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Feeder Terminal Unit for Distribution Automation Auto Recloser Control Model Name : FTU-R200
Technical Manual V2.4
Information in this document is subject to change without notice. No part of this document may be reproduced or transmitted in any form or by any means, electronic or mechanical, for any purpose without the express written permission of PNC Technologies Co.,Ltd.
Copyright©2010 PNC Technologies Co., Ltd. All rights reserved
For further information, Contact: 6F, Kwangmyung B/D Bangi-dong, Songpa-gu 138-050, Republic of Korea
Tel Fax Website E-mail
+82-2-2240-8190 +82-2-2240-8195 http://www.pnctech.co.kr [email protected]
REVISION HISTORY REV
DATE
DESCRIPTION
1.0
2010-02-24
DRAFT
1.1
2011-07-04
UPDATED
1.2
2011-09-30
ADDED APPENDIX 1.
2.0
2012-08-22
UPDATED (FUNCTIONS WERE IMPROVED)
2.1
2013-02-04
2.2
2013-04-01
2.3
2013-10-14
INTERRUPTER DUTY MONITOR FUNCTION WAS ADDED
2.4
2013-11-01
NEGATIVE SEQUENCE OC WAS CHANGED TO I2/I1. AND DELAYED CLOSING FUNCTION WAS ADDED.
FUNCTION OF WAS ADDED.
PROGRAMMABLE
BUTTON
LOOP SCHEME WAS ADDED
TABLE OF CONTENTS
1. Overview ............................................................................................ 1 1.1.
Protection of Distribution Lines .................................................................. 1
1.2.
Function of Automatic Circuit Recloser ...................................................... 1
1.3.
Main Features of FTU-R200 ...................................................................... 2
2. Technical Data ................................................................................... 5 2.1.
Digital Processor ......................................................................................... 5
2.1.1.
Dual Processor Architecture.................................................................................................. 5
2.1.2.
Analog/Digital Conversion .................................................................................................... 5
2.1.3.
DSP ......................................................................................................................................... 5
2.1.4.
CPU ......................................................................................................................................... 6
2.1.5.
Functional Block Diagram ..................................................................................................... 6
2.2.
Environmental Conditions ......................................................................... 7
2.3.
Inputs/Outputs ........................................................................................... 8
2.4.
Measurement ............................................................................................ 10
2.4.1.
Current ................................................................................................................................. 10
2.4.2.
Voltage .................................................................................................................................. 10
2.4.3.
Power .................................................................................................................................... 10
2.4.4.
Power Factor ......................................................................................................................... 11
2.4.5.
Frequency .............................................................................................................................. 11
2.4.6.
Energy .................................................................................................................................... 11
2.4.7.
Harmonic............................................................................................................................... 11
2.4.8.
2.5.
Demand Current and Power................................................................................................ 12
Communication..........................................................................................13
2.5.1.
Physical Layer ...................................................................................................................... 13
2.5.2.
Protocol for scada ................................................................................................................ 14
2.6.
Recording ................................................................................................... 15
2.6.1.
Event Recorder..................................................................................................................... 15
2.6.2.
Waveform Event Recorder .................................................................................................. 15
3. Construct and External Connection .................................................. 16 3.1.
Appearance & Dimension ..........................................................................16
3.2.
Connector .................................................................................................. 18
4. Front Panel Operations .................................................................... 20 4.1.
Button & LED Description .........................................................................21
4.1.1.
LCD Display ......................................................................................................................... 21
4.1.2.
FTU Status ............................................................................................................................ 21
4.1.3.
MENU/UP/DOWN/ENTER Buttons ................................................................................. 21
4.1.4.
Serial Port ............................................................................................................................. 21
4.1.5.
Ethernet/SCADA/Protection Communication Led ........................................................... 21
4.1.6.
Battery Test & Lamp Test .................................................................................................... 22
4.1.7.
Reset Button ......................................................................................................................... 22
4.1.8.
Function Led ........................................................................................................................ 22
4.1.9.
RECLOSE/PROTECTION/GROUND Enable Buttons and LEDS .................................... 23
4.1.10.
REMOTE/HOT LINE TAG Buttons and LEDs .................................................................. 23
4.1.11.
4.2. 4.2.1.
SELECT/OPEN/CLOSE Buttons and LEDS ...................................................................... 23
LCD Manipulation .................................................................................... 24 LCD Menu ............................................................................................................................ 25
5. Protection Functions ........................................................................ 30 5.1.
Fault Detection .......................................................................................... 30
5.1.1.
Definite Time Protection................................................................................................. 31
5.1.2.
High Current Trip (HCT) ................................................................................................ 32
5.1.3.
Single Shot Operation ...................................................................................................... 32
5.1.4.
TC Curve ............................................................................................................................. 33
5.1.5.
Example of TC Curve Editing .............................................................................................. 35
5.1.6.
Auto Reclosing Sequence .................................................................................................... 37
5.1.7.
Sequence Coordination........................................................................................................ 39
5.2.
Cold Load Pickup ...................................................................................... 40
5.3.
Inrush Restraint .........................................................................................41
5.4.
Sensitive Earth Fault (SEF) Detection .................................................... 42
5.5.
Direction Detection ................................................................................... 44
5.6.
Negative Phase Sequence (NPS) Detection .............................................. 45
5.7.
Open Line Detection (Loss Of Phase) ....................................................... 46
5.8.
Phase Sync. Check ..................................................................................... 46
5.9.
