millisecond
Reboot
shows the manipulation content of the device log
User operating information listed below may be displayed. Table 8.3-2 User operating event list No.
Message
Description
1
Reboot
The device has been reboot.
2
Settings_Chg
The device′s settings have been changed.
3
ActiveGrp_Chgd
Active setting group has been changed.
4
Report_Cleared
All reports have been deleted. (Device logs can not be deleted)
5
Waveform_Cleared
All waveforms have been deleted.
6
Process_Exit
A process has exited.
7
Counter_Cleared
Clear counter
It will be displayed on LCD before disturbance records and supervision events are confirmed. Only pressing both “ENT” and “ESC” at the same time can switch among disturbance records, supervision events and the normal running state of the device to display it. IO events will be displayed for 5s and then it will return to the previous display interface automatically.
8.4 Keypad Operation 8.4.1 View Device Measurements The operation is as follows: 1.
Press the “▲” to enter the main menu;
2.
Press the “▲” or “▼” to move the cursor to the “Measurements” menu, and then press
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the “ENT” or “►” to enter the menu; 3.
Press the “▲” or “▼” to move the cursor to any command menu, and then press the “ENT” to enter the menu;
4.
Press the “▲” or “▼” to page up/down (if all information cannot be displayed in one display screen, one screen can display 14 lines of information at most);
5.
Press the “◄” or “►” to select pervious or next command menu;
6.
Press the “ENT” or “ESC” to exit this menu (returning to the “Measurements” menu);
8.4.2 View Device Status The operation is as follows: 1.
Press the key “▲” to enter the main menu.
2.
Press the key “▲” or “▼” to move the cursor to the “Status” menu, and then press the “ENT” or “►” to enter the menu.
3.
Press the key “▲” or “▼” to move the cursor to any command menu item, and then press the key “ENT” to enter the submenu.
4.
Press the “▲” or “▼” to page up/down (if all information cannot be displayed in one display screen, one screen can display 14 lines of information at most).
5.
Press the key “◄” or “►” to select pervious or next command menu.
6.
Press the key “ENT” or “ESC” to exit this menu (returning to the “Status” menu).
8.4.3 View Device Records The operation is as follows: 1.
Press the “▲” to enter the main menu;
2.
Press the “▲” or “▼” to move the cursor to the “Records” menu, and then press the “ENT” or “►” to enter the menu;
3.
Press the “▲” or “▼” to move the cursor to any command menu, and then press the “ENT” to enter the menu;
4.
Press the “▲” or “▼” to page up/down;
5.
Press the “+” or “-” to select pervious or next record;
6.
Press the “◄” or “►” to select pervious or next command menu;
7.
Press the “ENT” or “ESC” to exit this menu (returning to the “Records” menu);
8.4.4 Print Device Records The operation is as follows: 1.
Press the “▲” to enter the main menu;
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2.
Press the “▲” or “▼” to move the cursor to the “Print” menu, and then press the “ENT” or “►” to enter the menu;
3.
Press the “▲” or “▼” to move the cursor to any command menu, and then press the “ENT” to enter the menu;
Selecting the “Disturb Records”, and then press the “+” or “-” to select pervious or next record. After pressing the key “ENT”, the LCD will display “Start Printing... ”, and then automatically exit this menu (returning to the menu “Print”). If the printer doesn’t complete its current print task and re-start it for printing, and the LCD will display “Printer Busy…”. Press the key “ESC” to exit this menu (returning to the menu “Print”).
Selecting the command menu “Superv Events” or “IO Events”, and then press the key “▲” or “▼” to move the cursor. Press the “+” or “-” to select the starting and ending numbers of printing message. After pressing the key “ENT”, the LCD will display “Start Printing…”, and then automatically exit this menu (returning to the menu “Print”). Press the key “ESC” to exit this menu (returning to the menu “Print”).
4.
If selecting the command menu “Device Info”, “Device Status“ or “IEC103 Info”, press the key “ENT”, the LCD will display “Start printing..”, and then automatically exit this menu (returning to the menu “Print”).
5.
If selecting the “Settings”, press the key “ENT” or “►” to enter the next level of menu.
6.
After entering the submenu “Settings”, press the key “▲” or “▼” to move the cursor, and then press the key “ENT” to print the corresponding default value. If selecting any item to printing: Press the key “+” or “-” to select the setting group to be printed. After pressing the key “ENT”, the LCD will display “Start Printing…”, and then automatically exit this menu (returning to the menu “Settings”). Press the key “ESC” to exit this menu (returning to the menu “Settings”).
7.
After entering the submenu “Waveforms”, press the “+” or “-” to select the waveform item to be printed and press ”ENT” to enter. If there is no any waveform data, the LCD will display “No Waveform Data!” (Before executing the command menu “Waveforms”, it is necessary to execute the command menu “Trig Oscillograph” in the menu “Local Cmd”, otherwise the LCD will display “No Waveform Data!”). With waveform data existing:
Press the key “+” or “-” to select pervious or next record. After pressing the key “ENT”, the LCD will display “Start Printing…”, and then automatically exit this menu (returning to the menu “Waveforms”). If the printer does not complete its current print task and re-start it for printing, and the LCD will display “Printer Busy…”. Press the key “ESC” to exit this menu (returning to the menu “Waveforms”).
8.4.5 View Device Setting The operation is as follows:
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1.
Press the “▲” to enter the main menu;
2.
Press the “▲” or “▼” to move the cursor to the “Settings” menu, and then press the “ENT” or “►” to enter the menu;
3.
Press the “▲” or “▼” to move the cursor to any command menu, and then press the “ENT” to enter the menu;
4.
Press the “▲” or “▼” to move the cursor;
5.
Press the “+” or “-” to page up/down;
6.
Press the “◄” or “►” to select pervious or next command menu;
7.
Press the “ESC” to exit this menu (returning to the menu “Settings”). Note! If the displayed information exceeds 14 lines, the scroll bar will appear on the right side of the LCD to indicate the quantity of all displayed information of the command menu and the relative location of information where the current cursor points at.
8.4.6 Modify Device Setting The operation is as follows: 1.
Press the “▲” to enter the main menu;
2.
Press the “▲” or “▼” to move the cursor to the “Settings” menu, and then press the “ENT” or “►” to enter the menu;
3.
Press the “▲” or “▼” to move the cursor to any command menu, and then press the “ENT” to enter the menu;
4.
Press the “▲” or “▼” to move the cursor;
5.
Press the “+” or “-” to page up/down;
6.
Press the “◄” or “►” to select pervious or next command menu;
7.
Press the “ESC” to exit this menu (returning to the menu “Settings” );
8.
If selecting the command menu “System Settings”, move the cursor to the setting item to be modified, and then press the “ENT”;
Press the “+” or “-” to modify the value (if the modified value is of multi-bit, press the “◄” or “►” to move the cursor to the digit bit, and then press the “+” or “-” to modify the value), press the “ESC” to cancel the modification and return to the displayed interface of the command menu “System Settings”. Press the “ENT” to automatically exit this menu (returning to the displayed interface of the command menu “System Settings”). Move the cursor to continue modifying other setting items. After all setting values are modified, press the “◄”, “►” or “ESC”, and the LCD will display “Save or Not?”. Directly press the “ESC” or
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press the “◄” or “►” to move the cursor. Select the “Cancel”, and then press the “ENT” to automatically exit this menu (returning to the displayed interface of the command menu “System Settings”). Press the “◄” or “►” to move the cursor. Select “No” and press the “ENT”, all modified setting item will restore to its original value, exit this menu (returning to the menu “Settings”). Press the “◄” or “►” to move the cursor to select “Yes”, and then press the “ENT”, the LCD will display password input interface.
Password:
____
Input a 4-bit password (“+”, “◄”, “▲” and “-”). If the password is incorrect, continue inputting it, and then press the “ESC” to exit the password input interface and return to the displayed interface of the command menu “System Settings”. If the password is correct, LCD will display “Save Setting Now…”, and then exit this menu (returning to the displayed interface of the command menu “System Settings”), with all modified setting items as modified values. Note! For different setting items, their displayed interfaces are different but their modification methods are the same. The following is ditto. 9.
If selecting the submenu “Prot Settings”, and press “ENT” to enter. After selecting different command menu, the LCD will display the following interface: (take “FD Settings” as an example)
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Line Settings
Please Select Group for Config Active Group:
01
Selected Group:
02
Press the “+” or “-” to modify the value, and then press the “ENT” to enter it. Move the cursor to the setting item to be modified, press the “ENT” to enter. Take the setting [FD.DPFC.I_Set] as an example is selected to modify, then press the “ENT” to enter and the LCD will display the following interface. is shown the “+” or “-” to modify the value and then press the “ENT” to confirm.
FD.DPFC.I_Set
Current Value
0.200
Modified Value
0.202
Min Value
0.050
Max Value
30.000
Note! After modifying protection settings in current active setting group or system parameters of the device, the “HEALTHY” LED indicator the device will be lit off, and the MON module will check the new settings. If the abnormality is detected during the setting check, corresponding alarm signals will be issued. Moreover, if the critical error is detected, the device will be blocked.
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8.4.7 Copy Device Setting The operation is as follows: 1.
Press the “▲” to enter the main menu;
2.
Press the “▲” or “▼” to move the cursor to the “Settings” menu, and then press the “ENT” or “►” to enter the menu;
3.
Press the “▲” or “▼” to move the cursor to the command menu “Copy Settings”, and then press the “ENT” to enter the menu.
Copy Settings Active Group:
01
Copy To Group:
02
Press the “+” or “-” to modify the value. Press the “ESC”, and return to the menu “Settings”. Press the “ENT”, the LCD will display the interface for password input, if the password is incorrect, continue inputting it, press the “ESC” to exit the password input interface and return to the menu “Settings”. If the password is correct, the LCD will display “copy setting OK!”, and exit this menu (returning to the menu “Settings”).
8.4.8 Switch Setting Group The operation is as follows: 1.
Exit the main menu;
2.
Press the “GRP”
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Change Active Group
Active Group:
01
Change To Group:
02
Press the “+” or “-” to modify the value, and then press the “ESC” to exit this menu (returning to the main menu). After pressing the “ENT”, the LCD will display the password input interface. If the password is incorrect, continue inputting it, and then press the “ESC” to exit the password input interface and return to its original state. If the password is correct, the “HEALTHY” indicator lamp of the protection device will go out, and the protection device will re-check the protection setting. If the check doesn’t pass, the protection device will be blocked. If the check is successful, the LCD will return to its original state.
8.4.9 Delete Device Records The operation is as follows: 1.
Exit the main menu;
2.
Press the “+”, “-”, “+”, “-” and “ENT”; Press the “ESC” to exit this menu (returning to the original state). Press the “ENT” to carry out the deletion.
Press To Clear Press To Exit
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Note! The operation of deleting device message will delete all messages saved by the protection device, including disturbance records, supervision events, binary events, but not including device logs. Furthermore, the message is irrecoverable after deletion, so the application of the function shall be cautious.
8.4.10 Remote Control Control operation method is introduced as below: 1.
Press the key “▲” to enter the main menu.
2.
Press the key “▲” or “▼” to move the cursor to the command menu “Local Cmd”, and then press the key “ENT” to enter submenus. Press the key “▲” or “▼” to move the cursor to the command menu “Control”, and then press the key “ENT” to enter and the following display will be shown on LCD.
Password: 000
Input a 3-bit password (“111”). If the password is incorrect, continue inputting it, and then press the “ESC” to exit the password input interface and return to the displayed interface of the command menu “Control”. If the password is correct, it will go to the following step. 3.
Press the key “▲” or “▼” to move the cursor to the control object and press the key “ENT” to select control object.
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Control
4.
1.
Step1: select Control Object CSWI01
2.
CSWI02
3.
CSWI03
4.
CSWI04
5.
CSWI05
6.
CSWI06
7.
CSWI07
8.
CSWI08
9.
CSWI09
10.
CSWI10
Press the key “◄” or “►” to select control command press the key “ENT” to the next step.
Three control commands are optional: 1) Open (Step down): Remote open 2) Close (Step up): Remote close 3) Stop: Reserved CSWI01 Step2: select Control Command Open(Lower)
Close(Raise)
NoCheck
SynchroCheck
LoopCheck
EF Line Selection
InterlockChk
InterlockNotChk
Select
Execute
(Stop) DeadCheck
Cancel
Result
5.
Press the key “◄” or “►” to select synchronism check mode and press the key “ENT” to the next step.
Five synchronism check modes are optional: 1) NoCheck: Without any check 2) SynchroCheck: Synchronism-check mode
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3) DeadCheck: Dead check mode 4) LoopCheck: Reserved 5) EF Line Selection: Reserved CSWI01 Step3: select Execution Condition Open(Lower)
Close(Raise)
NoCheck
SynchroCheck
LoopCheck
EF Line Selection
InterlockChk
InterlockNotChk
Select
Execute
(Stop) DeadCheck
Cancel
Result
6.
Press the key “◄” or “►” to select interlock mode and press the key “ENT” to next step.
Two interlock check modes are optional: 1) InterlockChk: Check interlocking criteria 2) InterlockNotChk: Not check interlocking criteria CSWI01 Step4: select Interlock Condition Open(Lower)
Close(Raise)
NoCheck
SynchroCheck
LoopCheck
EF Line Selection
InterlockChk
InterLockNotChk
Select
Execute
(Stop) DeadCheck
Cancel
Result
7.
Press the key “◄” or “►” to select control type and press the key “ENT”.
As shown in the following figure, operation results will be shown after “Result” at the bottom of the LCD.
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Three synchronism control types are optional: 1) Select: Select control object 2) Execute: Execute control operation 3) Cancel: Cancel control operation CSWI01 Step5: select Control Type Open(Lower)
Close(Raise)
NoCheck
SynchroCheck
LoopCheck
EF Line Selection
InterlockChk
InterLockNotChk
Select
Execute
(Stop) DeadCheck
Cancel
Result
Note! “Exectue” operation must be operated after “Select” operation.
8.4.11 Modify Device Clock The operation is as follows: 1.
Press the “▲” to enter the main menu;
2.
Press the “▲” or “▼” to move the cursor to the “Clock” menu, and then press the “ENT” to enter clock display
3.
Press the “▲” or “▼” to move the cursor to the date or time to be modified;
4.
Press the “+” or “-” to modify value, and then press the “ENT” to save the modification and return to the main menu;
5.
Press the “ESC” to cancel the modification and return to the main menu.
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Clock Year:
2008
Month:
11
Day:
28
Hour:
20
Minute:
59
Second:
14
8.4.12 View Module Information The operation is as follows: 1.
Press the “▲” to enter the main menu;
2.
Press the “▲” or “▼” to move the cursor to the “Information” menu, and then press the “ENT” or “►” to enter the menu;
3.
Press the “▲” or “▼” to move the cursor to the command menu “Board Info”, and then press the “ENT” to enter the menu;
4.
Press the “▲” or “▼” to move the scroll bar;
5.
Press the “ENT” or “ESC” to exit this menu (returning to the “Information” menu).
8.4.13 Check Software Version The operation is as follows: 1.
Press the “▲” to enter the main menu.
2.
Press the “▲” or “▼” to move the cursor to the “Information” menu, and then press the “ENT” to enter the submenu.
3.
Press the key “▲” or “▼” to move the cursor to the command menu “Version Info”, and then press the key “ENT” to display the software version.
4.
Press the “ESC” to return to the main menu.
8.4.14 Communication Test The operation is as follows: 1.
Press the key “▲” to enter the main menu.
2.
Press the key “▲” or “▼” to move the cursor to the “Test” menu, and then press the key “ENT” or “►” to enter the menu.
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3.
Press the key “▲” or “▼” to move the cursor to the submenu “Device Test”, and then press the key “ENT” to enter the submenu,to select test item. If “Disturb Events” “Superv Events” or “IO Events” is selected, two options “All Test” and “Select Test” are provided.
4.
Press the key “▲” or “▼” to move the cursor to select the corresponding command menu “All Test” or “Select Test”. If selecting the “All Test”, press the “ENT”, and the device will successively carry out all operation element message test one by one.
5.
If “Select Test” is selected, press the key “ENT”. Press the “+” or “-” to page up/down, and then press the key “▲” or “▼” to move the scroll bar. Move the cursor to select the corresponding protection element. Press the key “ENT” to execute the communication test of this protection element, the substation automatic system (SAS) will receive the corresponding message. Note! If no input operation is carried out within 60s, exit the communication transmission and return to the “Test” menu, at this moment, the LCD will display “Communication Test Timeout and Exiting...”.
Press the key “ESC” to exit this menu (returning to the menu “Test”, at this moment, the LCD will display “Communication Test Exiting…”.