Under Voltage Protection ......................................................................... 47
5.10.
Over Voltage Protection ............................................................................ 47
5.11.
Under Frequency Protection .................................................................... 48
5.12.
Over Frequency Protection ....................................................................... 48
5.13.
Analog Alarm ............................................................................................ 49
5.14.
Multiple Setting Groups............................................................................ 50
5.15.
Loop Automation Scheme.......................................................................... 51
6. Configuration Setting ....................................................................... 52 6.1.
I/O Configuration ..................................................................................... 52
6.1.1.
AC Rating ............................................................................................................................. 52
6.1.2.
Waveform Trigger ................................................................................................................ 53
6.1.3.
Demand Setting ................................................................................................................... 53
6.1.4.
Energy Profile....................................................................................................................... 54
6.1.5.
FI Reset Method ................................................................................................................... 54
6.1.6.
Close Interlock ..................................................................................................................... 54
6.1.7.
Voltage Display .................................................................................................................... 55
6.1.8.
Automatic Battery Check ..................................................................................................... 55
6.1.9.
FI Type Select ....................................................................................................................... 56
6.1.10.
Closing Delay ........................................................................................................................ 56
6.2.
Power Quality Monitoring Function......................................................... 57
6.2.1.
Voltage & Current Unbalance ............................................................................................. 57
6.2.2.
Short-Duration Voltage Variation....................................................................................... 57
6.2.3.
Voltage & Current THD Alarm ............................................................................................ 59
6.3. 6.3.1.
Communication......................................................................................... 60 Port Parameters ...................................................................................................................60
6.3.2.
DNP3.0 Parameters ............................................................................................................. 63
6.3.3.
IEC Parameters .................................................................................................................... 64
7. Status Monitoring & Control ............................................................ 65 7.1.
Switch (Recloser) Status Monitoring........................................................ 65
7.2.
Switch Control ........................................................................................... 66
7.3.
Battery & Battery Charger Monitoring ..................................................... 67
8. Measurements ................................................................................. 68 8.1.
Basic Electric Quantities ........................................................................... 68
8.2.
Sequence Components .............................................................................. 69
8.3.
Harmonics ................................................................................................. 69
8.4.
Energy ....................................................................................................... 69
8.5.
Demand currents and power ..................................................................... 71
8.6.
Interrupter Duty Monitor ......................................................................... 73
9. Maintenance Software ..................................................................... 74 9.1.
Overview .................................................................................................... 74
9.2.
Operation of FTUMan ............................................................................. 75
9.2.1.
Menu ..................................................................................................................................... 75
9.2.2.
Toolbar ................................................................................................................................. 79
9.2.3.
Statusbar ............................................................................................................................. 80
9.2.4.
Monitoring bar .................................................................................................................... 80
9.2.5.
Function and configuration Setting .................................................................................... 81
9.2.6.
Event .....................................................................................................................................83
9.2.7.
Measurement ....................................................................................................................... 91
9.2.8.
Waveform .............................................................................................................................98
10. I/O Configuration Tool ................................................................... 100 10.1.
Overview .................................................................................................. 100
10.2.
Operation of IOConfig ........................................................................... 101
10.2.1.
Menu ................................................................................................................................... 101
10.2.2.
Toolbar ............................................................................................................................... 102
10.2.3.
Input ................................................................................................................................... 103
10.2.4.
Output................................................................................................................................. 103
11. DNP3.0 Index Configuration Tool .................................................. 104 11.1.
Overview .................................................................................................. 104
11.2.
Operation of DNPConfig ...................................................................... 104
11.2.1.
Menu ................................................................................................................................... 106
11.2.2.
Toolbar ............................................................................................................................... 107
11.2.3.
Configuration Tool Box ..................................................................................................... 108
11.2.4.
Binary Input ....................................................................................................................... 109
11.2.5.
Binary Output...................................................................................................................... 111
11.2.6.
Analog Input........................................................................................................................112
11.2.7.
Counter ................................................................................................................................113
12. Waveform Evaluation Tool .............................................................. 115 12.1.
Overview ................................................................................................... 115
12.2.
Operation of EvalTool............................................................................ 116
12.2.1.
Menu ....................................................................................................................................116
12.2.2.
Toolbar ............................................................................................................................... 118
13. IEC Index Configuration Tool .......................................................... 119 13.1.
Overview ................................................................................................... 119
13.2.
Operation of IECConfig ........................................................................... 119
13.2.1.
Menu ................................................................................................................................... 120
13.2.2.
Toolbar ................................................................................................................................121
13.2.3.
Configuration Tool Box ..................................................................................................... 122
13.2.4.
MSP Point ........................................................................................................................... 123
13.2.5.
CSC Point ............................................................................................................................ 123
13.2.6.
MME Point ......................................................................................................................... 124
13.2.7.
MIT Point ........................................................................................................................... 125
Appendix 1. TC(Time-Current) Characteristic Curves .......................... 126
1.
OVERVIEW
1.1. PROTECTION OF DISTRIBUTION LINES
Distribution lines have their own equipment outdoors, the types of loads are various, and the configurations of the networks are flexible and complicated. There are many kinds of fault causes such as direct contact of trees or birds, natural phenomenon of lightning or heavy snow, and fault spread-out due to customer’s facilities. Among these faults, most of faults are temporary and the dominant fault type is ground-fault. For rapid fault detection and fault section isolation, blackout area minimization, many protection devices such as Recloser, Sectionalizer, and Line Fuse are adopted. Among these devices, Automatic Circuit Recloser is the most important protection device, whose main functions are fault current trip and auto-reclosing. One distribution line has over 2 Reclosers of serial connections or Recloser – Sectionalizer - Line Fuse of serial connections. This configuration is the concept of Primary Protection and Back-up Protection. In other words, protection coordination is required in the way that a protection device nearer to fault point operates first to eliminate the fault and other devices farther from fault point are configured to operate later with time delays.
1.2. FUNCTION OF AUTOMATIC CIRCUIT RECLOSER
When a fault occurs on the load side of Recloser installed location, Recloser detects fault current, trips fault current at high speed, and does reclosing actions after the set time to reactivate the faulted section. In case of temporary fault, the fault can be removed by itself according to high-speed trip and dead time before reclosing actions. But, in case of permanent fault, because fault current is still detected after trip and reclosing actions of pre-set counts, Recloser is locked out finally as opened. Recloser has the time delay element in protection function of its controller and can be freely configured for protection coordination with other protection devices.
1
1.3. MAIN FEATURES OF FTU-R200
Recloser body is connected serially to distribution line to operate open / close of the line, and Recloser Controller is in charge of measurements of currents, voltages, and other electric values, protection, control, status monitoring, recording, and communication. FTU-R200 is a kind of IED’s (Intelligent Electronic Device) for power system automation, which is a fully digitalized and microprocessor-based control device, and through connecting with this control device, Recloser can play a role of automated protection device. Main features of FTU-R200 are as follows, Measurements Magnitude and phase angle of voltages & currents(Fundamental frequency) Sequence components of 3-Phase voltages & currents True RMS, Harmonics and THD of voltages & currents Active, reactive and apparent power for each phase and 3-phase Energy(4-quadrant metering) Displacement Power Factor Frequency PQM, Fault, THD Counter Phase difference between source-side and load-side voltage
Control Manual Recloser Open/Close at local or remote(Select Before Operation) Interlocking(Gas low, Handle lock, Operator place, Sync Fail, Live Load) Battery Test External Trip and Close By contact input(Optional) Enable or disable reclosing, protection and Ground function
2
Protection 3-stage over current protection Fast and Delayed TC trip elements for phase and earth fault 54 types of built-in TC Curves and 4 Customized TC Curves Definite time over-current element Definite time HCT(High Current Trip) SEF(Sensitive Earth Fault) Detection Auto-Reclosing(up to 4 shots) Cold Load protection(Pickup Adjustment) Magnetizing Inrush Restraints Sequence Coordination Open Line Detection Phase Sync. Fail Detection Over Voltage, Under Voltage Under Frequency, Over frequency
Status Monitoring 10 Contact Inputs Recloser Open/Closed Mechanical Locked Gas Pressure Low External AC Power Loss Enclosure Door Open Etc. Battery Low or fail Battery charger fail Recloser, Protection, Ground Protection enabled Fault Indication Open Line Detection Over Voltage, Under Voltage, Under Frequency, Over Frequency
3
Event Recording Event recording with time-stamp I/O, Functional, System, Fault Current, Demand Current & Power, Daily Max Current & Power Waveform Recording 8 Fault Waveforms 6 PQM Waveforms 1 Manual Trigger Waveform 128 samples/cycle, 20 cycles Saving COMTRADE File Format
Counter FTU Restart count Switch Trip Count Fault Detection Count PQM Count THD Count
Communication Protocols DNP3.0 SCADA Port
DNP3.0 over TCP/IP IEC60870-5-101 IEC60870-5-104 (Unbalanced/Balanced)
4
Maintenance Port
Modbus-RTU
GSM/GPRS
Supports PPP connection, SMS
SNTP Client
Supported through TCP/IP port
2. TECHNICAL DATA 2.1. DIGITAL PROCESSOR 2.1.1. DUAL PROCESSOR ARCHITECTURE ü
32-bit RISC type micro-controller with on-chip flash program memory
ü
32-bit floating-point Digital Signal Processor
ü
HPI-Port Memory for communication between two processors
ü
Data Memory(SRAM)
ü
Non-volatile Memory(1Mbytes) for storing events and parameters
ü
Flash Memory for storing fault and PQM Waveforms
ü
Real Time Clock
2.1.2. ANALOG/DIGITAL CONVERSION ü
16-bit A/D Converter
ü
Sampling rate : 128 samples/cycle
ü
Anti-aliasing analog filter
ü
One gain channel for each current input : effective 16-bit resolution for current measurements
2.1.3. DSP ü
Correction of analog input error
ü
Fast Fourier Transform : phasor calculation
ü
Electric quantities calculation & Fault Decision
5
2.1.4. CPU ü
Status monitoring & Control Command
ü
Local Human-Machine Interface
ü
Event Recording
ü
Remote Communication(DNP3.0, IEC60870-5-101 and IEC60870-5-104)
ü
Self Diagnosis
2.1.5. FUNCTIONAL BLOCK DIAGRAM
Figure 2-1 Functional Block Diagram
6
2.2. ENVIRONMENTAL CONDITIONS
Altitude