8.4.15 Select Language The operation is as follows: 1.
Press the key “▲” to enter the main menu.
2.
Press the key “▲” or “▼” to move the cursor to the command menu “Language”, and then press the key “ENT” to enter the menu and the following display will be shown on LCD.
Please Select Language: 1
中文
2
English
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3.
Press the key “▲” or “▼” to move the cursor to the language user preferred and press the key “ENT” to execute language switching. After language switching is finished, LCD will return to the menu “Language”, and the display language is changed. Otherwise, press the key “ESC” to cancel language switching and return to the menu “Language”. Note! LCD interface provided in this chapter is only a reference and available for explaining specific definition of LCD. The displayed interface of the actual device may be some different from it, so you shall be subject to the actual protection device.
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9 Configurable Function Table of Contents 9 Configurable Function ...................................................................... 9-a 9.1 Overview .......................................................................................................... 9-1 9.2 Introduction on PCS-Explorer Software ........................................................ 9-1 9.3 Signal List ........................................................................................................ 9-1 9.3.1 Input Signal .......................................................................................................................... 9-2 9.3.2 Output Signal ..................................................................................................................... 9-10
List of Tables Table 9.3-1 Input signals ............................................................................................................. 9-2 Table 9.3-2 Output signals ........................................................................................................ 9-10
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9 Configurable Function
9.1 Overview By adoption of PCS-Explorer software, it is able to make device configuration, function configuration, LCD configuration, binary input and binary output configuration, LED indicator configuration and programming logic for PCS-931.
9.2 Introduction on PCS-Explorer Software PCS-Explorer software is developed in order to meet customer’s demand on functions of UAPC platform device such as device configuration and programmable design. It selects substation as the core of data management and the device as fundamental unit, supporting one substation to govern many devices. The software provides on-line and off-line functions: on-line mode: Ethernet connected with the device supporting IEC60870-5-103 and capable of uploading and downloading configuration files through Ethernet net; off-line mode: off-line setting configuration. In addition, it also supports programmable logic to meet customer’s demand. After function configuration is finished, disabled protection function will be hidden in the device and in setting configuration list of PCS-Explorer Software. The user can select to show or hide some setting by this way, and modify the setting value. Please refer to the instruction manual “PCS-Explorer Auxiliary Software” for details. Overall functions:
Programmable logic (off-line function)
Device configuration (off-line function)
Function configuration (off-line function)
LCD configuration (off-line function)
LED indicators configuration (off-line function)
Binary signals configuration (off-line function)
Setting configuration (off-line & on-line function)
Real-time display of analogue and digital quantity of device (on-line function)
Display of sequence of report (SOE) (on-line function)
Analysis of waveform (off-line & on-line function)
File downloading/uploading (on-line function)
9.3 Signal List If an input signal or output signal is gray in PCS-Explorer, it means that the input signal or output PCS-931 Line Differential Relay
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9 Configurable Function
signal is not configurable. Otherwise, it is configurable signal.
9.3.1 Input Signal All input signals of this device are listed in the following table. Table 9.3-1 Input signals No.
Item
Description Circuit breaker position supervision
1
52b_PhA
Normally closed auxiliary contact of phase A of corresponding circuit breaker
2
52b_PhB
Normally closed auxiliary contact of phase B of corresponding circuit breaker
3
52b_PhC
Normally closed auxiliary contact of phase C of corresponding circuit breaker
4
ManCls
External manual closing binary input, it is only applied to SOTF logic
5
52b
Normally closed contact of three-phase of circuit breaker
6
52a
Normally open contact of three-phase of circuit breaker Control circuit failure (normally closed contact and normally open contact of
7
TCCS.Input
three-phase circuit breaker are all de-energized due to DC power loss of control circuit) Auxiliary element
8
AuxE.OCD.En
9
AuxE.OCD.Blk
10
AuxE.ROC1.En
11
AuxE.ROC1.Blk
12
AuxE.ROC2.En
13
AuxE.ROC2.Blk
14
AuxE.ROC3.En
15
AuxE.ROC3.Blk
16
AuxE.OC1.En
17
AuxE.OC1.Blk
18
AuxE.OC2.En
19
AuxE.OC2.Blk
20
AuxE.OC3.En
Current change auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Current change auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 1 of residual current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 1 of residual current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 2 of residual current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 2 of residual current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 3 of residual current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 3 of residual current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 1 of phase current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 1 of phase current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 2 of phase current auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Stage 2 of phase current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Stage 3 of phase current auxiliary element enabling input, it is triggered from
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9 Configurable Function No.
Item
Description binary input or programmable logic etc.
21
AuxE.OC3.Blk
22
AuxE.UVD.En
23
AuxE.UVD.Blk
24
AuxE.UVG.En
25
AuxE.UVG.Blk
26
AuxE.UVS.En
27
AuxE.UVS.Blk
28
AuxE.ROV.En
29
AuxE.ROV.Blk
Stage 3 of phase current auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Voltage change auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Voltage change auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Phase-to-ground under voltage auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Phase-to-ground under voltage auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Phase-to-phase under voltage auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Phase-to-phase under voltage auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Residual voltage auxiliary element enabling input, it is triggered from binary input or programmable logic etc. Residual voltage auxiliary element blocking input, it is triggered from binary input or programmable logic etc. Distance protection DPFC distance protection enabling input, it is triggered from binary input or
30
21D.En_DPFC
31
21D.Blk_DPFC
32
LoadEnch.En
33
LoadEnch.Blk
34
21M.En
35
21M.Blk
36
21M.ZGx.En
37
21M.ZGx.Blk
38
21M.ZPx.En
39
21M.ZPx.Blk
40
21M.Zx.En_ShortDly
Enable accelerating zone x of distance protection (x=2, 3)
41
21M.Zx.Blk_ShortDly
Accelerating zone x of distance protection is disabled (x=2, 3)
programmable logic etc. DPFC distance protection blocking input, it is triggered from binary input or programmable logic etc. Load trapezoid characteristic enabling input, it is triggered from binary input or programmable logic etc. Load trapezoid characteristic blocking input, it is triggered from binary input or programmable logic etc. Distance protection enabling input, it is triggered from binary input or programmable logic etc. Distance protection blocking input, it is triggered from binary input or programmable logic etc. Zone x of phase-to-ground distance protection enabling input, default value is “1” (x=1, 2, 3, 4) Zone x of phase-to-ground distance protection blocking input, default value is “0” (x=1, 2, 3, 4) Zone x of phase-to-phase distance protection enabling input, default value is “1” (x=1, 2, 3, 4) Zone x of phase-to-phase distance protection blocking input, default value is “0” (x=1, 2, 3, 4)
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9 Configurable Function No.
Item
Description
42
21M.Z1.En_Instant
Enable zone 1 of distance protection operates without time delay
43
21Q.En
44
21Q.Blk
45
21Q.ZGx.En
46
21Q.ZGx.Blk
47
21Q.ZPx.En
48
21Q.ZPx.Blk
49
21Q.Zx.En_ShortDly
Enable accelerating zone x of distance protection (x=2, 3)
50
21Q.Zx.Blk_ShortDly
Accelerating zone x of distance protection is disabled (x=2, 3)
51
21Q.Z1.En_Instant
Enable zone 1 of distance protection operates without time delay
52
68.En
53
68.Blk
54
21M.En_PSBR
Enabling power swing blocking releasing (Mho characteristic)
55
21Q.En_PSBR
Enabling power swing blocking releasing (Quad characteristic)
56
21M.Blk_PSBR
Blocking power swing blocking releasing (Mho characteristic)
57
21Q.Blk_PSBR
Blocking power swing blocking releasing (Quad characteristic)
58
21SOTF.En
59
21SOTF.Blk
Distance protection enabling input, it is triggered from binary input or programmable logic etc. Distance protection blocking input, it is triggered from binary input or programmable logic etc. Zone x of phase-to-ground distance protection enabling input, default value is “1” (x=1, 2, 3, 4) Zone x of phase-to-ground distance protection blocking input, default value is “0” (x=1, 2, 3, 4) Zone x of phase-to-phase distance protection enabling input, default value is “1” (x=1, 2, 3, 4) Zone x of phase-to-phase distance protection blocking input, default value is “0” (x=1, 2, 3, 4)
Power swing detection enabling input, it is triggered from binary input or programmable logic etc. Power swing detection blocking input, it is triggered from binary input or programmable logic etc.
Distance SOTF protection enabling input, it is triggered from binary input or programmable logic etc. Distance SOTF protection blocking input, it is triggered from binary input or programmable logic etc. Optical pilot channel
60
FOx.En
Enabling channel x
61
FOx.Send1
Sending signal 1 of channel x
62
FOx.Send2
Sending signal 2 of channel x
63
FOx.Send3
Sending signal 3 of channel x
64
FOx.Send4
Sending signal 4 of channel x
65
FOx.Send5
Sending signal 5 of channel x
66
FOx.Send6
Sending signal 6 of channel x
67
FOx.Send7
Sending signal 7 of channel x
68
FOx.Send8
Sending signal 8 of channel x Current differential protection
69
87L.En1
70
87L.En2
Current differential protection enabling input 1, it is triggered from binary input or programmable logic etc. Current differential protection enabling input 2, it can be a binary inputs or a
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9 Configurable Function No.
Item
Description logic link.
71
87L.Blk
Current differential protection blocking input, it is triggered from binary input or programmable logic etc. Phase overcurrent protection
72
50/51Px.En1
73
50/51Px.En2
74
50/51Px.Blk
Stage x of phase overcurrent protection enabling input 1, it is triggered from binary input or programmable logic etc. Stage x of phase overcurrent protection enabling input 2, it is triggered from binary input or programmable logic etc. Stage x of phase overcurrent protection blocking input, it is triggered from binary input or programmable logic etc. Earth fault protection
75
50/51Gx.En1
76
50/51Gx.En2
77
50/51Gx.Blk
Stage x of earth fault protection enabling input 1, it is triggered from binary input or programmable logic etc. Stage x of earth fault protection enabling input 2, it is triggered from binary input or programmable logic etc. Stage x of earth fault protection blocking input, it is triggered from binary input or programmable logic etc. Overcurrent protection for VT circuit failure
78
50PVT.En1
79
50PVT.En2
80
50PVT.Blk
81
50GVT.En1
82
50GVT.En2
83
50GVT.Blk
Phase overcurrent protection for VT circuit failure enabling input 1, it is triggered from binary input or programmable logic etc. Phase overcurrent protection for VT circuit failure enabling input 2, it is triggered from binary input or programmable logic etc. Phase overcurrent protection for VT circuit failure blocking input, it is triggered from binary input or programmable logic etc. Ground overcurrent protection for VT circuit failure enabling input 1, it is triggered from binary input or programmable logic etc. Ground overcurrent protection for VT circuit failure enabling input 2, it is triggered from binary input or programmable logic etc. Ground overcurrent protection for VT circuit failure blocking input, it is triggered from binary input or programmable logic etc. Residual SOTF protection
84
50GSOTF.En1
85
50GSOTF.En2
86
50GSOTF.Blk
Residual current SOTF protection enabling input 1, it is triggered from binary input or programmable logic etc. Residual current SOTF protection enabling input 2, it is triggered from binary input or programmable logic etc. Residual current SOTF protection blocking input, it is triggered from binary input or programmable logic etc. Voltage protection
87
59Px.En1
88
59Px.En2
Stage x of overvoltage protection enabling input 1, it is triggered from binary input or programmable logic etc. Stage x of overvoltage protection enabling input 2, it is triggered from binary input or programmable logic etc.
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9 Configurable Function No.
Item
89
59Px.Blk
90
27Px.En1
91
27Px.En2
92
27Px.Blk
Description Stage x of overvoltage protection blocking input, it is triggered from binary input or programmable logic etc. Stage x of undervoltage protection enabling input 1, it is triggered from binary input or programmable logic etc. Stage x of undervoltage protection enabling input 2, it is triggered from binary input or programmable logic etc. Stage x of undervoltage protection blocking input, it is triggered from binary input or programmable logic etc. Frequency protection
93
81U.En1
94
81U.En2
95
81U.Blk
96
81O.En1
97
81O.En2
98
81O.Blk
Underfrequency protection enabling input 1, it is triggered from binary input or programmable logic etc. Underfrequency protection enabling input 2, it is triggered from binary input or programmable logic etc. Underfrequency protection blocking input, it is triggered from binary input or programmable logic etc. Overfrequency protection enabling input 1, it is triggered from binary input or programmable logic etc. Overfrequency protection enabling input 2, it is triggered from binary input or programmable logic etc. Overfrequency protection blocking input, it is triggered from binary input or programmable logic etc. Breaker failure protection
99
50BF.ExTrp3P_L
Input signal of three-phase tripping contact from line protection Input signal of three-phase tripping contact from generator or transformer
100
50BF.ExTrp3P_GT
101
50BF.ExTrpA
Input signal of phase-A tripping contact from external device
102
50BF.ExTrpB
Input signal of phase-B tripping contact from external device
103
50BF.ExTrpC
Input signal of phase-C tripping contact from external device
protection
Input signal of three-phase tripping contact from external device. Once it is 104
50BF.ExTrp_WOI
energized, normally closed auxiliary contact of circuit breaker is chosen in addition to breaker failure current check to trigger breaker failure timers.
105
50BF.En
Input signal of enabling breaker failure protection Breaker failure protection blocking input, such as function blocking binary
106
50BF.Blk
input. When the input is 1, breaker failure protection is reset and time delay is cleared. Thermal overload protection
107
49.Clr_Cmd
108
49.En
109
49.Blk
Input signal of clear thermal accumulation value Thermal overload protection enabling input, it is triggered from binary input or programmable logic etc. Thermal overload protection blocking input, it is triggered from binary input or programmable logic etc.
9-6
PCS-931 Line Differential Relay Date: 2013-12-27
9 Configurable Function No.
Item
Description Stub overcurrent protection
110
50STB.En1
111
50STB.En2
112
50STB.Blk
113
50STB.89b_DS
Stub overcurrent protection enabling input 1, it is triggered from binary input or programmable logic etc. Stub overcurrent protection enabling input 2, it is triggered from binary input or programmable logic etc. Stub overcurrent protection blocking input, it is triggered from binary input or programmable logic etc. Normally closed auxiliary contact of line disconnector Dead zone protection
114
50DZ.En1
Dead zone protection enabling input 1, it can be binary inputs or logic link.
115
50DZ.En2
Dead zone protection enabling input 2, it can be binary inputs or logic link.
116
50DZ.Blk
117
50DZ.Init
Dead zone protection blocking input, such as function blocking binary input. When the input is 1, dead zone protection is reset and time delay is cleared. Initiation signal input of the dead zone protection. Pole discrepancy protection
118
62PD.En1
119
62PD.En2
120
62PD.Blk
Pole discrepancy protection enabling input 1, it is triggered from binary input or programmable logic etc. Pole discrepancy protection enabling input 2, it is triggered from binary input or programmable logic etc. Pole discrepancy protection blocking input, it is triggered from binary input or programmable logic etc. Broken conductor protection
121
46BC.En1
122
46BC.En2
123
46BC.Blk
Enable broken conductor protection input 1, it is triggered from binary input or programmable logic etc. Enable broken conductor protection input 2, it is triggered from binary input or programmable logic etc. Broken conductor protection blocking input, it is triggered from binary input or programmable logic etc. Reverse power protection
124
32R1.En
125
32R1.Blk
126
32R2.En
127
32R2.Blk
Enable stage 1 of reverse power protection input 1, it is triggered from binary input or programmable logic etc. Stage 1 of reverse power protection blocking input, it is triggered from binary input or programmable logic etc. Enable stage 2 of reverse power protection input 2, it is triggered from binary input or programmable logic etc. Stage 2 of reverse power protection blocking input, it is triggered from binary input or programmable logic etc. Synchrocheck function
128
25.Blk_Chk
129
25.Blk_SynChk
130
25.Blk_DdChk
Input signal of blocking synchrocheck function for AR Input signal of blocking synchronism check for AR. If the value is “1”, the output of synchronism check is “0” Input signal of blocking dead charge check for AR
PCS-931 Line Differential Relay
9-7 Date: 2013-12-27
9 Configurable Function No.
Item
Description Input signal of starting synchronism check, usually it was starting signal of AR
131
25.Start_Chk
132
25.Blk_VTS_UB
VT circuit supervision (UB) is blocked
133
25.Blk_VTS_UL
VT circuit supervision (UL) is blocked
134
25.MCB_VT_UB
Binary input for VT MCB auxiliary contact (UB)
135
25.MCB_VT_UL
Binary input for VT MCB auxiliary contact (UL)
from auto-reclosing module
Auto-reclosing Binary input for enabling AR. If the logic setting [79.En_ExtCtrl]=1, enabling
136
79.En
137
79.Blk
138
79.Sel_1PAR
Input signal for selecting 1-pole AR mode of corresponding circuit breaker
139
79.Sel_3PAR
Input signal for selecting 3-pole AR mode of corresponding circuit breaker
140
79.Sel_1P/3PAR
Input signal for selecting 1/3-pole AR mode of corresponding circuit breaker
141
79.Trp
Input signal of single-phase tripping from line protection to initiate AR
142
79.Trp3P
Input signal of three-phase tripping from line protection to initiate AR
143
79.TrpA
Input signal of A-phase tripping from line protection to initiate AR
144
79.TrpB
Input signal of B-phase tripping from line protection to initiate AR
145
79.TrpC
Input signal of C-phase tripping from line protection to initiate AR
AR will be controlled by the external signal via binary input Binary input for disabling AR. If the logic setting [79.En_ExtCtrl]=1, disabling AR will be controlled by the external input
Input signal of blocking reclosing, usually it is connected with the operating 146
79.LockOut
signals of definite-time protection, transformer protection and busbar differential protection, etc.
147
79.PLC_Lost
Input signal of indicating the alarm signal that signal channel is lost
148
79.WaitMaster
149
79.CB_Healthy
150
79.Clr_Counter
Clear the reclosing counter
151
79.Ok_Chk
Synchrocheck condition of AR is met
Input signal of waiting for reclosing permissive signal from master AR (when reclosing multiple circuit breakers) The input for indicating whether circuit breaker has enough energy to perform the close function
Transfer trip 152
TT.Init
153
TT.En
154
TT.Blk
Input signal of initiating transfer trip after receiving transfer trip Transfer trip enabling input, it is triggered from binary input or programmable logic etc. Transfer trip blocking input, it is triggered from binary input or programmable logic etc. VT circuit supervision
155
VTS.En
156
VTS.Blk
157
VTNS.En
VT supervision enabling input, it is triggered from binary input or programmable logic etc. VT supervision blocking input, it is triggered from binary input or programmable logic etc. VT neutral point supervision enabling input, it is triggered from binary input or programmable logic etc.
9-8
PCS-931 Line Differential Relay Date: 2013-12-27
9 Configurable Function No.
Item
158
VTNS.Blk
159
VTS.MCB_VT
Description VT neutral point supervision blocking input, it is triggered from binary input or programmable logic etc. Binary input for VT MCB auxiliary contact CT circuit supervision
160
CTS.En
161
CTS.Blk
CT circuit supervision enabling input, it is triggered from binary input or programmable logic etc. CT circuit supervision blocking input, it is triggered from binary input or programmable logic etc. Control and Synchrocheck for Manual Closing
162
CSWIxx.CILO.EnOpn
It is the interlock status of No.xx open output of BO module (xx=01~10)
163
CSWIxx.CILO.EnCls
It is the interlock status of No.xx closing output of BO module (xx=01~10) From receiving a closing command, this device will continuously check whether the 2 voltages (Incoming voltage and reference voltage) involved in synchronism check(or dead check) can meet the criteria.
164
Sig_Ok_Chk
Within the duration of [MCBrd.25.t_Wait_Chk], if the synchronism check(or dead check) criteria are not met, [Sig_Ok_Chk] will be set as “0”; if the synchronism check(or dead check) criteria are met, [Sig_Ok_Chk] will be set as “1”. It is used to select the local control to No.xx controlled object (CB/DS/ES).
165
CSWIxx.LocCtrl
When the local control is active, No.xx binary outputs can only be locally controlled. It is used to select the remote control to No.xx controlled object (CB/DS/ES).
166
CSWIxx.RmtCtrl
When the remote control is active, No.xx binary outputs can only be remotely controlled by SCADA or control centers. It is used to disable the interlock blocking function for control output. If the
167
CSWIxx.CILO.Disable
signal “CSWIxx.CILO.Disable” is “1”, No.xx binary outputs of the device will not be blocked by interlock conditions. It is used to select the remote control to controlled object (CB/DS/ES). When
168
BIinput.RmtCtrl
the remote control is active, all binary outputs can only be remotely controlled by SCADA or control centers.
169
BIinput.LocCtrl
It is used to select the local control to controlled object (CB/DS/ES). When the local control is active, all binary outputs can only be locally controlled. It is used to disable the interlock blocking function for control output. If the
170
BIinput.CILO.Disable
signal “BIinput.CILO.Disable” is “1”, all binary outputs of this device will not be blocked by interlock conditions. When
171
CSWI01.ManSynCls
the
condition
of
local
control
is
met
and
the
signal
“CSWI01.ManSynCls” is “1”, the output contact [BO_CtrlCls01] is closed to execute manually closing the circuit breaker with synschrochcek. When the condition of local control is met and the signal “CSWI01.ManOpn” is
172
CSWI01.ManOpn
“1”, the output contact [BO_CtrlOpn01] is closed to execute manually open the circuit breaker.
PCS-931 Line Differential Relay
9-9 Date: 2013-12-27
9 Configurable Function
9.3.2 Output Signal All output signals of this device have been listed in the following table. Table 9.3-2 Output signals No.
Signal
Description Circuit breaker position supervision
1
Alm_52b
CB position is abnormal
2
TCCS.Alm
Control circuit of circuit breaker is abnormal Fault detector
3
FD.Pkp
The device picks up
4
FD.DPFC.Pkp
DPFC current fault detector element operates.
5
FD.ROC.Pkp
Residual current fault detector element operates. Auxiliary element
6
AuxE.St
Any auxiliary element of the device operates
7
AuxE.OCD.St_Ext
Current change auxiliary element operates (7s delayed drop off).
8
AuxE.OCD.On
Current change auxiliary element is enabled
9
AuxE.ROC1.St
Stage 1 of residual current auxiliary element operates.
10
AuxE.ROC1.On
Stage 1 of residual current auxiliary element is enabled
11
AuxE.ROC2.St
Stage 2 of residual current auxiliary element operates.
12
AuxE.ROC2.On
Stage 2 of residual current auxiliary element is enabled
13
AuxE.ROC3.St
Stage 3 of residual current auxiliary element operates.
14
AuxE.ROC3.On
Stage 3 of residual current auxiliary element is enabled
15
AuxE.OC1.St
Stage 1 of phase current auxiliary element operates.
16
AuxE.OC1.StA
Stage 1 of phase current auxiliary element operates (phase A)
17
AuxE.OC1.StB
Stage 1 of phase current auxiliary element operates (phase B)
18
AuxE.OC1.StC
Stage 1 of phase current auxiliary element operates (phase C)
19
AuxE.OC1.On
Stage 1 of phase current auxiliary element is enabled
20
AuxE.OC2.St
Stage 2 of phase current auxiliary element operates.
21
AuxE.OC2.StA
Stage 2 of phase current auxiliary element operates (phase A)
22
AuxE.OC2.StB
Stage 2 of phase current auxiliary element operates (phase B)
23
AuxE.OC2.StC
Stage 2 of phase current auxiliary element operates (phase C)
24
AuxE.OC2.On
Stage 2 of phase current auxiliary element is enabled
25
AuxE.OC3.St
Stage 3 of phase current auxiliary element operates
26
AuxE.OC3.StA
Stage 1 of phase current auxiliary element operates (phase A)
27
AuxE.OC3.StB
Stage 1 of phase current auxiliary element operates (phase B)
28
AuxE.OC3.StC
Stage 1 of phase current auxiliary element operates (phase C)
29
AuxE.OC3.On
Stage 3 of phase current auxiliary element is enabled
30
AuxE.UVD.St
Voltage change auxiliary element operates.
31
AuxE.UVD.St_Ext
Voltage change auxiliary element operates (7s delayed drop off)
32
AuxE.UVD.On
Voltage change auxiliary element is enabled
33
AuxE.UVG.St
Phase-to-ground under voltage auxiliary element operates.
34
AuxE.UVG.StA
Phase-to-ground under voltage auxiliary element operates (phase A)
9-10
PCS-931 Line Differential Relay Date: 2013-12-27
9 Configurable Function No.
Signal
Description
35
AuxE.UVG.StB
Phase-to-ground under voltage auxiliary element operates (phase B)
36
AuxE.UVG.StC
Phase-to-ground under voltage auxiliary element operates (phase C)
37
AuxE.UVG.On
Phase-to-ground under voltage auxiliary element is enabled
38
AuxE.UVS.St
Phase-to-phase under voltage auxiliary element operates.
39
AuxE.UVS.StAB
Phase-to-phase under voltage auxiliary element operates (phase AB)
40
AuxE.UVS.StBC
Phase-to-phase under voltage auxiliary element operates (phase BC)
41
AuxE.UVS.StCA
Phase-to-phase under voltage auxiliary element operates (phase CA)
42
AuxE.UVS.On
Phase-to-phase under voltage auxiliary element is enabled
43
AuxE.ROV.St
Residual voltage auxiliary element operates.
44
AuxE.ROV.On
Residual voltage auxiliary element is enabled Distance protection
45
21D.Op_DPFC
DPFC distance protection operates.
46
21D.On
DPFC distance protection is enabled.
47
LoadEnch.St
Measured impedance into the load area
48
21M.Z1.On
Zone 1 of distance protection is enabled
49
21M.Z2.On
Zone 2 of distance protection is enabled
50
21M.Z3.On
Zone 3 of distance protection is enabled
51
21M.Z4.On
zone 4 of distance protection is enabled
52
21M.Z1.Op
Zone 1 of distance protection operates
53
21M.Z2.Op
Zone 2 of distance protection operates
54
21M.Z3.Op
Zone 3 of distance protection operates
55
21M.Z4.Op
zone 4 of distance protection operates
56
21Q.Z1.On
Zone 1 of distance protection is enabled
57
21Q.Z2.On
Zone 2 of distance protection is enabled
58
21Q.Z3.On
Zone 3 of distance protection is enabled
59
21Q.Z4.On
zone 4 of distance protection is enabled
60
21Q.Z1.Op
Zone 1 of distance protection operates
61
21Q.Z2.Op
Zone 2 of distance protection operates
62
21Q.Z3.Op
Zone 3 of distance protection operates
63
21Q.Z4.Op
zone 4 of distance protection operates
64
68.St
Power swing detection takes into effect.
65
21M.Z1.Rls_PSBR
PSBR operates to release zone 1 (Mho characteristic)
66
21Q.Z1.Rls_PSBR
PSBR operates to release zone 1 (Quad characteristic)
67
21M.Z2.Rls_PSBR
PSBR operates to release zone 2 (Mho characteristic)
68
21Q.Z2.Rls_PSBR
PSBR operates to release zone 2 (Quad characteristic)
69
21M.Z3.Rls_PSBR
PSBR operates to release zone 3 (Mho characteristic)
70
21Q.Z3.Rls_PSBR
PSBR operates to release zone 3 (Quad characteristic)
71
21SOTF.Op
72
21SOTF.Op_PDF
73
21SOTF.On
Accelerate distance protection to trip when manual closing or auto-reclosing to fault Accelerate distance protection to trip when another fault happening under pole discrepancy conditions Accelerate distance protection is enabled.
PCS-931 Line Differential Relay
9-11 Date: 2013-12-27
9 Configurable Function No.
Signal
Description Optical pilot channel
74
FOx.On
Channel x is enabled.
75
FOx.Recv1
Receiving signal 1 of channel x
76
FOx.Recv2
Receiving signal 2 of channel x
77
FOx.Recv3
Receiving signal 3 of channel x
78
FOx.Recv4
Receiving signal 4 of channel x
79
FOx.Recv5
Receiving signal 5 of channel x
80
FOx.Recv6
Receiving signal 6 of channel x
81
FOx.Recv7
Receiving signal 7 of channel x
82
FOx.Recv8
Receiving signal 8 of channel x
83
FOx.Alm
Channel x is abnormal
84
FOx.Alm_ID
Received ID from the remote end is not as same as the setting [FO.RmtID] of the device in local end Current differential protection
85
87L.On
Current differential protection is enabled Current
86
87L.Op
differential
protection
“[87L.Op_DPFC1],
operates,
if
[87L.Op_DPFC2],
any
of
them
[87L.Op_Biased1],
[87L.Op_Biased2], [87L.Op_Neutral], [87L.Op_InterTrp]” operates, then [87L.Op] will operate.
87
87L.Op_A
Current differential protection of phase A operates
88
87L.Op_B
Current differential protection of phase B operates
89
87L.Op_C
Current differential protection of phase C operates
90
87L.Op_DPFC1
87L.Op_DPFC1
91
87L.Op_DPFC2
87L.Op_DPFC2
92
87L.Op_Biased1
87L.Op_Biased1
93
87L.Op_Biased2
87L.Op_Biased2
94
87L.Op_Neutral
87L.Op_Neutral
95
87L.Op_InterTrp
87L.Op_InterTrp
96
87L.FOx.Alm_Diff
87L.FOx.Alm_Diff
97
87L.FOx.Alm_Comp
87L.FOx.Alm_Comp Current direction
98
FwdDir_ROC
The forward direction of zero-sequence power
99
RevDir_ROC
The reverse direction of zero-sequence power
100
FwdDir_NegOC
The forward direction of negative-sequence power
101
RevDir_NegOC
The reverse direction of negative-sequence power
102
FwdDir_A
The forward direction of phase-A current
103
FwdDir_B
The forward direction of phase-B current
104
FwdDir_C
The forward direction of phase-C current
105
RevDir_A
The reverse direction of phase-A current
106
RevDir_B
The reverse direction of phase-B current
107
RevDir_C
The reverse direction of phase-C current
108
FwdDir_AB
The forward direction of phase-AB current
9-12
PCS-931 Line Differential Relay Date: 2013-12-27
9 Configurable Function No.
Signal
Description
109
FwdDir_BC
The forward direction of phase-BC current
110
FwdDir_CA
The forward direction of phase-CA current
111
RevDir_AB
The reverse direction of phase-AB current
112
RevDir_BC
The reverse direction of phase-BC current
113
RevDir_CA
The reverse direction of phase-CA current Phase overcurrent protection
114
50/51Px.On
Stage x of phase overcurrent protection is enabled.
115
50/51Px.Op
Stage x of phase overcurrent protection operates.
116
50/51Px.St
Stage x of phase overcurrent protection starts.
117
50/51Px.StA
Stage x of phase overcurrent protection starts (A-Phase).
118
50/51Px.StB
Stage x of phase overcurrent protection starts (B-Phase).
119
50/51Px.StC
Stage x of phase overcurrent protection starts (C-Phase). Earth fault protection
120
50/51Gx.On
Stage x of earth fault protection is enabled.
121
50/51Gx.St
Stage x of earth fault protection starts.
122
50/51Gx.Op
Stage x of earth fault protection operates. Overcurrent protection for VT circuit failure
123
50PVT.On
Phase overcurrent protection for VT circuit failure is enabled.
124
50PVT.Op
Phase overcurrent protection for VT circuit failure operates.
125
50PVT.St
Phase overcurrent protection for VT circuit failure starts.
126
50PVT.StA
Phase overcurrent protection for VT circuit failure starts (A-Phase).
127
50PVT.StB
Phase overcurrent protection for VT circuit failure starts (B-Phase).
128
50PVT.StC
Phase overcurrent protection for VT circuit failure starts (C-Phase).
129
50GVT.On
Ground overcurrent protection for VT circuit failure is enabled.
130
50GVT.Op
Ground overcurrent protection for VT circuit failure operates.
131
50GVT.St
Ground overcurrent protection for VT circuit failure starts. Residual SOTF protection
132
50GSOTF.On
Residual current SOTF protection is enabled.
133
50GSOTF.Op
Residual current SOTF protection operates.
134
50GSOTF.St
Residual current SOTF protection starts. Voltage protection
135
59Px.On
Stage x of overvoltage protection is enabled.
136
59Px.Op
Stage x of overvoltage protection operates.
137
59Px.St
Stage x of overvoltage protection starts.
138
59Px.St1
Stage x of overvoltage protection starts (A or AB).
139
59Px.St2
Stage x of overvoltage protection starts (B or BC).
140
59Px.St3
Stage x of overvoltage protection starts (C or CA).
141
59Px.Op_InitTT
Stage x of overvoltage protection operates to initiate transfer trip.
142
59Px.Alm
Stage x of overvoltage protection alarms.
143
27Px.On
Stage x of undervoltage protection is enabled.
144
27Px.Op
Stage x of undervoltage protection operates.
145
27Px.Alm
Stage x of undervoltage protection alarms.
PCS-931 Line Differential Relay
9-13 Date: 2013-12-27
9 Configurable Function No.
Signal
Description
146
27Px.St
Stage x of undervoltage protection starts.