< 2,000m
Wind Speed
< 40m/s
Ambıent Temporature
- 25 ~ +70°C, KSC 0220/1
Storage Temporature
- 40 ~ +85°C
Humidity
< 95%RH
Dielectric withstand
IEC 60255-5, 2kV
Impulse voltage
IEC 60255-5, 6kV for current input circuit IEC 60255-5, 4kV for voltage, power input & Contacts I/O
Insulation resistance
IEC 60255-5, >500MW (DC500V)
High frequency disturbance
IEC 61000-4-12 class 3 (2.5kV)
Fast transient noise
IEC61000-4-4 class 4 (4kV)
Radio frequency noise
IEC 61000-4-3 10V/m
Vibrations
IEC 60255-21-1 class 2
Mechanical Shock
IEC 60255-21-2 class 2
Enclosure protection
IP54
7
2.3. INPUTS/OUTPUTS
Binary Contacts Input : 10 Points DC 24V Biased in the control box Opto-isolation(Viso) : 2,000 Vrms Delay time setting(10~500ms) for each contact input to suppress bouncing Signal Recloser Open Recloser Closed Recloser Locked Gas Pressure Low External AC Power Fail Battery Discharged Control Box Door Open External Trip Command(Optional) External Closer Command(Optional) Spare
Binary Contacts Output : 6 Points Pulse width of output is variable Signal & Contact rating DC24V Aux. Relay Contact Contact Relay : Spare #1~#4 PhotoMOS Relay : Recloser Open, Close ü
Contact Relay Rating
Rated Current Rated Voltage/Max. Breaking Voltage AC Max. Breaking Capacity AC Make Current (Max. 4s at duty cycle 10%) Dielectric Strength Coil-Contacts Open Contact Circuit Mechanical Life Operate Time ü
5,000Vrms 1,000Vrms > 30 x 106 operations typical 7ms
PhotoMOS Relay Rating
Rated Load Current Rated Load Voltage I/O isolation Voltage
8
16A 250Vac/440Vac 4,000VA 30A
120mA 350Vac 1,500Vac
Current Input : 4 Channel 12.5A Maximum(external CT Ratio is 1,000:1 normally) Burden : below than 1VA 3-Phase Current and Neutral Currents Isolation by auxiliary CT of RTU(Viso) : 2,000 Vrms Surge Withstand Voltage : 6kV Signal : Ia, Ib, Ic, In
Voltage Input : 6 Channel 4Vrms at rated Phase Voltages Burden : below than 0.01VA Maximum input range : ~200% Isolation by auxiliary PT of RTU(Viso) : 2,000 Vrms Surge Withstand Voltage : 4kV Signal : Va, Vb, Vc, Vr, Vs, Vt
Power Supply Input DC 24V(DC20~DC29V) Power Consumption: Max. 15W
9
2.4. MEASUREMENT 2.4.1. CURRENT RMS(A) & Phase angle(°)
Ia, Ib, Ic, In
Sequence Component
I1, I2, I0
True RMS
Ia, Ib, Ic
Reading Range
2~12, 500A(External CT Ratio 1,000 : 1)
Accuracy
2~600A
±1% or ±1A
600~12,000A
±3%
2.4.2. VOLTAGE RMS(kV) & Phase angle(°)
Va, Vb, Vc, Vr, Vs, Vt
Sequence Component
V1s, V2s, V0S, V1L, V2L, V0L,
True RMS
Va, Vb, Vc, Vr, Vs, Vt
Phase Angle Difference(°)
∠Va - ∠Vr
Reading Range
0.1~40kV
Accuracy
±1% or ±0.1kV
2.4.3. POWER
10
Active Power(kW)
A-Phase, B-Phase, C-Phase, 3-Phase Total
Reactive Power(kVAR)
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Apparent Power(kVA)
A-Phase, B-Phase, C-Phase, 3-Phase Total
Reading Range
-32767~32767
Accuracy
±2%
2.4.4. POWER FACTOR A-Phase, B-Phase, C-Phase, 3-Phase Total Lead/Lag Display Reading Range
0~1.0
Accuracy
±4%
2.4.5. FREQUENCY Reading Range
45 ~ 55Hz (System Frequency : 50Hz) 55 ~ 65Hz (System Frequency : 60Hz)
Accuracy
±0.02Hz
2.4.6. ENERGY Positive kWh
A-Phase, B-Phase, C-Phase, 3-Phase Total
Negative kWh
A-Phase, B-Phase, C-Phase, 3-Phase Total
Capacitive Positive kVARh
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Capacitive Negative kVARh
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Inductive Positive kVARh
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Inductive Negative kVARh
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Reading Range
0~65535(Rollover)
Accuracy
±4%
2.4.7. HARMONIC Total Harmonic Distortion (%)
3-Phase Current THD (Ia, Ib, Ic, I3ph) Source side 3-Phase Voltage THD (Va, Vb, Vc, V3ph)
2nd~31st Harmonic RMS(A, kV)
Ia, Ib, Ic, In, Va, Vb, Vc
11
2.4.8. DEMAND CURRENT AND POWER Configurable Demand Interval
5, 10, 15min (Default 15min)
RMS(A), Active Power(kW), Reactive Power(kVAR)
Ia, Ib, Ic, In, Pa, Pb, Pc, P3ph, Qa, Qb, Qc, Q3ph
Daily Max Current and Power are Stored
12
2.5. COMMUNICATION 2.5.1. PHYSICAL LAYER 2.5.1.1. RS232C (2 ND PORT FROM TOP OF RTU) 9-Pin Male Connector
DCD(1), Rx(2), Tx(3), DTR(4), GND(5) DSR(6), RTS(7), CTS(8), NC(9)
Speed(Baud Rate)
1200, 2400, 4800, 9600, 19200 BPS
Supports Modem Control
CTS, DCD Signal Timeout Configurable RTS Off-delay Configurable
Optical Isolation ESD, Transient Noise Protection
2.5.1.2. RS232C/RS485 (1 ST PORT FROM TOP OF RTU) RS232C Signals
Rx(2), Tx(3), GND(5), RTS(7), CTS(8), MODE(4) To use RS232C, MODE pin shall be connected to GND externally.