147
27Px.St1
Stage x of undervoltage protection starts (A or AB).
148
27Px.St2
Stage x of undervoltage protection starts (B or BC).
149
27Px.St3
Stage x of undervoltage protection starts (C or CA). Frequency protection
150
81O.OFx.On
Stage x of overfrequency protection is enabled (x=1, 2, 3 or 4).
151
81O.OFx.Op
Stage x of overfrequency protection operates (x=1, 2, 3 or 4).
152
81O.St
Overfrequency protection starts.
153
81U.UFx.On
Stage x of underfrequency protection is enabled (x=1, 2, 3 or 4).
154
81U.UFx.Op
Stage x of underfrequency protection operates (x=1, 2, 3 or 4).
155
81U.St
Underfrequency protection starts. Breaker failure protection
156
50BF.On
Breaker failure protection is enabled
157
50BF.Op_ReTrpA
Breaker failure protection operates to re-trip phase-A circuit breaker
158
50BF.Op_ReTrpB
Breaker failure protection operates to re-trip phase-B circuit breaker
159
50BF.Op_ReTrpC
Breaker failure protection operates to re-trip phase-C circuit breaker
160
50BF.Op_ReTrp3P
161
50BF.Op_t1
Stage 1 of breaker failure protection operates
162
50BF.Op_t2
Stage 2 of breaker failure protection operates
Breaker failure protection operates to re-trip three-phase circuit breaker
Thermal overload protection 163
49.On
Thermal overload protection is enabled.
164
49.St
Thermal overload protection starts.
165
49-1.Op
Stage 1 of thermal overload protection operates to trip.
166
49-2.Op
Stage 2 of thermal overload protection operates to trip.
167
49-1.Alm
Stage 1 of thermal overload protection operates to alarm.
168
49-2.Alm
Stage 2 of thermal overload protection operates to alarm. Stub overcurrent protection
169
50STB.On
Stub overcurrent protection is enabled.
170
50STB.Op
Stub overcurrent protection operates.
171
50STB.St
Stub overcurrent protection starts.
172
50STB.StA
Phase A of stub overcurrent protection starts.
173
50STB.StB
Phase B of stub overcurrent protection starts.
174
50STB.StC
Phase C of stub overcurrent protection starts. Dead zone protection
175
50DZ.On
Dead zone protection is enabled.
176
50DZ.St
Dead zone protection starts.
177
50DZ.Op
Dead zone protection operates. Pole discrepancy protection
178
62PD.On
Pole discrepancy protection is enabled.
179
62PD.Op
Pole discrepancy protection operates to trip
180
62PD.St
Pole discrepancy protection starts
9-14
PCS-931 Line Differential Relay Date: 2013-12-27
9 Configurable Function No.
Signal
Description Broken conductor protection
181
46BC.On
Broken-conductor protection is enabled.
182
46BC.St
Broken-conductor protection starts.
183
46BC.Op
Broken-conductor protection operates to trip.
184
46BC.Alm
Broken-conductor protection operates to alarm. Reverse power protection
185
P1
Positive-sequence active power
186
32R1.On
Stage 1 of reverse power protection is enabled.
187
32R1.St
Stage 1 of reverse power protection starts.
188
32R1.Op
Stage 1 of reverse power protection operates to trip.
189
32R1.Alm
Stage 1 of reverse power protection operates to alarm.
190
32R2.On
Stage 2 of reverse power protection is enabled.
191
32R2.St
Stage 2 of reverse power protection starts.
192
32R2.Op
Stage 2 of reverse power protection operates to trip. Synchrocheck function To indicate that frequency difference condition for synchronism check
193
25.Ok_fDiffChk
of AR is met, frequency difference between UB and UL is smaller than [25.f_Diff]. To indicate that voltage difference condition for synchronism check of
194
25.Ok_UDiffChk
AR is met, voltage difference between UB and UL is smaller than [25.U_Diff] To indicate phase difference condition for synchronism check of AR is
195
25.Ok_phiDiffChk
met, phase difference between UB and UL is smaller than [25.phi_Diff].
196
25.Ok_DdL_DdB
Dead line and dead bus condition is met
197
25.Ok_DdL_LvB
Dead line and live bus condition is met
198
25.Ok_LvL_DdB
Live line and dead bus condition is met
199
25.Chk_LvL
Line voltage is greater than the voltage setting [25.U_Lv]
200
25.Chk_DdL
Line voltage is smaller than the voltage setting [25.U_Dd]
201
25.Chk_LvB
Bus voltage is greater than the voltage setting [25.U_Lv]
202
25.Chk_DdB
Bus voltage is smaller than the voltage setting [25.U_Dd]
203
25.Ok_DdChk
To indicate that dead charge check condition of AR is met
204
25.Ok_SynChk
To indicate that synchronism check condition of AR is met
205
25.Ok_Chk
To indicate that synchrocheck condition of AR is met
206
25.Alm_VTS_UB
Synchronism voltage circuit is abnormal (UB)
207
25.Alm_VTS_UL
Reference voltage circuit is abnormal (UL) Auto-reclosing
208
79.On
Automatic reclosure is enabled
209
79.Off
Automatic reclosure is disabled
210
79.Close
Output of auto-reclosing signal
211
79.Ready
Automatic reclosure have been ready for reclosing cycle
212
79.AR_Blkd
Automatic reclosure is blocked
PCS-931 Line Differential Relay
9-15 Date: 2013-12-27
9 Configurable Function No.
Signal
Description
213
79.Active
Automatic reclosing logic is actived
214
79.Inprog
Automatic reclosing cycle is in progress
215
79.Inprog_1P
The first 1-pole AR cycle is in progress
216
79.Inprog_3P
3-pole AR cycle is in progress
217
79.Inprog_3PS1
First 3-pole AR cycle is in progress
218
79.Inprog_3PS2
Second 3-pole AR cycle is in progress
219
79.Inprog_3PS3
Third 3-pole AR cycle is in progress
220
79.Inprog_3PS4
Fourth 3-pole AR cycle is in progress
221
79.WaitToSlave
222
79.Perm_Trp1P
223
79.Perm_Trp3P
224
79.Rcls_Status
225
79.Fail_Rcls
Auto-reclosing fails
226
79.Succ_Rcls
Auto-reclosing is successful
227
79.Fail_Chk
Synchrocheck for AR fails
228
79.Mode_1PAR
Output of 1-pole AR mode
229
79.Mode_3PAR
Output of 3-pole AR mode
230
79.Mode_1/3PAR
Output of 1/3-pole AR mode
231
TT.Alm
Input signal of receiving transfer trip is abnormal
232
TT.Op
Transfer trip operates
233
TT.On
Transfer trip is enabled
Waiting signal of automatic reclosing which will be sent to slave (when reclosing multiple circuit breakers) Single-phase circuit breaker will be tripped once protection device operates Three-phase circuit breaker will be tripped once protection device operates Automatic reclosure status (0: AR is ready, 1: AR is in progress, 2: AR is successful)
Transfer trip
Trip logic 234
On
Tripping logic is enabled.
235
TrpA
Tripping A-phase circuit breaker
236
TrpB
Tripping B-phase circuit breaker
237
TrpC
Tripping C-phase circuit breaker
238
Trp
Tripping any phase circuit breaker
239
Trp3P
Tripping three-phase circuit breaker
240
BFI_A
241
BFI_B
242
BFI_C
243
BFI
244
Trp3P_PSFail
Protection tripping signal of A-phase configured to initiate BFP, BFI signal shall be reset immediately after tripping signal drops off. Protection tripping signal of B-phase configured to initiate BFP, BFI signal shall be reset immediately after tripping signal drops off. Protection tripping signal of C-phase configured to initiate BFP, BFI signal shall be reset immediately after tripping signal drops off. Protection tripping signal configured to initiate BFP, BFI signal shall be reset immediately after tripping signal drops off. Initiating three-phase tripping due to failure in fault phase selection
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9 Configurable Function No. 245
Signal
Description
BlkAR
Blocking auto-reclosing VT circuit supervision
246
VTS.Alm
Alarm signal to indicate VT circuit fails
247
VTNS.Alm
Alarm signal to indicate VT neutral point fails CT circuit supervision
248
CTS.Alm
Alarm signal to indicate CT circuit fails Control and Synchrocheck for Manual Closing
249
CSWIxx.Op_Opn
No.xx command output for open. (xx=01~10)
250
CSWIxx.Op_Cls
No.xx command output for closing. (xx=01~10)
251
BIinput.RmtCtrl
In order to be convenient to user configure control output, three same
252
BIinput.LocCtrl
output signals with input signals are available. The relationship with 10 binary output have been configured inside the device. The user only assigns a specific binary input to input signal, the relevant function can
253
BIinput.CILO.Disable
be gained. If some binary output need not be controlled by three signals, please cancle the configuration by PCS-Explorer, and configure it independently. Faulty phase selection
254
PhSA
Phase-A is selected as faulty phase
255
PhSB
Phase-B is selected as faulty phase
256
PhSC
Phase-C is selected as faulty phase
257
GndFlt
Earth fault
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10 Communication Table of Contents 10 Communication ............................................................................ 10-a 10.1 Overview ...................................................................................................... 10-1 10.2 Rear Communication Port Information ..................................................... 10-1 10.2.1 RS-485 Interface ............................................................................................................ 10-1 10.2.2 Ethernet Interface .......................................................................................................... 10-3 10.2.3 IEC60870-5-103 Communication ................................................................................... 10-4
10.3 IEC60870-5-103 Interface over Serial Port ................................................ 10-4 10.3.1 Physical Connection and Link Layer .............................................................................. 10-5 10.3.2 Initialization .................................................................................................................... 10-5 10.3.3 Time Synchronization ..................................................................................................... 10-5 10.3.4 Spontaneous Events ...................................................................................................... 10-5 10.3.5 General Interrogation ..................................................................................................... 10-5 10.3.6 General Service ............................................................................................................. 10-6 10.3.7 Disturbance Records ..................................................................................................... 10-6
10.4 Messages Description for IEC61850 Protocol .......................................... 10-6 10.4.1 Overview ........................................................................................................................ 10-6 10.4.2 Communication Profiles ................................................................................................. 10-7 10.4.3 MMS Communication Network Deployment................................................................... 10-8 10.4.4 Server Data Organization............................................................................................. 10-11 10.4.5 Server Features and Configuration .............................................................................. 10-13 10.4.6 ACSI Conformance ...................................................................................................... 10-15 10.4.7 Logical Nodes .............................................................................................................. 10-19
10.5 DNP3.0 Interface ....................................................................................... 10-22 10.5.1 Overview ...................................................................................................................... 10-22 10.5.2 Link Layer Functions .................................................................................................... 10-22
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10.5.3 Transport Functions ..................................................................................................... 10-22 10.5.4 Application Layer Functions ......................................................................................... 10-22
List of Figures Figure 10.2-1 EIA RS-485 bus connection arrangements.....................................................10-2 Figure 10.2-2 Ethernet communication cable .......................................................................10-3 Figure 10.2-3 Ethernet communication structure .................................................................10-4 Figure 10.4-1 Dual-net full duplex mode sharing the RCB block instance .........................10-8 Figure 10.4-2 Dual-net hot-standby mode sharing the same RCB instance .......................10-9 Figure 10.4-3 Dual-net full duplex mode with 2 independent RCB instances ..................10-10
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10.1 Overview This section outlines the remote communications interfaces of NR Relays. The protective device supports a choice of three protocols via the rear communication interface (RS-485 or Ethernet), selected via the model number by setting. The protocol provided by the protective device is indicated in the menu “Settings→Device Setup→Comm Settings”. The rear EIA RS-485 interface is isolated and is suitable for permanent connection of whichever protocol is selected. The advantage of this type of connection is that up to 32 protective devices can be “daisy chained” together using a simple twisted pair electrical connection. It should be noted that the descriptions contained within this section do not aim to fully detail the protocol itself. The relevant documentation for the protocol should be referred to for this information. This section serves to describe the specific implementation of the protocol in the relay.
10.2 Rear Communication Port Information 10.2.1 RS-485 Interface This protective device provides two rear RS-485 communication ports, and each port has three terminals in the 12-terminal screw connector located on the back of the relay and each port has a ground terminal for the earth shield of the communication cable. The rear ports provide RS-485 serial data communication and are intended for use with a permanently wired connection to a remote control center. 10.2.1.1 EIA RS-485 Standardized Bus The EIA RS-485 two-wire connection provides a half-duplex fully isolated serial connection to the product. The connection is polarized and whilst the product’s connection diagrams indicate the polarization of the connection terminals it should be borne in mind that there is no agreed definition of which terminal is which. If the master is unable to communicate with the product, and the communication parameters match, then it is possible that the two-wire connection is reversed. 10.2.1.2 Bus Termination The EIA RS-485 bus must have 120Ω (Ohm) ½ Watt terminating resistors fitted at either end across the signal wires (refer to Figure 10.2-1). Some devices may be able to provide the bus terminating resistors by different connection or configuration arrangements, in which case separate external components will not be required. However, this product does not provide such a facility, so if it is located at the bus terminus then an external termination resistor will be required.
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Master
EIA RS-485
10 Communication
120 Ohm
120 Ohm
Slave
Slave
Slave
Figure 10.2-1 EIA RS-485 bus connection arrangements
10.2.1.3 Bus Connections & Topologies The EIA RS-485 standard requires that each device is directly connected to the physical cable that is the communications bus. Stubs and tees are expressly forbidden, such as star topologies. Loop bus topologies are not part of the EIA RS-485 standard and are forbidden by it also. Two-core screened cable is recommended. The specification of the cable will be dependent on the application, although a multi-strand 0.5mm2 per core is normally adequate. Total cable length must not exceed 500m. The screen must be continuous and connected to ground at one end, normally at the master connection point; it is important to avoid circulating currents, especially when the cable runs between buildings, for both safety and noise reasons. This product does not provide a signal ground connection. If a signal ground connection is present in the bus cable then it must be ignored, although it must have continuity for the benefit of other devices connected to the bus. At no stage must the signal ground be connected to the cables screen or to the product’s chassis. This is for both safety and noise reasons. 10.2.1.4 Biasing It may also be necessary to bias the signal wires to prevent jabber. Jabber occurs when the signal level has an indeterminate state because the bus is not being actively driven. This can occur when all the slaves are in receive mode and the master is slow to turn from receive mode to transmit mode. This may be because the master purposefully waits in receive mode, or even in a high impedance state, until it has something to transmit. Jabber causes the receiving device(s) to miss the first bits of the first character in the packet, which results in the slave rejecting the message and consequentially not responding. Symptoms of these are poor response times (due to retries), increasing message error counters, erratic communications, and even a complete failure to communicate. Biasing requires that the signal lines be weakly pulled to a defined voltage level of about 1V. There should only be one bias point on the bus, which is best situated at the master connection point. The DC source used for the bias must be clean; otherwise noise will be injected. Note that some devices may (optionally) be able to provide the bus bias, in which case external components will not be required.
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Note! It is extremely important that the 120Ω termination resistors are fitted. Failure to do so will result in an excessive bias voltage that may damage the devices connected to the bus. As the field voltage is much higher than that required, NR cannot assume responsibility for any damage that may occur to a device connected to the network as a result of incorrect application of this voltage. Ensure that the field voltage is not being used for other purposes (i.e. powering logic inputs) as this may cause noise to be passed to the communication network.
10.2.2 Ethernet Interface This protective device can provide four rear Ethernet interfaces (optional) and they are unattached each other. Parameters of each Ethernet port can be configured in the menu “Settings→Device Setup→Comm Settings”. 10.2.2.1 Ethernet Standardized Communication Cable It is recommended to use twisted screened eight-core cable as the communication cable. A picture is shown bellow.
Figure 10.2-2 Ethernet communication cable
10.2.2.2 Connections and Topologies Each equipment is connected with an exchanger via communication cable, and thereby it forms a star structure network. Dual-network is recommended in order to increase reliability. SCADA is also connected to the exchanger and will play a role of master station, so the every equipment which has been connected to the exchanger will play a role of slave unit.
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SCADA
Switch: Net A
Switch: Net B
……
Figure 10.2-3 Ethernet communication structure
10.2.3 IEC60870-5-103 Communication The IEC specification IEC60870-5-103: Telecontrol Equipment and Systems, Part 5: Transmission Protocols Section 103 defines the use of standards IEC60870-5-1 to IEC60870-5-5 to perform communication with protective device. The standard configuration for the IEC60870-5-103 protocol is to use a twisted pair EIA RS-485 connection over distances up to 500m. It also supports to use an Ethernet connection. The relay operates as a slave in the system, responding to commands from a master station. To use the rear port with IEC60870-5-103 communication, the relevant settings to the protective device must be configured.
10.3 IEC60870-5-103 Interface over Serial Port The IEC60870-5-103 interface over serial port (RS-485) is a master/slave interface with the protective device as the slave device. It is properly developed by NR. The protective device conforms to compatibility level 3. The following IEC60870-5-103 facilities are supported by this interface:
Initialization (reset)
Time synchronization
Event record extraction
General interrogation
General commands
Disturbance records
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10.3.1 Physical Connection and Link Layer Two EIA RS-485 standardized ports are available for IEC60870-5-103 in this protective device. The transmission speed is optional: 4800 bit/s, 9600 bit/s, 19200 bit/s or 38400 bit/s. The link layer strictly abides by the rules defined in the IEC60870-5-103.
10.3.2 Initialization Whenever the protective device has been powered up, or if the communication parameters have been changed, a reset command is required to initialize the communications. The protective device will respond to either of the two reset commands (Reset CU or Reset FCB), the difference is that the Reset CU will clear any unsent messages in the transmit buffer. The protective device will respond to the reset command with an identification message ASDU 5, the COT (Cause Of Transmission) of this response will be either Reset CU or Reset FCB depending on the nature of the reset command.
10.3.3 Time Synchronization The protective device time and date can be set using the time synchronization feature of the IEC60870-5-103 protocol. The protective device will correct for the transmission delay as specified in IEC60870-5-103. If the time synchronization message is sent as a send/confirm message then the protective device will respond with a confirmation. Whether the time-synchronization message is sent as a send confirmation or a broadcast (send/no reply) message, a time synchronization class 1 event will be generated/produced. If the protective device clock is synchronized using the IRIG-B input then it will not be possible to set the protective device time using the IEC60870-5-103 interface. An attempt to set the time via the interface will cause the protective device to create an event with the current date and time taken from the IRIG-B synchronized internal clock.
10.3.4 Spontaneous Events Events are categorized using the following information:
Type identification (TYP)
Function type (FUN)
Information number (INF)
Messages sent to substation automation system are grouped according to IEC60870-5-103 protocol. Operating elements are sent by ASDU2 (time-tagged message with relative time), and status of binary signal and alarm element are sent by ASDU1 (time-tagged message). The cause of transmission (COT) of these responses is 1. All spontaneous events can be gained by printing, implementing submenu “IEC103 Info” in the menu “Print”.
10.3.5 General Interrogation The GI can be used to read the status of the relay, the function numbers, and information numbers PCS-931 Line Differential Relay
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that will be returned during the GI cycle. The GI cycle strictly abides by the rules defined in the IEC60870-5-103. Refer the IEC60870-5-103 standard can get the enough details about general interrogation.
10.3.6 General Service The generic functions can be used to read the setting and protection measurement of the protective device, and modify the setting. Two supported type identifications are ASDU 21 and ASDU 10. For more details about generic functions, see the IEC60870-5-103 standard. All general classification service group numbers can be gained by printing, implementing submenu “IEC103 Info” in the menu “Print”.
10.3.7 Disturbance Records This protective device can store up to 32 disturbance records in its memory. A pickup of the fault detector or an operation of the relay can make the protective device store the disturbance records. The disturbance records are stored in uncompressed format and can be extracted using the standard mechanisms described in IEC60870-5-103. All channel numbers (ACC) of disturbance data can be gained by printing, implementing submenu “IEC103 Info” in the menu “Print”.
10.4 Messages Description for IEC61850 Protocol 10.4.1 Overview The IEC 61850 standard is the result of years of work by electric utilities and vendors of electronic equipment to produce standardized communications systems. IEC 61850 is a series of standards describing client/server and peer-to-peer communications, substation design and configuration, testing, environmental and project standards. The complete set includes:
IEC 61850-1: Introduction and overview
IEC 61850-2: Glossary
IEC 61850-3: General requirements
IEC 61850-4: System and project management
IEC 61850-5: Communications and requirements for functions and device models
IEC 61850-6: Configuration description language for communication in electrical substations related to IEDs
IEC 61850-7-1: Basic communication structure for substation and feeder equipment– Principles and models
IEC 61850-7-2: Basic communication structure for substation and feeder equipment - Abstract communication service interface (ACSI)
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IEC 61850-7-3: Basic communication structure for substation and feeder equipment– Common data classes
IEC 61850-7-4: Basic communication structure for substation and feeder equipment– Compatible logical node classes and data classes
IEC 61850-8-1: Specific Communication Service Mapping (SCSM) – Mappings to MMS (ISO 9506-1 and ISO 9506-2) and to ISO/IEC 8802-3 IEC 61850-9-1: Specific Communication Service Mapping (SCSM) – Sampled values over serial unidirectional multidrop point to point link IEC 61850-9-2: Specific Communication Service Mapping (SCSM) – Sampled values over ISO/IEC 8802-3 IEC 61850-10: Conformance testing
These documents can be obtained from the IEC (http://www.iec.ch). It is strongly recommended that all those involved with any IEC 61850 implementation obtain this document set.
10.4.2 Communication Profiles The PCS-900 series relay supports IEC 61850 server services over TCP/IP communication protocol stacks. The TCP/IP profile requires the PCS-900 series to have an IP address to establish communications. These addresses are located in the menu “Settings→Device Setup→Comm Settings”. 1.
MMS protocol
IEC 61850 specifies the use of the Manufacturing Message Specification (MMS) at the upper (application) layer for transfer of real-time data. This protocol has been in existence for a number of years and provides a set of services suitable for the transfer of data within a substation LAN environment. IEC 61850-7-2 abstract services and objects are mapped to actual MMS protocol services in IEC61850-8-1. 2.
Client/server
This is a connection-oriented type of communication. The connection is initiated by the client, and communication activity is controlled by the client. IEC61850 clients are often substation computers running HMI programs or SOE logging software. Servers are usually substation equipment such as protection relays, meters, RTUs, transformer, tap changers, or bay controllers. 3.
Peer-to-peer
This is a non-connection-oriented, high speed type of communication usually between substation equipment, such as protection relays, intelligent terminal. GOOSE is the method of peer-to-peer communication. 4.
Substation configuration language (SCL)
A substation configuration language is a number of files used to describe IED configurations and communication systems according to IEC 61850-5 and IEC 61850-7. Each configured device has
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an IED Capability Description (ICD) file and a Configured IED Description (CID) file. The substation single line information is stored in a System Specification Description (SSD) file. The entire substation configuration is stored in a Substation Configuration Description (SCD) file. The SCD file is the combination of the individual ICD files and the SSD file, moreover, add communication system parameters (MMS, GOOSE, control block, SV control block) and the connection relationship of GOOSE and SV to SCD file.
10.4.3 MMS Communication Network Deployment In order to enhance the stability and reliability of SAS, dual-MMS Ethernet is widely adopted. This section is applied to introduce the details of dual-MMS Ethernet technology. Generally, single-MMS Ethernet is recommended to be adopted in the SAS of 110kV and lower voltage levels, while dual-MMS Ethernet is recommended to be adopted in the SAS of voltage levels above 110kV. Client-server mode is adopted: clients (SCADA, control center and etc.) communicate with the IEDs via MMS communication network, and the IEDs operate as the servers. IEDs are connected to clients passively, and they can interact with the clients according to the configuration and the issued command of the clients. Three modes for dual-MMS Ethernet (abbreviated as dual-net) are provided as below. Note! Hereinafter, the normal operation status of net means the physical link and TCP link are both ok. The abnormal operation status of net means physical link or TCP link is broken. 10.4.3.1 Dual-net Full Duplex Mode Sharing the Same RCB Instance
Client
Client
Net A
Net B
Net A
Net B
Report Instance 1 RptEna = true
Report Instance 1 RptEna = true
Report Control Block
Report Control Block
IED (Server)
IED (Server)
Normal operation status
Abnormal operation status
TCP Link
MMS Link
Figure 10.4-1 Dual-net full duplex mode sharing the RCB block instance
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Net A and Net B share the same report control block (abbreviated as RCB) enabled by the client. IED sends undifferentiated date through dual-net to the clients. If one net is physically disconnected, the flag of RCB instance (i.e.: “RptEna” in above figure) is still “true”. Only when both Net A and Net B are disconnected, the flag of the RCB instance will automatically change to “false”. In normal operation status of this mode, IED provides the same MMS service for Net A and Net B. If one net is physically disconnected (i.e.: “Abnormal operation status” in above figure), the working mode will switch to single-net mode seamlessly and immediately. Network communication supervision is unnecessary here, and Buffered Report Control Block (abbreviated as BRCB) need not to be used. On the other net, date alternation works normally. Therefore, MMS service can interact normally without interruption. This mode ensures no data loss during one net is in abnormal operation status. In this mode, one report will be transmitted twice via dual nets for the same report instance, so the client needs to distinguish whether two reports are same according to corresponding EntryIDs. 10.4.3.2 Dual-net Hot-standby Mode Sharing the Same RCB Instance
Client
Net A
Client
Net B
Net A
Net B
Report Instance 1 RptEna = true
Report Instance 1 RptEna = true
Report Control Block
Report Control Block
IED (Server)
IED (Server)
Normal operation status
Abnormal operation status
TCP Link
Main MMS Link
Standby MMS Link
Figure 10.4-2 Dual-net hot-standby mode sharing the same RCB instance
In this mode, the MMS service is provided on main MMS link, no MMS service interacts on the standby MMS link. The definitions of two links are as follows:
Main MMS Link: Physically connected, TCP level connected, MMS report service available.
Standby MMS Link: Physically connected, TCP level connected, MMS report service not available.
If the main net fails to operate (i.e.: “Abnormal operation status” in the above figure), the IED will set “RptEna” to “false”. Meanwhile the client will detect the failure by heartbeat message or “keep-alive”, it will automatically enable the RCB instance by setting “RptEna” back to “true” PCS-931 Line Differential Relay
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through standby MMS link. By the buffer function of BRCB, the IED can provide uninterrupted MMS service on the standby net. However, the differences of BRCB standards among different manufacturers may cause data loss. Moreover, if duration of net switch is too long, the data loss is positively as the capacity of BRCB’s buffer function is limited. Note! The first mode and second mode, Net A IED host address and Net B IED host address must be the same. For example, if the subnet mask is “255.255.0.0”, network prefix of Net A is “198.120.0.0”, network prefix of Net B is “198.121.0.0”, Net A IP address of the IED is “198.120.1.2”, and then Net B IP address of the IED must be configured as “198.121.1.2”, i.e., Net A IED host address =1x256+2=258, Net B IED host address =1x256+2=258, Net A IED host address equals to Net B IED host address. 10.4.3.3 Dual-net Full Duplex Mode with 2 Independent RCB Instances
Client
Net A
Client
Net B
Report Instance 1 RptEna = true
Report Instance 2 RptEna = true
Net A
Net B
Report Instance 1 RptEna = true
Report Instance 2 RptEna = true
Report Control Block
Report Control Block
IED (Server)
IED (Server)
Normal operation status
Abnormal operation status
TCP Link
MMS Link
Figure 10.4-3 Dual-net full duplex mode with 2 independent RCB instances
In this mode, IED provides 2 report instances for each RCB, Net A and Net B work independently from each other, failures of any net will not affect the other net at all. Tow report instances are required for each client. Therefore, the IED may be unable to provide enough report instances if there are too many clients. Net A and Net B send the same report separately when they operates normally, To ensure no repeated data is saved into database, massive calculation is required for the client. Moreover, accurate clock synchronization of the IED is required to distinguish whether 2 reports are the same report according to the timestamps. Clock synchronization error of the IED may lead to report loss/redundancy.
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As a conclusion, for the second mode, it’s difficult to realize seamless switchover between dual nets, however, for the third mode, the IED may be unable to provide enough report instances if too many clients are applied on site. Considering client treatment and IED implementation, the first mode (Dual-net full duplex mode sharing the same report instance) is recommended for MMS communication network deployment.
10.4.4 Server Data Organization IEC61850 defines an object-oriented approach to data and services. An IEC61850 physical device can contain one or more logical device(s) (for proxy). Each logical device can contain many logical nodes. Each logical node can contain many data objects. Each data object is composed of data attributes and data attribute components. Services are available at each level for performing various functions, such as reading, writing, control commands, and reporting. Each IED represents one IEC61850 physical device. The physical device contains one or more logical device(s), and the logical device contains many logical nodes. The logical node LPHD contains information about the IED physical device. The logical node LLN0 contains common information about the IED logical device. 10.4.4.1 Digital Status Values The GGIO logical node is available in the PCS-900 series relays to provide access to digital status points (including general I/O inputs and warnings) and associated timestamps and quality flags. The data content must be configured before the data can be used. GGIO provides digital status points for access by clients. It is intended that clients use GGIO in order to access digital status values from the PCS-900 series relays. Clients can utilize the IEC61850 buffered reporting features available from GGIO in order to build sequence of events (SOE) logs and HMI display screens. Buffered reporting should generally be used for SOE logs since the buffering capability reduces the chances of missing data state changes. All needed status data objects are transmitted to HMI clients via buffered reporting, and the corresponding buffered reporting control block (BRCB) is defined in LLN0. 10.4.4.2 Analog Values Most of analog measured values are available through the MMXU logical nodes, and metering values in MMTR, the else in MMXN, MSQI and so on. Each MMXU logical node provides data from a IED current/voltage “source”. There is one MMXU available for each configurable source. MMXU1 provides data from CT/VT source 1(usually for protection purpose), and MMXU2 provides data from CT/VT source 2 (usually for monitor and display purpose). All these analog data objects are transmitted to HMI clients via unbuffered reporting periodically, and the corresponding unbuffered reporting control block (URCB) is defined in LLN0. MMXUx logical nodes provide the following data for each source:
MMXU.MX.Hz: frequency
MMXU.MX.PPV.phsAB: phase AB voltage magnitude and angle
MMXU.MX.PPV.phsBC: phase BC voltage magnitude and angle
MMXU.MX.PPV.phsCA: Phase CA voltage magnitude and angle
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MMXU.MX.PhV.phsA: phase AG voltage magnitude and angle
MMXU.MX.PhV.phsB: phase BG voltage magnitude and angle
MMXU.MX.PhV.phsC: phase CG voltage magnitude and angle
MMXU.MX.A.phsA: phase A current magnitude and angle
MMXU.MX.A.phsB: phase B current magnitude and angle
MMXU.MX.A.phsC: phase C current magnitude and angle
10.4.4.3 Protection Logical Nodes The following list describes the protection elements for PCS-931 series relays. The specified relay will contain a subset of protection elements from this list.
PDIF: Current differential and transfer trip
PDIS: Phase-to-phase distance, phase-to-ground distance and SOTF distance
PTUC: Undercurrent
PTOC: Phase overcurrent, zero-sequence overcurrent and overcurrent when VT circuit failure
PTTR: Thermal overload
PTUV: Undervoltage
PTOV: Overvoltage and auxiliary overvoltage
PTOF: Overfrequency
PTUF: Underfrequency
PPDP: Pole discrepancy
PSCH: Protection scheme
RBRF: Breaker failure
RPSB: Power swing detection/blocking
RREC: Automatic reclosing
RSYN: Synchronism-check
RFLO: Fault location
The protection elements listed above contain start (pickup) and operate flags, instead of any element has its own start (pickup) flag separately, all the elements share a common start (pickup) flags “PTRC.ST.Str.general”. The operate flag for PTOC1 is “PTOC1.ST.Op.general”. For PCS-931 series relays protection elements, these flags take their values from related module for the corresponding element. Similar to digital status values, the protection trip information is reported via BRCB, and BRCB also locates in LLN0.
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10.4.4.4 LLN0 and Other Logical Nodes Logical node LLN0 is essential for an IEC61850 based IED. This LN shall be used to address common issues for Logical Devices. Most of the public services, the common settings, control values and some device oriented data objects are available here. The public services may be BRCB, URCB and GSE control blocks and similar global defines for the whole device; the common settings include all the setting items of communication settings, system settings and some of the protection setting items, which can be configured to two or more protection elements (logical nodes). In LLN0, the item Loc is a device control object, this Do item indicates the local operation for complete logical device, when it is true, all the remote control commands to the IED will be blocked and those commands make effective until the item Loc is changed to false. In PCS-900 series relays, besides the logical nodes we describe above, there are some other logical nodes below in the IEDs:
MMXU: This LN shall be used to acquire values from CTs and VTs and calculate measurands such as r.m.s. values for current and voltage or power flows out of the acquired voltage and current samples. These values are normally used for operational purposes such as power flow supervision and management, screen displays, state estimation, etc. The requested accuracy for these functions has to be provided.