RS485 Signals
DATA-(3) DATA+(7)
Speed(Baud Rate)
1200, 2400, 4800, 9600, 19200 BPS
Optical Isolation ESD, Transient Noise Protection
2.5.1.3. TCP/IP Ethernet Port
10/100 Base-T
2.5.1.4. CAN (CODE AREA NETWOK) Dedicated channel for the communication between RTU and power supply board with battery charger.
13
2.5.2. PROTOCOL FOR SCADA 2.5.2.1. DNP3.0 ①
Support DNP3.0 Subset Level 3
②
Class of each point is settable(Using DNP3.0 Index Configuration Tool)
③
Supports multi-frame transmission (multi-frame interval is configurable)
④
Enable/Disable unsolicited message class
⑤
Supports file transfer function for uploading fault waveform and local event history
⑥
Non-transmitted events are stored on non-volatile memory during communication fail
⑦
Event buffer size : Binary Input(255), Analog Input(128), Counter(128)
⑧
Supports direct operate or select before operate(SBO) for control output
⑨
Supports report by exception for updating analog values
⑩
Protocol frame monitor was built in FTU
⑪
Event transmission by dial-up can be enabled in GSM environment.
2.5.2.2. IEC60870-5-101 ①
Address size (Link address, common address) is configurable.
②
Two time tag formats are selectable. :24-bit or 56-bit
③
Single character for NACK is supported.
④
Cyclic update of measurements data is supported.
⑤
Class assignable for each object type. ( single point, double points, measured point)
⑥
Supports report by exception for updating analog values
2.5.2.3. IEC60870-5-104
IEC 60870-5-104 (also known as IEC 870-5-104) is an international standard, released in 2000 by the IEC (International Electrotechnical Commission). As can be seen from the standard's full designation 'Network access for IEC 60870-5-101 using standard transport profiles', its application layer is based on IEC 60870-5-101. IEC 60870-5-104 enables communication between control station and substation via a standard TCP/IP network. The TCP protocol is used for connection-oriented secure data transmission.
2.5.2.4. MODBUS RTU SERIAL/TCP ①
Modbus RTU protocol can be selected for communicating with SCADA
②
Modbus TCP can be selected in the Ethernet port.
14
2.6. RECORDING 2.6.1. EVENT RECORDER
This function is used to verify shortly the operated history or log of FTU in normal operation and fault situation. Event recording is triggered by power reset, set value change, operation of protection functions, system error or self-diagnosis, etc., and events can be stored including event occurred time, measured values of current/voltage and operation description. And, this recording function follows the FIFO (First In First Out) rule. Stored events can be uploaded to and listed on FTU PC S/W (FTUMan) through RS232C port on front panel. Event List
Sub Items
Max.
I/O Events
Status change of binary Input/Output
1023
Function Events
Operated status of Protection Function
30000
System Events
Setting change, Reset, Self Diagnosis
255
Fault I Events
Latest fault current, phase and time
255
PQM Events
Operated status of PQM Function
255
Demand I,P,Q Events
Each phase daily average load current, active power and reactive power with time
6143
Max. I,P,Q Events
Each phase daily Peak load current, active power and reactive power with time
1023
2.6.2. WAVEFORM EVENT RECORDER
Fault & PQM waveforms recording function are used to store the measured instantaneous current/voltage values of pre-fault and post-fault at 128 samples per cycle. Record length, trigger source and trigger position of pre/post-fault in recorded data are adjustable. The record types are 128 samples * 20 cycles, 64 samples * 40 cycles, 32 samples * 80 cycles, 16 samples * 160 cycles. According to the purpose, operators can set the fault recording trigger source and trigger position of pre-fault/post-fault. Trigger position means the percentage position in recorded fault data, and the pre-fault data are recorded before this point and rest of the data are recorded as the post-fault after this point. The recorded fault waveforms are also uploaded to FTU PC S/W, and current/voltage waveforms at fault and protection elements operation can be analyzed with fault evaluation. This waveform recording function follows the COMTRADE file format rule.
15
3. CONSTRUCT AND EXTERNAL CONNECTION 3.1. APPEARANCE & DIMENSION
Front panel of FTU-R200 has an operational LCD display, a RS232C port for setting and maintenance, indicating LED’s, and push buttons. The arrangement of LEDs and buttons on the front panel of delivered product may be different from the following picture due to customizing for special requirements of user.
Figure 3-1 Front Panel Drawing of FTU
16
The following is the Top-view of FTU-R200 panel.
Figure 3-2 Top View of FTU Panel
The next drawing is Side-view of FTU-R200 panel, and there are measurement module connector, control module connector, monitoring module connector, power connectors, and RS232 port for SCADA communication on the right side of FTU panel.
Figure 3-3 Side View of FTU Panel
17
3.2. CONNECTOR
On the right side of FTU-R200 panel, there are RS232 communication port to SCADA, control source power connector, DI (Status Monitoring) connector, DO (Control) connector, AI (Measurement) connectors for Voltage, Current from top to bottom, TCP/IP connector, CAN connector, and TD connector. RS232C port is DB9 male-type connector.