LPHD: Physical device information, the logical node to model common issues for physical device.
PTRC: Protection trip conditioning, it shall be used to connect the “operate” outputs of one or more protection functions to a common “trip” to be transmitted to XCBR. In addition or alternatively, any combination of “operate” outputs of protection functions may be combined to a new “operate” of PTRC. RDRE: Disturbance recorder function. It triggers the fault wave recorder and its output refers to the “IEEE Standard Format for Transient Data Exchange (COMTRADE) for Power System” (IEC 60255-24). All enabled channels are included in the recording, independently of the trigger mode.
10.4.5 Server Features and Configuration 10.4.5.1 Buffered/unbuffered Reporting IEC61850 buffered and unbuffered reporting control blocks locate in LLN0, they can be configured to transmit information of protection trip information (in the Protection logical nodes), binary status values (in GGIO) and analog measured/calculated values (in MMXU, MMTR and MSQI). The reporting control blocks can be configured in CID files, and then be sent to the IED via an IEC61850 client. The following items can be configured.
TrgOps: Trigger options.
The following bits are supported by the PCS-900 series relays: - Bit 1: Data-change - Bit 4: Integrity
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10 Communication
- Bit 5: General interrogation OptFlds: Option Fields.
The following bits are supported by the PCS-900 series relays: - Bit 1: Sequence-number - Bit 2: Report-time-stamp - Bit 3: Reason-for-inclusion - Bit 4: Data-set-name - Bit 5: Data-reference - Bit 7: EntryID (for buffered reports only) - Bit 8: Conf-revision - Bit 9: Segmentation
IntgPd: Integrity period.
10.4.5.2 File Transfer MMS file services are supported to allow transfer of oscillography, event record or other files from a PCS-900 series relay. 10.4.5.3 Timestamps The Universal Time Coordinated(UTC for short) timestamp associated with all IEC61850 data items represents the lastest change time of either the value or quality flags of the data item. 10.4.5.4 Logical Node Name Prefixes IEC61850 specifies that each logical node can have a name with a total length of 11 characters. The name is composed of:
A five or six-character name prefix.
A four-character standard name (for example, MMXU, GGIO, PIOC, etc.).
A one or two-character instantiation index.
Complete names are of the form xxxxxxPTOC1, where the xxxxxx character string is configurable. Details regarding the logical node naming rules are given in IEC61850 parts 6 and 7-2. It is recommended that a consistent naming convention be used for an entire substation project. 10.4.5.5 GOOSE Services IEC61850 specifies the type of broadcast data transfer services: Generic Object Oriented Substation Events (GOOSE). IEC61850 GOOSE services provide virtual LAN (VLAN) support, Ethernet priority tagging, and Ether-type Application ID configuration. The support for VLANs and priority tagging allows for the optimization of Ethernet network traffic. GOOSE messages can be given a higher priority than standard Ethernet traffic, and they can be separated onto specific 10-14
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10 Communication
VLANs. Devices that transmit GOOSE messages also function as servers. Each GOOSE publisher contains a “GOOSE control block” to configure and control the transmission. The GOOSE transmission (including subscribing and publishing) is controlled by GOOSE logic link settings in device. The PCS-900 series relays support IEC61850 Generic Object Oriented Substation Event (GOOSE) communication. All GOOSE messages contain IEC61850 data collected into a dataset. It is this dataset that is transferred using GOOSE message services. The GOOSE related dataset is configured in the CID file and it is recommended that the fixed GOOSE be used for implementations that require GOOSE data transfer between PCS-900 series relays. IEC61850 GOOSE messaging contains a number of configurable parameters, all of which must be correct to achieve the successful transfer of data. It is critical that the configured datasets at the transmission and reception devices are an exact match in terms of data structure, and that the GOOSE addresses and name strings match exactly.
10.4.6 ACSI Conformance 10.4.6.1 ACSI Basic Conformance Statement Services
Client
Server
PCS-900 Series
B11
Server side (of Two-party Application-Association)
-
C1
Y
B12
Client side (of Two-party Application-Association)
C1
-
N
Client-Server Roles
SCSMS Supported B21
SCSM: IEC 61850-8-1 used
Y
Y
Y
B22
SCSM: IEC 61850-9-1 used
N
N
N
B23
SCSM: IEC 61850-9-2 used
Y
N
Y
B24
SCSM: other
N
N
N
Generic Substation Event Model (GSE) B31
Publisher side
-
O
Y
B32
Subscriber side
O
-
Y
Transmission Of Sampled Value Model (SVC) B41
Publisher side
-
O
N
B42
Subscriber side
O
-
N
Where: C1: Shall be "M" if support for LOGICAL-DEVICE model has been declared O: Optional M: Mandatory Y:
Supported by PCS-900 series relays
N:
Currently not supported by PCS-900 series relays
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10.4.6.2 ACSI Models Conformance Statement Services
Client
Server
PCS-900 Series
M1
Logical device
C2
C2
Y
M2
Logical node
C3
C3
Y
M3
Data
C4
C4
Y
M4
Data set
C5
C5
Y
M5
Substitution
O
O
Y
M6
Setting group control
O
O
Y
M7
Buffered report control
O
O
Y
M7-1
sequence-number
Y
Y
Y
M7-2
report-time-stamp
Y
Y
Y
M7-3
reason-for-inclusion
Y
Y
Y
M7-4
data-set-name
Y
Y
Y
M7-5
data-reference
Y
Y
Y
M7-6
buffer-overflow
Y
Y
N
M7-7
entryID
Y
Y
Y
M7-8
BufTm
N
N
N
M7-9
IntgPd
Y
Y
Y
M7-10
GI
Y
Y
Y
M8
Unbuffered report control
M
M
Y
M8-1
sequence-number
Y
Y
Y
M8-2
report-time-stamp
Y
Y
Y
M8-3
reason-for-inclusion
Y
Y
Y
M8-4
data-set-name
Y
Y
Y
M8-5
data-reference
Y
Y
Y
M8-6
BufTm
N
N
N
M8-7
IntgPd
N
Y
Y
M9
Log control
O
O
N
M9-1
IntgPd
N
N
N
M10
Log
O
O
N
M12
GOOSE
O
O
Y
M13
GSSE
O
O
N
M14
Multicast SVC
O
O
N
M15
Unicast SVC
O
O
N
M16
Time
M
M
Y
M17
File transfer
O
O
Y
Reporting
Logging
GSE
Where: C2: Shall be "M" if support for LOGICAL-NODE model has been declared 10-16
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10 Communication
C3: Shall be "M" if support for DATA model has been declared C4: Shall be "M" if support for DATA-SET, Substitution, Report, Log Control, or Time models has been declared C5: Shall be "M" if support for Report, GSE, or SMV models has been declared M: Mandatory Y:
Supported by PCS-900 series relays
N:
Currently not supported by PCS-900 series relays
10.4.6.3 ACSI Services Conformance Statement Services
Server/Publisher
PCS-931
M
Y
Server S1
ServerDirectory
Application association S2
Associate
M
Y
S3
Abort
M
Y
S4
Release
M
Y
M
Y
Logical device S5
LogicalDeviceDirectory
Logical node S6
LogicalNodeDirectory
M
Y
S7
GetAllDataValues
M
Y
S8
GetDataValues
M
Y
S9
SetDataValues
M
Y
S10
GetDataDirectory
M
Y
S11
GetDataDefinition
M
Y
S12
GetDataSetValues
M
Y
S13
SetDataSetValues
O
Y
S14
CreateDataSet
O
N
S15
DeleteDataSet
O
N
S16
GetDataSetDirectory
M
Y
M
Y
Data
Data set
Substitution S17
SetDataValues
Setting group control S18
SelectActiveSG
M/O
Y
S19
SelectEditSG
M/O
Y
S20
SetSGValuess
M/O
Y
S21
ConfirmEditSGValues
M/O
Y
S22
GetSGValues
M/O
Y
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10 Communication S23
GetSGCBValues
M/O
Y
Reporting Buffered report control block S24
Report
M
Y
S24-1
data-change
M
Y
S24-2
qchg-change
M
N
S24-3
data-update
M
N
S25
GetBRCBValues
M
Y
S26
SetBRCBValues
M
Y
Unbuffered report control block S27
Report
M
Y
S27-1
data-change
M
Y
S27-2
qchg-change
M
N
S27-3
data-update
M
N
S28
GetURCBValues
M
Y
S29
SetURCBValues
M
Y
Logging Log control block S30
GetLCBValues
O
N
S31
SetLCBValues
O
N
S32
QueryLogByTime
O
N
S33
QueryLogAfter
O
N
S34
GetLogStatusValues
O
N
Log
Generic substation event model (GSE) GOOSE control block S35
SendGOOSEMessage
M
Y
S36
GetGoReference
O
Y
S37
GetGOOSEElementNumber
O
N
S38
GetGoCBValues
M
Y
S39
SetGoCBValuess
M
N
S51
Select
O
N
S52
SelectWithValue
M
Y
S53
Cancel
M
Y
S54
Operate
M
Y
S55
Command-Termination
O
Y
S56
TimeActivated-Operate
O
N
Control
File transfer S57
GetFile
M/O
Y
S58
SetFile
O
N
S59
DeleteFile
O
N
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10 Communication S60
GetFileAttributeValues
M/O
Y
M
Y
Time SNTP
10.4.7 Logical Nodes 10.4.7.1 Logical Nodes Table The PCS-931 series relays support IEC61850 logical nodes as indicated in the following table. Note that the actual instantiation of each logical node is determined by the product order code. Nodes
PCS-931 Series
L: System Logical Nodes LPHD: Physical device information
YES
LLN0: Logical node zero
YES
P: Logical Nodes For Protection Functions PDIF: Differential
YES -
PDIR: Direction comparison PDIS: Distance
YES
PDOP: Directional overpower
-
PDUP: Directional underpower
-
PFRC: Rate of change of frequency
-
PHAR: Harmonic restraint
-
PHIZ: Ground detector
-
PIOC: Instantaneous overcurrent
-
PMRI: Motor restart inhibition
-
PMSS: Motor starting time supervision
-
POPF: Over power factor
-
PPAM: Phase angle measuring
-
PSCH: Protection scheme
YES
PSDE: Sensitive directional earth fault
-
PTEF: Transient earth fault
-
PTOC: Time overcurrent
YES
PTOF: Overfrequency
YES
PTOV: Overvoltage
YES
PTRC: Protection trip conditioning
YES
PTTR: Thermal overload
YES -
PTUC: Undercurrent PPDP: Pole discrepancy
YES
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10 Communication Nodes
PCS-931 Series
PTUV: Undervoltage
YES -
PUPF: Underpower factor PTUF: Underfrequency
YES
PVOC: Voltage controlled time overcurrent
-
PVPH: Volts per Hz
-
PZSU: Zero speed or underspeed
-
R: Logical Nodes For Protection Related Functions RDRE: Disturbance recorder function
YES
RADR: Disturbance recorder channel analogue
-
RBDR: Disturbance recorder channel binary
-
RDRS: Disturbance record handling
-
RBRF: Breaker failure
YES -
RDIR: Directional element RFLO: Fault locator
YES
RPSB: Power swing detection/blocking
YES
RREC: Autoreclosing
YES
RSYN: Synchronism-check or synchronizing
YES
C: Logical Nodes For Control CALH: Alarm handling
-
CCGR: Cooling group control
-
CILO: Interlocking
-
CPOW: Point-on-wave switching
-
CSWI: Switch controller
-
G: Logical Nodes For Generic References GAPC: Generic automatic process control
YES
GGIO: Generic process I/O
YES -
GSAL: Generic security application I: Logical Nodes For Interfacing And Archiving IARC: Archiving
-
IHMI: Human machine interface
-
ITCI: Telecontrol interface
-
ITMI: Telemonitoring interface
-
A: Logical Nodes For Automatic Control ANCR: Neutral current regulator
-
ARCO: Reactive power control
-
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10 Communication Nodes
PCS-931 Series
ATCC: Automatic tap changer controller
-
AVCO: Voltage control
-
M: Logical Nodes For Metering And Measurement MDIF: Differential measurements
YES
MHAI: Harmonics or interharmonics
-
MHAN: Non phase related harmonics or interharmonic
-
MMTR: Metering
-
MMXN: Non phase related measurement
-
MMXU: Measurement
YES
MSQI: Sequence and imbalance
-
MSTA: Metering statistics
-
S: Logical Nodes For Sensors And Monitoring SARC: Monitoring and diagnostics for arcs
-
SIMG: Insulation medium supervision (gas)
-
SIML: Insulation medium supervision (liquid)
-
SPDC: Monitoring and diagnostics for partial discharges
-
X: Logical Nodes For Switchgear TCTR: Current transformer
YES
TVTR: Voltage transformer
YES
Y: Logical Nodes For Power Transformers YEFN: Earth fault neutralizer (Peterson coil)
-
YLTC: Tap changer
-
YPSH: Power shunt
-
YPTR: Power transformer
-
Z: Logical Nodes For Further Power System Equipment ZAXN: Auxiliary network
-
ZBAT: Battery
-
ZBSH: Bushing
-
ZCAB: Power cable
-
ZCAP: Capacitor bank
-
ZCON: Converter
-
ZGEN: Generator
-
ZGIL: Gas insulated line
-
ZLIN: Power overhead line
-
ZMOT: Motor
-
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10 Communication Nodes
PCS-931 Series
ZREA: Reactor
-
ZRRC: Rotating reactive component
-
ZSAR: Surge arrestor
-
ZTCF: Thyristor controlled frequency converter
-
ZTRC: Thyristor controlled reactive component
-
10.5 DNP3.0 Interface 10.5.1 Overview The descriptions given here are intended to accompany this relay. The DNP3.0 protocol is not described here; please refer to the DNP3.0 protocol standard for the details about the DNP3.0 implementation. This manual only specifies which objects, variations and qualifiers are supported in this relay, and also specifies what data is available from this relay via DNP3.0. The relay operates as a DNP3.0 slave and supports subset level 2 of the protocol, plus some of the features from level 3. The DNP3.0 communication uses the Ethernet ports at the rear side of this relay. The Ethernet ports are optional: electrical or optical.
10.5.2 Link Layer Functions Please see the DNP3.0 protocol standard for the details about the linker layer functions.
10.5.3 Transport Functions Please see the DNP3.0 protocol standard for the details about the transport functions.
10.5.4 Application Layer Functions 10.5.4.1 Time Synchronization 1.
2.
3.
Time delay measurement Master/Slave
Function Code
Object
Variation
Qualifier
Master
0x17
-
-
-
Slave
0x81
0x34
0x02
0x07
Master/Slave
Function Code
Object
Variation
Qualifier
Master
0x01
0x34
0x00, 0x01
0x07-
Slave
0x81
0x32
0x01
0x07
Read time of device
Write time of device Master/Slave
Function Code
Object
Variation
Qualifier
Master
0x02
0x32
0x01
0x00, 0x01, 0x07, 0x08
Slave
0x81
-
-
-
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10 Communication
10.5.4.2 Supported Writing Functions 1.
Write time of device See Section 10.5.4.1 for the details.
2.
Reset the CU (Reset IIN bit7) Master/Slave
Function Code
Object
Variation
Qualifier
Master
0x02
0x50
0x01
0x00, 0x01
Slave
0x81
-
-
-
10.5.4.3 Supported Reading Functions 1.
2.
Supported qualifiers Master Qualifier
0x00
0x01
0x06
0x07
0x08
Slave Qualifier
0x00
0x01
0x01
0x07
0x08
Supported objects and variations
Object 1, Binary inputs Master Variation
0x00
0x01
0x02
Slave Variation
0x02
0x01
0x02
The protection operation signals, alarm signals and binary input state change signals are transported respectively according to the variation sequence in above table.
Object 2, SOE Master Variation
0x00
0x01
0x02
0x03
Slave Variation
0x02
0x01
0x02
0x03
If the master qualifier is “0x07”, the slave responsive qualifier is “0x27”; and if the master qualifier is “0x01”, “0x06” or “0x08”, the slave responsive qualifier is “0x28”.
Object 30, Analog inputs Master Variation
0x00
0x01
0x02
0x03
0x04
Slave Variation
0x01
0x01
0x02
0x03
0x04
The measurement values are transported firstly, and then the measurement values are transported.
Object 40, Analog outputs Master Variation
0x00
0x01
0x02
Slave Variation
0x01
0x01
0x02
The protection settings are transported in this object.
Object 50, Time Synchronization See Section 10.5.4.1 for the details.
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10 Communication
3.
Class 0 data request The master adopts the “Object 60” for the Class 0 data request and the variation is “0x01”. The slave responds with the above mentioned “Object 1”, “Object 30” and “Object 40” (see “Supported objects and variations” in Section 10.5.4.3).
4.
Class 1 data request The master adopts the “Object 60” for the Class 1 data request and the variation is “0x02”. The slave responds with the above mentioned “Object 2” (see “Supported objects and variations” in Section 10.5.4.3).
5.
Multiple object request The master adopts the “Object 60” for the multiple object request and the variation is “0x01”, “0x02”, “0x03” and “0x04”. The slave responds with the above mentioned “Object 1”, “Object 2”, “Object 30” and “Object 40” (see “Supported objects and variations” in Section 10.5.4.3).
10.5.4.4 Remote Control Functions The function code 0x03 and 0x04 are supported in this relay. The function code 0x03 is for the remote control with selection; and the function code 0x04 is for the remote control with execution. The selection operation must be executed before the execution operation, and the single point control object can be supported to this relay. Master Qualifier
0x17
0x27
0x18
0x28
Slave Qualifier
0x17
0x27
0x18
0x28
The “Object 12” is for the remote control functions. Master Variation
0x01
Slave Variation
0x01
Control Code
0x01: closing 0x10: tripping
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11 Installation
11 Installation Table of Contents 11 Installation .................................................................................... 11-a 11.1 Overview ....................................................................................................... 11-1 11.2 Safety Information ........................................................................................ 11-1 11.3 Checking Shipment ...................................................................................... 11-2 11.4 Material and Tools Required........................................................................ 11-2 11.5 Device Location and Ambient Conditions.................................................. 11-2 11.6 Mechanical Installation ................................................................................ 11-3 11.7 Electrical Installation and Wiring ................................................................ 11-4 11.7.1 Grounding Guidelines .................................................................................................... 11-4 11.7.2 Cubicle Grounding ......................................................................................................... 11-4 11.7.3 Ground Connection on the Device ................................................................................. 11-5 11.7.4 Grounding Strips and their Installation............................................................................ 11-6 11.7.5 Guidelines for Wiring ...................................................................................................... 11-6 11.7.6 Wiring for Electrical Cables ............................................................................................ 11-7
List of Figures Figure 11.6-1 Dimensions and panel cut-out of PCS-931 ..................................................... 11-3 Figure 11.6-2 Demonstration of plugging a board into its corresponding slot .................. 11-4 Figure 11.7-1 Cubicle grounding system ............................................................................... 11-5 Figure 11.7-2 Ground terminal of this relay ........................................................................... 11-6 Figure 11.7-3 Ground strip and termination .......................................................................... 11-6 Figure 11.7-4 Glancing demo about the wiring for electrical cables ................................... 11-7
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11 Installation
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11 Installation
11.1 Overview The device must be shipped, stored and installed with the greatest care. Choose the place of installation such that the communication interface and the controls on the front of the device are easily accessible. Air must circulate freely around the equipment. Observe all the requirements regarding place of installation and ambient conditions given in this instruction manual. Take care that the external wiring is properly brought into the equipment and terminated correctly and pay special attention to grounding. Strictly observe the corresponding guidelines contained in this section.
11.2 Safety Information Modules and units may only be replaced by correspondingly trained personnel. Always observe the basic precautions to avoid damage due to electrostatic discharge when handling the equipment. In certain cases, the settings have to be configured according to the demands of the engineering configuration after replacement. It is therefore assumed that the personnel who replace modules and units are familiar with the use of the operator program on the service PC. DANGER! Only insert or withdraw the PWR module while the power supply is switched off. To this end, disconnect the power supply cable that connects with the PWR module. WARNING! Only insert or withdraw other modules while the power supply is switched off. WARNING! The modules may only be inserted in the slots designated in Section 6.2. Components can be damaged or destroyed by inserting boards in the wrong slots. DANGER! Improper handling of the equipment can cause damage or an incorrect response of the equipment itself or the primary plant. WARNING! Industry packs and ribbon cables may only be replaced or the positions of jumpers be changed on a workbench appropriately designed for working on electronic equipment. The PCS-931 Line Differential Relay
11-1 Date: 2013-09-11
11 Installation
modules, bus backplanes are sensitive to electrostatic discharge when not in the unit's housing. The basic precautions to guard against electrostatic discharge are as follows:
Should boards have to be removed from this relay installed in a grounded cubicle in an HV switchgear installation, please discharge yourself by touching station ground (the cubicle) beforehand.
Only hold electronic boards at the edges, taking care not to touch the components.
Only works on boards that have been removed from the cubicle on a workbench designed for electronic equipment and wear a grounded wristband. Do not wear a grounded wristband, however, while inserting or withdrawing units.
Always store and ship the electronic boards in their original packing. Place electronic parts in electrostatic screened packing materials.
11.3 Checking Shipment Check that the consignment is complete immediately upon receipt. Notify the nearest NR Company or agent, should departures from the delivery note, the shipping papers or the order be found. Visually inspect all the material when unpacking it. When there is evidence of transport damage, lodge a claim immediately in writing with the last carrier and notify the nearest NR Company or agent. If the equipment is not going to be installed immediately, store all the parts in their original packing in a clean dry place at a moderate temperature. The humidity at a maximum temperature and the permissible storage temperature range in dry air are listed in Chapter “Technical Data”.
11.4 Material and Tools Required The necessary mounting kits will be provided, including screws, pincers and assembly instructions. A suitable drill and spanners are required to secure the cubicles to the floor using the plugs provided (if this relay is mounted in cubicles).
11.5 Device Location and Ambient Conditions The place of installation should permit easy access especially to front of the device, i.e. to the human machine interface of the equipment. There should also be free access at the rear of the equipment for additions and replacement of electronic boards. Since every piece of technical equipment can be damaged or destroyed by inadmissible ambient conditions, such as:
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11 Installation
1.
The location should not be exposed to excessive air pollution (dust, aggressive substances).
2.
Severe vibration, extreme changes of temperature, high levels of humidity, surge voltages of high amplitude and short rise time and strong induced magnetic fields should be avoided as far as possible.
3.
Air must not be allowed to circulate freely around the equipment.
The equipment can in principle be mounted in any attitude, but it is normally mounted vertically (visibility of markings). WARNING! Excessively high temperature can appreciably reduce the operating life of this relay.
11.6 Mechanical Installation The device adopts IEC standard chassis and is rack with modular structure. It uses an integral faceplate and plug terminal block on backboard for external connections. PCS-931 series is IEC 4U high, and Figure 11.6-1 shows its dimensions and panel cut-out.
Figure 11.6-1 Dimensions and panel cut-out of PCS-931
Note! It is necessary to leave enough space top and bottom of the cut-out in the cubicle for heat emission of this relay. The safety instructions must be abided by when installing the boards, please see Section 11.2 for the details. PCS-931 Line Differential Relay
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11 Installation
Following figure shows the installation way of a module being plugged into a corresponding slot.
Figure 11.6-2 Demonstration of plugging a board into its corresponding slot
In the case of equipment supplied in cubicles, place the cubicles on the foundations that have been prepared. Take care while doing so not to jam or otherwise damage any of the cables that have already been installed. Secure the cubicles to the foundations.
11.7 Electrical Installation and Wiring 11.7.1 Grounding Guidelines Switching operations in HV installations generate transient over voltages on control signal cables. There is also a background of electromagnetic RF fields in electrical installations that can induce spurious currents in the devices themselves or the leads connected to them. All these influences can influence the operation of electronic apparatus. On the other hand, electronic apparatus can transmit interference that can disrupt the operation of other apparatus. In order to minimize these influences as far as possible, certain standards have to be observed with respect to grounding, wiring and screening. Note! All these precautions can only be effective if the station ground is of good quality.
11.7.2 Cubicle Grounding The cubicle must be designed and fitted out such that the impedance for RF interference of the ground path from the electronic device to the cubicle ground terminal is as low as possible. Metal accessories such as side plates, blanking plates etc., must be effectively connected surface-to-surface to the grounded frame to ensure a low-impedance path to ground for RF interference. The contact surfaces must not only conduct well, they must also be non-corroding. Note! If the above conditions are not fulfilled, there is a possibility of the cubicle or parts of it 11-4
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11 Installation
forming a resonant circuit at certain frequencies that would amplify the transmission of interference by the devices installed and also reduce their immunity to induced interference. Movable parts of the cubicle such as doors (front and back) or hinged equipment frames must be effectively grounded to the frame by three braided copper strips (see Figure 11.7-1). The metal parts of the cubicle housing and the ground rail are interconnected electrically conducting and corrosion proof. The contact surfaces shall be as large as possible. Note! For metallic connections please observe the voltage difference of both materials according to the electrochemical code. The cubicle ground rail must be effectively connected to the station ground rail by a grounding strip (braided copper).
Door or hinged equipment frame
Cubicle ground rail close to floor
Braided copper strip Station ground Conducting connection
Figure 11.7-1 Cubicle grounding system
11.7.3 Ground Connection on the Device There is a ground terminal on the rear panel, and the ground braided copper strip can be connected with it. Take care that the grounding strip is always as short as possible. The main thing is that the device is only grounded at one point. Grounding loops from unit to unit are not allowed. There are some ground terminals on some connectors of this relay, and the sign is “GND”. All the ground terminals are connected in the cabinet of this relay. So, the ground terminal on the rear panel (see Figure 11.7-2) is the only ground terminal of this device.
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Figure 11.7-2 Ground terminal of this relay
11.7.4 Grounding Strips and their Installation High frequency currents are produced by interference in the ground connections and because of skin effect at these frequencies, only the surface region of the grounding strips is of consequence. The grounding strips must therefore be of (preferably tinned) braided copper and not round copper conductors, as the cross-section of round copper would have to be too large. Proper terminations must be fitted to both ends (press/pinch fit and tinned) with a hole for bolting them firmly to the items to be connected. The surfaces to which the grounding strips are bolted must be electrically conducting and non-corroding. The following figure shows the ground strip and termination. Press/pinch fit cable terminal
Braided copper strip
Terminal bolt Contact surface
Figure 11.7-3 Ground strip and termination
11.7.5 Guidelines for Wiring There are several types of cables that are used in the connection of this relay: braided copper cable, serial communication cable etc. Recommendation of each cable:
Grounding: braided copper cable, 2.5mm2 ~ 6.0mm2
Power supply, binary inputs & outputs: brained copper cable, 1.0mm2 ~ 2.5mm2
AC voltage inputs: brained copper cable, 1.0mm2 ~ 2.5mm2
AC current inputs: brained copper cable, 1.5mm2 ~ 4.0mm2
Serial communication: 4-core shielded braided cable
Ethernet communication: 4-pair screened twisted category 5E cable
11-6
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11 Installation
11.7.6 Wiring for Electrical Cables A female connector is used for connecting the wires with it, and then a female connector plugs into a corresponding male connector that is in the front of one board. See Chapter “Hardware” for further details about the pin defines of these connectors. The following figure shows the glancing demo about the wiring for the electrical cables.
Tighten
01
02
03
04
05
06
07
08
09
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
01
Figure 11.7-4 Glancing demo about the wiring for electrical cables
DANGER! Never allow the current transformer (CT) secondary circuit connected to this equipment to be opened while the primary system is live. Opening the CT circuit will produce a dangerously high voltage.
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12 Commissioning
12 Commissioning Table of Contents 12 Commissioning ............................................................................ 12-a 12.1 Overview ...................................................................................................... 12-1 12.2 Safety Instructions ...................................................................................... 12-1 12.3 Commission Tools ...................................................................................... 12-2 12.4 Setting Familiarization ................................................................................ 12-2 12.5 Product Checks ........................................................................................... 12-3 12.5.1 With the Relay De-energized ......................................................................................... 12-3 12.5.2 With the Relay Energized............................................................................................... 12-5 12.5.3 Print Fault Report ........................................................................................................... 12-8 12.5.4 On-load Checks ............................................................................................................. 12-8
12.6 Final Checks ................................................................................................ 12-9
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12.1 Overview This relay is fully numerical in their design, implementing all protection and non-protection functions in software. The relay employs a high degree of self-checking and in the unlikely event of a failure, will give an alarm. As a result of this, the commissioning test does not need to be as extensive as with non-numeric electronic or electro-mechanical relays. To commission numerical relays, it is only necessary to verify that the hardware is functioning correctly and the application-specific software settings have been applied to the relay. Blank commissioning test and setting records are provided at the end of this manual for completion as required. Before carrying out any work on the equipment, the user should be familiar with the contents of the safety and technical data sections and the ratings on the equipment’s rating label.
12.2 Safety Instructions WARNING! Hazardous voltages are present in this electrical equipment during operation. Non-observance of the safety rules can result in severe personal injury or property damage. WARNING! Only the qualified personnel shall work on and around this equipment after becoming thoroughly familiar with all warnings and safety notices of this manual as well as with the applicable safety regulations. Particular attention must be drawn to the following:
The earthing screw of the device must be connected solidly to the protective earth conductor before any other electrical connection is made.
Hazardous voltages can be present on all circuits and components connected to the supply voltage or to the measuring and test quantities.
Hazardous voltages can be present in the device even after disconnection of the supply voltage (storage capacitors!)
The limit values stated in the Chapter “Technical Data” must not be exceeded at all, not even during testing and commissioning.
When testing the device with secondary test equipment, make sure that no other measurement quantities are connected. Take also into consideration that the trip circuits and maybe also close commands to the circuit breakers and other primary switches are disconnected from the device unless expressly stated.
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DANGER! Current transformer secondary circuits must have been short-circuited before the current leads to the device are disconnected. WARNING! Primary test may only be carried out by qualified personnel, who are familiar with the commissioning of protection system, the operation of the plant and safety rules and regulations (switching, earthing, etc.).
12.3 Commission Tools Minimum equipment required:
Multifunctional dynamic current and voltage injection test set with interval timer.
Multimeter with suitable AC current range and AC/DC voltage ranges of 0~440V and 0~250V respectively.
Continuity tester (if not included in the multimeter).
Phase angle meter.
Phase rotation meter. Note! Modern test set may contain many of the above features in one unit.
Optional equipment:
An electronic or brushless insulation tester with a DC output not exceeding 500V (for insulation resistance test when required).
A portable PC, with appropriate software (this enables the rear communications port to be tested, if this is to be used, and will also save considerable time during commissioning).
EIA RS-485 to EIA RS-232 converter (if EIA RS-485 IEC60870-5-103 port is being tested).
PCS-900 serials dedicated protection tester HELP-2000.
12.4 Setting Familiarization When commissioning this device for the first time, sufficient time should be allowed to become familiar with the method by which the settings are applied. A detailed description of the menu structure of this relay is contained in Chapter “Operation Theory” and Chapter “Settings”. With the front cover in place all keys are accessible. All menu cells can be read. The LED indicators and alarms can be reset. Protection or configuration settings can be changed, or fault 12-2
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and event records cleared. However, menu cells will require the appropriate password to be entered before changes can be made. Alternatively, if a portable PC is available together with suitable setting software (such as PCS-9700 SAS software), the menu can be viewed one page at a time to display a full column of data and text. This PC software also allows settings to be entered more easily, saved to a file on disk for future reference or printed to produce a setting record. Refer to the PC software user manual for details. If the software is being used for the first time, allow sufficient time to become familiar with its operation.
12.5 Product Checks These product checks cover all aspects of the relay which should be checked to ensure that it has not been physically damaged prior to commissioning, is functioning correctly and all input quantity measurements are within the stated tolerances. If the application-specific settings have been applied to the relay prior to commissioning, it is advisable to make a copy of the settings so as to allow them restoration later. This could be done by extracting the settings from the relay itself via printer or manually creating a setting record.
12.5.1 With the Relay De-energized This relay is fully numerical and the hardware is continuously monitored. Commissioning tests can be kept to a minimum and need only include hardware tests and conjunctive tests. The function tests are carried out according to user’s correlative regulations. The following tests are necessary to ensure the normal operation of the equipment before it is first put into service.
Hardware tests These tests are performed for the following hardware to ensure that there is no hardware defect. Defects of hardware circuits other than the following can be detected by self-monitoring when the DC power is supplied.
User interfaces test
Binary input circuits and output circuits test
AC input circuits test
Function tests These tests are performed for the following functions that are fully software-based. Tests of the protection schemes and fault locator require a dynamic test set.
Measuring elements test
Timers test
Measurement and recording test
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Conjunctive tests The tests are performed after the relay is connected with the primary equipment and other external equipment.
On load test.
Phase sequence check and polarity check.
12.5.1.1 Visual Inspection After unpacking the product, check for any damage to the relay case. If there is any damage, the internal module might also have been affected, contact the vendor. The following items listed is necessary.
Protection panel Carefully examine the protection panel, protection equipment inside and other parts inside to see that no physical damage has occurred since installation. The rated information of other auxiliary protections should be checked to ensure it is correct for the particular installation.