Figure 3-4 Pin Connectors on the Right Side of FTU-R200
18
Figure 3-5 Pin Connectors on the Right Side of FTU-R200c
19
4. FRONT PANEL OPERATIONS
On the front panel, there are LED’s indicating Recloser’s status, function buttons and LED’s, control buttons and LED’s, LCD & Menu buttons and a RS232C port for maintenance.
2 1 4 3
5
6
7
8
9 10
11
Figure 4-1 Front Panel Sheet of FTU-R200
20
4.1. BUTTON & LED DESCRIPTION 4.1.1. LCD DISPLAY
4 lines * 20 characters LCD is used and through MENU/UP/DOWN/ENTER buttons, operators can survey all data and current set values.
4.1.2. FTU STATUS
These LED’s indicate status of FTU-R200. CPU Run
Normal operation of FTU(CPU OK)
System Error
Self-diagnosis Error & Switch Status Trouble
Ext.Power
External AC Power is supplied
Battery Fail
Battery voltage is low (discharged)
4.1.3. MENU/UP/DOWN/ENTER BUTTONS
These buttons are used to operate FTU in local position. Refer to LCD Manipulation section for detailed methods.
4.1.4. SERIAL PORT
Engineering tool on PC is connected to this port for maintenance and upgrade. RS232C port for maintenance is DB9 female-type connector. RS232C
Rx(2), Tx(3), GND(5), MODE(9)
4.1.5. ETHERNET/SCADA/PROTECTION COMMUNICATION LED
These LED’s indicate status of FTU-R200. Ethernet Link
Ethernet Linking
Ethernet Act
Ethernet Active
SCADA Rx
Communication data are received 21
SCADA Tx
Transmitting communication data
SCADA RTS
Data transmission request
Protection Rx
Communication data are received from another FTU through RS232C/485 port. (optional function)
Protection Tx
Transmitting communication data to another FTU through RS232C/485 port. (optional function)
4.1.6. BATTERY TEST & LAMP TEST
To test the battery and charger circuit, push ‘BATTERY TEST’ button. When the test result is fail, we will see turn on Battery Fail LED. To test the LED, push ‘LAMP TEST’ button. When test is OK, all of the LEDs are turn on for a while. 4.1.7. RESET BUTTON
This button is used for Annunciator LED Reset (LED turn off). Annunciator LED represents all the LED’s related to Protection, Reclosing and Self-diagnosis Error. 4.1.8. FUNCTION LED
LIVE LINE LEDs indicate if the lines to source side and load side are energized or deenergized. LEDs are lit on, when the line voltage goes up the set ‘Voltage ON Level’ and LEDs are lit off, when the voltage goes down the set ‘Voltage OFF Level’. Under Voltage LEDs indicate if under voltage function operated. Sync.Fail LED is lit on when the sync. failure function operates. The function operates when the phase angle difference between source-side voltage (Va) and load-side voltage (Vr) is over the setting value and is sustained during set detection time. This status can be used for the interlock condition of close operation by configuration. Fault (Passage) Indicator LEDs are lit on when a fault passes through the Recloser and line is deenergized by backup protection equipment or recloser trips the line. Depending on the faulted phase, indicators A, B, C, N, SEF will be lit on. Reclose Ready LED “On” represents that recloser is closed and reclosing action is ready. Reclose Progress LED is lit on when reclosing sequence is in progress. Reclose Lockout LED is lit on when recloser goes to lockout with open.
22
4.1.9. RECLOSE/PROTECTION/GROUND ENABLE BUTTONS AND LEDS
Push the enable buttons and makes the respective LEDs on to fulfill the Reclosing and Protection functions. These buttons are toggled between Enable and Disable. RECLOSE ENABLED button enables or disables the Reclosing Function. In disable mode, the Recloser is locked out right after the 1st trip. PROTECTION ENABLED button enables or disables Phase Fault Detection and Earth Fault Detection Functions, simultaneously. GROUND ENABLED button enables or disables Earth Fault Detection Function only. 4.1.10. REMOTE/HOT LINE TAG BUTTONS AND LEDS
To decide the control position to Remote, push REMOTE button and make the LED on. This button and LED are also toggled between Remote and Local position. But, the manipulation of this button is possible only in the local for operator’s safety. The HOT LINE TAG button enables or disables the Recloser switching operation. If HOT LINE TAG LED is on, Recloser switching operation and auto-reclosing will be prohibited and only tripping by protection is allowed 4.1.11. SELECT/OPEN/CLOSE BUTTONS AND LEDS
These buttons are used to control (OPEN/CLOSE) the Recloser locally. Before local control command, check first if the control position is LOCAL. SELECT button is a twophase safety & confirmation check mechanism, and this concept is similar to SBO (Select Before Operate) in communication protocol. To manually and locally control the Recloser, SELECT button should be pushed down to make the corresponding LED on first. Selected status by SELECT button is sustained until Close or Open command is issued or SBO time elapses.
23
4.2. LCD MANIPULATION
MENU/UP/DOWN/ENTER buttons are used to manipulate the LCD. The following table explains the common roles of 4 buttons. Button MENU
Description ü To toggle between Main Menu Display from Initial Display ü To come back to Parent Menu from Child Menu ü Be careful, because all the set value changes are canceled when this button is pushed down during the change of set values
ENTER
ü To select and enter into each menu item ü To enter the changed set value and configuration ü After entering the changed set value, this button again goes out from each item to menu tree. (Toggle between menu tree and each menu item) ü After changing the set values, be sure to save the changed values in the Set Value Change Save Menu.