Panel wiring Check the conducting wire which is used in the panel to assure that their cross section meeting the requirement. Carefully examine the wiring to see that they are no connection failure exists.
Label Check all the isolator binary inputs, terminal blocks, indicators, switches and push buttons to make sure that their labels meet the requirements of this project.
Device plug-in modules Check each plug-in module of the equipments on the panel to make sure that they are well installed into the equipment without any screw loosened.
Earthing cable Check whether the earthing cable from the panel terminal block is safely screwed to the panel steel sheet.
Switch, keypad, isolator binary inputs and push button Check whether all the switches, equipment keypad, isolator binary inputs and push buttons work normally and smoothly.
12.5.1.2 Insulation Test (if required) Insulation resistance tests are only necessary during commissioning if it is required for them to be done and they have not been performed during installation.
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Isolate all wiring from the earth and test the isolation with an electronic or brushless insulation tester at a DC voltage not exceeding 500V, The circuits need to be tested should include:
Voltage transformer circuits
Current transformer circuits
DC power supply
Optic-isolated control inputs
Output contacts
Communication ports
The insulation resistance should be greater than 100MΩ at 500V. Test method: To unplug all the terminals sockets of this relay, and do the Insulation resistance test for each circuit above with an electronic or brushless insulation tester. On completion of the insulation resistance tests, ensure all external wiring is correctly reconnected to the protection. 12.5.1.3 External Wiring Check that the external wiring is correct to the relevant relay diagram and scheme diagram. Ensure as far as practical that phasing/phase rotation appears to be as expected. Check the wiring against the schematic diagram for the installation to ensure compliance with the customer’s normal practice. 12.5.1.4 Auxiliary Power Supply The relay only can be operated under the auxiliary power supply depending on the relay’s nominal power supply rating. The incoming voltage must be within the operating range specified in Chapter “Technical Data”, before energizing the relay, measure the auxiliary supply to ensure it within the operating range. Other requirements to the auxiliary power supply are specified in Chapter “Technical Data”. See this section for further details about the parameters of the power supply. WARNING! Energize this relay only if the power supply is within the specified operating ranges in Chapter “Technical Data”.
12.5.2 With the Relay Energized The following groups of checks verify that the relay hardware and software is functioning correctly and should be carried out with the auxiliary supply applied to the relay.
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The current and voltage transformer connections must remain isolated from the relay for these checks. The trip circuit should also remain isolated to prevent accidental operation of the associated circuit breaker. 12.5.2.1 Front Panel LCD Display Connect the relay to DC power supply correctly and turn the relay on. Check program version and forming time displayed in command menu to ensure that are corresponding to what ordered. 12.5.2.2 Date and Time If the time and date is not being maintained by substation automation system, the date and time should be set manually. Set the date and time to the correct local time and date using menu item “Clock”. In the event of the auxiliary supply failing, with a battery fitted on CPU board, the time and date will be maintained. Therefore when the auxiliary supply is restored the time and date will be correct and not need to set again. To test this, remove the auxiliary supply from the relay for approximately 30s. After being re-energized, the time and date should be correct. 12.5.2.3 Light Emitting Diodes (LEDs) On power up, the green LED “HEALTHY” should have illuminated and stayed on indicating that the relay is healthy. The relay has latched signal relays which remember the state of the trip, auto-reclose when the relay was last energized from an auxiliary supply. Therefore these indicators may also illuminate when the auxiliary supply is applied. If any of these LEDs are on then they should be reset before proceeding with further testing. If the LED successfully reset, the LED goes out. There is no testing required for that that LED because it is known to be operational. It is likely that alarms related to voltage transformer supervision will not reset at this stage. 12.5.2.4 Testing HEALTHY and ALARM LEDs Apply the rated DC power supply and check that the “HEALTHY” LED is lighting in green. We need to emphasize that the “HEALTHY” LED is always lighting in operation course except that the equipment find serious errors in it. Produce one of the abnormal conditions listed in Chapter “Supervision”, the “ALARM” LED will light in yellow. When abnormal condition reset, the “ALARM” LED extinguishes. 12.5.2.5 Testing AC Current Inputs This test verified that the accuracy of current measurement is within the acceptable tolerances. Apply rated current to each current transformer input in turn; checking its magnitude using a multimeter/test set readout. The corresponding reading can then be checked in the relays menu. The measurement accuracy of the protection is 2.5% or 0.02In. However, an additional allowance
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must be made for the accuracy of the test equipment being used. Note! The closing circuit should remain isolated during these checks to prevent accidental operation of the associated circuit breaker. Group No.
Item
Input Value
Input Angle
Display Value
Display Angle
Ia Three-phase current 1
Ib Ic Ia
Three-phase current 2
Ib Ic Ia
Three-phase current 3
Ib Ic Ia
Three-phase current ……
Ib Ic
12.5.2.6 Testing AC Voltage Inputs This test verified that the accuracy of voltage measurement is within the acceptable tolerances. Apply rated voltage to each voltage transformer input in turn; checking its magnitude using a multimeter/test set readout. The corresponding reading can then be checked in the relays menu. The measurement accuracy of the relay is 2.5% or 0.1V. However an additional allowance must be made for the accuracy of the test equipment being used. Note! The closing circuit should remain isolated during these checks to prevent accidental operation of the associated circuit breaker. Group No.
Item
Input Value
Input Angle
Display Value
Display Angle
Ua Three-phase voltage 1
Ub Uc Ua
Three-phase voltage 2
Ub Uc
Three-phase voltage 3
Ua
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12 Commissioning Group No.
Item
Input Value
Input Angle
Display Value
Display Angle
Ub Uc Ua Three-phase voltage……
Ub Uc
12.5.2.7 Testing Binary Inputs This test checks that all the binary inputs on the equipment are functioning correctly. The binary inputs should be energized one at a time, see external connection diagrams for terminal numbers. Ensure that the voltage applied on the binary input must be within the operating range. The status of each binary input can be viewed using relay menu. Sign “1” denotes an energized input and sign “0” denotes a de-energized input. Terminal No.
Signal Name
BI Status on LCD
Correct?
12.5.3 Print Fault Report In order to acquire the details of protection operation, it is convenient to print the fault report of protection device. The printing work can be easily finished when operator presses the print button on panel of protection device to energize binary input [BI_Print] or operate control menu. What should be noticed is that only the latest fault report can be printed if operator presses the print button. A complete fault report includes the content shown as follows. 1) Trip event report 2) Binary input when protection devices start 3) Self-check and the transition of binary input in the process of devices start 4) Fault wave forms compatible with COMTRADE 5) The setting value when the protection device trips
12.5.4 On-load Checks The objectives of the on-load checks are:
Confirm the external wiring to the current and voltage inputs is correct.
Measure the magnitude of on-load current and voltage (if applicable).
Check the polarity of each current transformer.
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However, these checks can only be carried out if there are no restrictions preventing the tenderization of the plant being protected. Remove all test leads, temporary shorting leads, etc. and replace any external wiring that has been removed to allow testing. If it has been necessary to disconnect any of the external wiring from the protection in order to perform any of the foregoing tests, it should be ensured that all connections are replaced in accordance with the relevant external connection or scheme diagram. Confirm current and voltage transformer wiring.
12.6 Final Checks After the above tests are completed, remove all test or temporary shorting leads, etc. If it has been necessary to disconnect any of the external wiring from the protection in order to perform the wiring verification tests, it should be ensured that all connections are replaced in accordance with the relevant external connection or scheme diagram. Ensure that the protection has been restored to service. If the protection is in a new installation or the circuit breaker has just been maintained, the circuit breaker maintenance and current counters should be zero. If a test block is installed, remove the test plug and replace the cover so that the protection is put into service. Ensure that all event records, fault records, disturbance records and alarms have been cleared and LED’s has been reset before leaving the protection.
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13 Maintenance
13 Maintenance Table of Contents 13 Maintenance ................................................................................. 13-a 13.1 Appearance Check ...................................................................................... 13-1 13.2 Failure Tracing And Repair ......................................................................... 13-1 13.3 Replace Failed Modules ............................................................................. 13-1 13.4 Cleaning ....................................................................................................... 13-3 13.5 Storage ......................................................................................................... 13-3
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13 Maintenance
13-b
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13 Maintenance
NR numerical relay PCS-931 is designed to require no special maintenance. All measurement and signal processing circuit are fully solid state. All input modules are also fully solid state. The output relays are hermetically sealed. Since the device is almost completely self-monitored, from the measuring inputs to the output relays, hardware and software defects are automatically detected and reported. The self-monitoring ensures the high availability of the device and generally allows for a corrective rather than preventive maintenance strategy. Therefore, maintenance checks in short intervals are not required. Operation of the device is automatically blocked when a hardware failure is detected. If a problem is detected in the external measuring circuits, the device normally only provides alarm messages.
13.1 Appearance Check 1. The relay case should be clean without any dust stratification. Case cover should be sealed well. No component has any mechanical damage and distortion, and they should be firmly fixed in the case. Relay terminals should be in good condition. The keys on the front panel with very good feeling can be operated flexibly. 2. It is only allowed to plug or withdraw relay board when the supply is reliably switched off. Never allow the CT secondary circuit connected to this equipment to be opened while the primary system is live when withdrawing an AC module. Never try to insert or withdraw the relay board when it is unnecessary. 3. Check weld spots on PCB whether they are well soldered without any rosin joint. All dual inline components must be well plugged.
13.2 Failure Tracing And Repair Failures will be detected by automatic supervision or regular testing. When a failure is detected by supervision, a remote alarm is issued and the failure is indicated on the front panel with LED indicators and LCD display. It is also recorded in the event record. Failures detected by supervision are traced by checking the “Superv Events” screen on the LCD. When a failure is detected during regular testing, confirm the following:
Test circuit connections are correct
Modules are securely inserted in position
Correct DC power voltage is applied
Correct AC inputs are applied
Test procedures comply with those stated in the manual
13.3 Replace Failed Modules If the failure is identified to be in the relay module and the user has spare modules, the user can PCS-931 Line Differential Relay
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13 Maintenance
recover the protection by replacing the failed modules. Repair at the site should be limited to module replacement. Maintenance at the component level is not recommended. Check that the replacement module has an identical module name (AI, PWR, CPU, SIG, BI, BO, etc.) and hardware type-form as the removed module. Furthermore, the CPU module replaced should have the same software version. In addition, the AI and PWR module replaced should have the same ratings. The module name is indicated on the top front of the module. The software version is indicated in LCD menu “Version Info”. Caution! When handling a module, take anti-static measures such as wearing an earthed wrist band and placing modules on an earthed conductive mat. Otherwise, many of the electronic components could suffer damage. After replacing the CPU module, check the settings. 1)
Replacing a module
Switch off the DC power supply
Disconnect the trip outputs
Short circuit all AC current inputs and disconnect all AC voltage inputs
Unscrew the module. Warning! Hazardous voltage can be present in the DC circuit just after switching off the DC power supply. It takes approximately 30 seconds for the voltage to discharge.
2)
Replacing the Human Machine Interface Module (front panel)
Open the relay front panel
Unplug the ribbon cable on the front panel by pushing the catch outside.
Detach the HMI module from the relay
Attach the replacement module in the reverse procedure.
3)
Replacing the AI, PWR, CPU, BI or BO module
Unscrew the module connector
Unplug the connector from the target module.
Unscrew the module.
Pull out the module
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13 Maintenance
Inset the replacement module in the reverser procedure.
After replacing the CPU module, input the application-specific setting values again. Warning! Units and modules may only be replaced while the supply is switched off and only by appropriately trained and qualified personnel. Strictly observe the basic precautions to guard against electrostatic discharge. Warning! When handling a module, take anti-static measures such as wearing an earthed wrist band and placing modules on an earthed conductive mat. Otherwise, many of the electronic components could suffer damage. After replacing the CPU module, check the settings. Danger! After replacing modules, be sure to check that the same configuration is set as before the replacement. If this is not the case, there is a danger of the unintended operation of switchgear taking place or of protections not functioning correctly. Persons may also be put in danger.
13.4 Cleaning Before cleaning the relay, ensure that all AC/DC supplies, current transformer connections are isolated to prevent any chance of an electric shock whilst cleaning. Use a smooth cloth to clean the front panel. Do not use abrasive material or detergent chemicals.
13.5 Storage The spare relay or module should be stored in a dry and clean room. Based on IEC standard 60255-1 the storage temperature should be from -40oC to +70oC, but the temperature of from 0oC to +40oC is recommended for long-term storage.
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13-4
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14 Decommissioning and Disposal
14 Decommissioning and Disposal Table of Contents 14 Decommissioning and Disposal................................................. 14-a 14.1 Decommissioning ....................................................................................... 14-1 14.2 Disposal ....................................................................................................... 14-1
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14 Decommissioning and Disposal
14-b
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14 Decommissioning and Disposal
14.1 Decommissioning 1.
Switching off
To switch off the PCS-931, switch off the external miniature circuit breaker of the power supply. 2.
Disconnecting Cables
Disconnect the cables in accordance with the rules and recommendations made by relational department. Danger! Before disconnecting the power supply cables that connected with the PWR module of the PCS-931, make sure that the external miniature circuit breaker of the power supply is switched off. Danger! Before disconnecting the cables that are used to connect analog input module with the primary CTs and VTs, make sure that the circuit breaker for the primary CTs and VTs is switched off. 3.
Dismantling
The PCS-931 rack may now be removed from the system cubicle, after which the cubicles may also be removed. Danger! When the station is in operation, make sure that there is an adequate safety distance to live parts, especially as dismantling is often performed by unskilled personnel.
14.2 Disposal In every country there are companies specialized in the proper disposal of electronic waste. Note! Strictly observe all local and national regulations when disposing of the device.
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PCS-931 Line Differential Relay Date: 2011-04-13
15 Manual Version History
15 Manual Version History In the latest version of the instruction manual, several descriptions on existing features have been modified. Manual version and modification history records Manual Version Source
Software
New
Version
R1.00
R1.00
Date 2011-07-07
Description of change Form the original manual Add the description about C37.94 Rewrite datas of ambient temperature and humidity range and binary input Amend fault detector (FD) Add load encroachment element Delete blinder element
R1.00
R1.01
R1.10
2011-12-16
Amend current differential protection Add broken conductor protection Amend descriptions of supervision alarms Add remote control function Add explanations about that external CT circuit is closed itself Rewrite configurable function based on PCS-Explorer
R1.01
R1.02
R1.10
2012-03-15
R1.02
R1.03
R1.10
2012-05-08 2012-07-02
R1.03
R1.04
R2.00
2012-07-07
Modify remote control function Add GOOSE alarm signals Modify setting range of underfrequency protection Add blocking AR logic Add dead zone protection Modify logic of power swing blocking releasing Modify logic of reclosing failure and success
2012-08-14
Add zone 5 of distance protection
2012-12-10
Modify the breaking capacity of binary output contact
2013-05-29
Modify mechanical installation size of the device Modify the logic of AR Add symbol corresponding relationship about phase
R1.04
R1.05
R2.10
2013-06-01
sequence Modify the breaking capacity of binary output contact Add the setting of system parameters Add output sigals of function enabled and element
2013-05-29
operation ahead time delay. Add FD condition for all function logics Modify the setting description of clock synchronization
PCS-931 Line Differential Relay
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15 Manual Version History Manual Version Source
New
Software Version
Date
Description of change Modify function number of overcurrent protection for VT circuit failure Add settings for broken conductor protection and modify the logic Add function block diagram for power swing blocking releasing, current direction, trip logic, faulty phase
R1.04
R1.05
R2.11
2013-09-12
selection and fault location Add frequency upper limit setting and frequency lower limit setting for alarm Add the setting [IP_StandbyServer_SNTP] (the address of the standby SNTP time synchronization server) for communication settings Modify LCD displays and descriptions of human machine interface
R1.04
R1.05
R2.12
2013-11-11
Modify setting range of current direction settings Modify the logic of VT circuit supervision Delete the setting [phi0_Reach] (Phase angle of line zero-sequence impedance) Add
R1.05
R1.06
R2.13
2013-12-25
the
seting items of
communication
([Opt_Display_Status],
setting
[t_Dly_Net_DNP],
[Fmt_Setting_DNP]) Add the setting items of
Quadrilateral
Distance
Protection ([21Q.ZGx.RCA], [21Q.ZPx.RCA], x=1, 2, 3, 4) 2013-12-27
Add reverse power protection Add directionality option setting for reverse power
R1.06
R1.07
R2.13
2014-02-24
protection [32R.Opt_Dir], and modify the corresponding logic of reverse power protection
2014-03-06
Modify the logic of differential protection self-check
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