UP
ü To move up the cursor in the menu tree ü To increment the set values ü The set values are rolled up and UP button at the highest value goes to the lowest value
DOWN
ü To move down the cursor in the menu tree ü To decrement the set values ü The set values are rolled down and DOWN button at the lowest value goes to the highest value
24
4.2.1. LCD MENU
Figure 4-2 LCD Menu Tree Diagram of FTU-R200
* Actual display messages may differ from those described here.
25
4.2.1.1. INITIAL DISPLAY
[Initial Display] shows up the reclosing status. < R/ C f o r DAS > S e que nc e : 0 [ HO] R/ C S t a t us : CL OS E [ HOME ] Figure 4-3 Initial Display
MENU button at [Initial Display] goes to [Main Menu Display]. MENU button toggles between [Initial Display] and [Main Menu Display]. UP or DOWN button at [Initial Display] goes to [Current / Voltage Measurement Display]. UP / DOWN button toggles between [Initial Display] and [Current / Voltage Measurement Display]. I I I I
a b c n
: : : :
0 0 0 0
0 0 0 0
0 0 0 0
0 0 0 0
0 0 0 0
A A A A
0 0 0
Figure 4-4 Current / Voltage Measurement Display
26
Reclosing Sequence
0, 1, 2, 3 and 4
Total Reclosing Shot 3 Times
0[HO], 1~3[SR], 4[LO] ü
HO
Home
ü
SR
Sequence Running
ü
LO
Lockout
R/C Status
CLOSE/OPEN/TROUBLE (No Status Input)
Current (Ia,Ib,Ic,In)
Each Phase Instantaneous Current Value (unit : A)
Voltage (ABC.RST)
Source Side Voltage (Va,Vb,Vc) / Load Side Voltage (Vr,Vs,Vt), (unit : kV)
4.2.1.2. MAIN MENU DISPLAY [ 1 2 3 4
MA . F . C . D . E
I u o i v
N n n s e
c f p n
ME t i i g l a t
NU on ur a y L i s
] S et t i ng t i o n t
Figure 4-5 Main Menu Display
[Main Menu Display] shows up 4 main menu items. And UP & DOWN buttons move up and down the main menu trees. ‘>’ symbol indicates the cursor position and ENTER button enters into the selected main menu’s sub items. Main Menus
Sub Items
Function Setting
Group1, Group2, Group3, Group4, Group Setting, Group Copy
Configuration
I/O, Communication, Event, Time
Display
Measurements, Status, Counter
Event List
I/O events, Function events, System events, Fault I events, Demand I events, Demand P events, Demand Q events, Max. I events, Max. P events, Max. Q events
4.2.1.3. FUNCTION SETTING [ 1 2 3 4 5 6
S . . . . . .
et Gr Gr Gr Gr Gr Gr
t o o o o o o
i u u u u u u
n p p p p p p
g 1 2 3 4
Me n u ]
S e t t i ng Co py
Figure 4-6 Function Setting
In Function Setting, there are 4 different setting groups and the different setting values can be stored individually in 4 different setting groups. After finishing the set value change, when MENU button is pushed to return to [Main Menu Display], [Set Value Change Save Display] shows up to determine Yes or No. If selecting yes and pushing ENTER button, the changed set values are all saved. However, if selecting No and ENTER button or MENU button again, the changed set values are not saved and the existing set values are still applied.
27
ü CAUTION: Be careful not to push down MENU buttons repeatedly! Then, the newly changed set values are neither saved nor applied.
S a v e
Cha ng e d S e t Ye s / No
?
Figure 4-7 Set Value Change Save Display
S e t t i ng
S a v i ng !
Figure 4-8 ENTER to Yes [ MA > 1. F u 2. Co 3. Di
I n n s
N ME N U ] c t i o n S e t t i ng f i g ur a t i o n pl a y
Figure 4-9 ENTER to No
4.2.1.4. CONFIGURATION [ 1 2 3 4
C . . . .
ON F I G ME N U ] I / O C o mmu n i c a t i o n Ev e nt T i me Figure 4-10 Configuration
Configuration menu has the setting items for communication, I/O, and system configuration. Setting items are I/O, Communication, Event and Time. After finishing the set value change, when MENU button is pushed to return to [Main Menu Display], [Set Value Change Save Display] shows up to determine Yes or No. If selecting yes and pushing ENTER button, the changed set values are all saved. However, if selecting No and ENTER button or MENU button again, the changed set values are not saved and the existing set values are still applied. ü CAUTION: Be careful not to push down MENU buttons repeatedly! Then, the newly changed set values are neither saved nor applied. 28
4.2.1.5. DISPLAY [ DI 1 . Me 2. S t 3. Co
S a a u
P s t n
L u u t
A Y ME N U r e me n t s s e r
]
Figure 4-11 Display
In Display menu, measurement values, monitored status, and counter values are displayed. 4.2.1.6. EVENT LIST [ E 1 . 2 . 3 . 4 . 5 . 6 . 7 . 8 . 9 . 10 .
VE I / Fu S y Fa De De De Ma Ma Ma
NT O nc s t ul ma ma ma x . x . x .
L I S T E v e nt t e i o n e m e v t s e v nd I nd P nd Q I e v P e v Q e v
] s e e e e e e e e e
v n n v v v n n n
e t t e e e t t t
n s s n n n s s s
t s
t s t s t s
Figure 4-12 Event List
In Event List menu, all types of events are displayed with occurred time and event description. Using UP & DOWN buttons, event list can be scrolled up and down in the LCD display. Event List
Sub Items
Max.
I/O Events
Status change of binary Input/Output
1023
Function Events
Operated status of Protection Function
30000
System Events
Setting change, Reset, Self Diagnosis
255
Fault I Events
Latest fault current, phase and time
255
Demand I,P,Q Events
Each phase daily average load current, active power and reactive power with time
6143
Max. I,P,Q Events
Each phase daily Peak load current, active power and reactive power with time
1023
29
5. PROTECTION FUNCTIONS 5.1. FAULT DETECTION
FTU detects phase and earth fault and trip the breaker. The fastest operation time is within 45msec including auto-recloser operating time. There are 58 trip curves, which can be selected for fast and delayed operation respectively. The curve can be edited by using several parameters, i.e. time multiplier, time adder and minimum response time. The operating count of fast and delay element can be adjusted by other parameters. Earth fault detection function can be enabled or disabled also by toggling ‘Ground Protection Enable’ button. Phase Fault
Earth Fault
Step
Unit
1
A
Range
Def.
Range
Def.
Pickup Current
10~1500
400
2~1500
60
2nd Harmonic Block
NO/YES
YES
NO/YES
YES
Fault Trip Direction
OFF/FWD/REV
OFF
OFF/FWD/REV
OFF
1~58
1-A
1~58
20-1
1
Time Multiplier
0.05~2.00
1.00
0.05~2.00
1.00
0.01
sec
Time Adder
0.00~1.00
0.00
0.00~1.00
0.00
0.01
sec
Min. Response Time
0.00~1.00
0.00
0.00~1.00
0.00
0.01
sec
RDMT/RIDMT
RDMT
RDMT/RIDMT
Fast Operation Time Curve Type
Reset Type
RDMT RDMT(Definite Time) RIDMT(Inverse Time)
Reset Definite Time
30
0.00~10.00
0.00
0.00~10.00
0.00
0.01
sec
Phase Fault
Earth Fault
Step
Unit
Range
Def.
Range
Def.
1~58
2-B
1~58
21-2
1
Time Multiplier
0.05~2.00
1.00
0.05~2.00
1.00
0.01
sec
Time Adder
0.00~1.00
0.00
0.00~1.00
0.00
0.01
sec
Min. Response Time
0.00~1.00
0.00
0.00~1.00
0.00
0.01
sec
RDMT/RIDMT
RDMT
RDMT/RIDMT
Delayed Operation Time Curve Type
Reset Type
RDMT RDMT(Definite Time) RIDMT(Inverse Time)
Reset Definite Time
5.1.1.
0.00~10.00
0.00
0.00~10.00
0.00
0.01
sec
Definite Time Protection
Definite time element is an alternative to inverse time protection. It works by tripping the recloser at a fixed time after pick-up. The combination of inverse curve and definte time element makes the protection coordination easier. The definite time element follows the same reclosing sequence with the inverse time element. Range
Def.
Step
Unit
OFF/ON
OFF
Pickup Current
50~10000
1000
1
A
Detection Time
0.00~1.00
0.00
0.01
sec
OFF/ON
OFF
Pickup Current
50~10000
1000
1
A
Detection Time
0.00~1.00
0.00
0.01
sec
Comment
Phase Detection Active
Earth Detection Active
31
5.1.2. High Current Trip (HCT)
HCT can be configured up to 4 times for phase fault and earth fault, respectively. Range
Def.
Step
Unit
0~5
0
1
Pickup Current
100~1500
500
1
%
Detection Time
0.00~1.00
0.00
0.01
sec
0~5
0
1
Pickup Current
100~1500
1500
1
%
Detection Time
0.00~1.00
0.00
0.01
sec
Comment
Phase Detection Operation Count
‘0' means disable.
Earth Detection Operation Count
‘0' means disable.
5.1.3. Single Shot Operation
Single shot operation is used to provide an appropriate protection when non-reclosing operation such as closing onto a fault is required. In single shot operation the controller goes directly to lockout after a trip and will not reclose.
Single Shot Time
32
Range
Def.
Step
Unit
0~180
10
1
sec
Comment
5.1.4. TC Curve
FTU-R200 has 54 types of built-in TC curves including ANSI, IEC Standard curves. And customer can define additional 4 curves as his own curves by using PC Software. Basically, built-in curves have inverse time characteristics, but can be easily adjusted by three parameters such as multiplier, time adder and minimum response time. In engineering step, the selection and adjustments of TC curves shall be done for the protection coordination with other protection devices in the feeder. The following parameters are related to change and editing of TC curve’s characteristics. ü Time Multiplier ü Time Adder ü Minimum Response Time Time Multiplier is multiplied to the operating time of basic curve (TDM=1.0), then Time Adder is added to the resulting operating time of the curve adjusted by multiplier. Minimum Response Time defines the fastest operating time of the curve. The following tables describe the built-in TC Curve Type and the corresponding numbers in the setting. TC Curve graphs are shown in the appendix. Setting No.
1
2
3
4
5
6
7
8
9
10
Curve
A
B
C
D
E
EI
KP
L
M
N
Setting No.
11
12
13
14
15
16
17
18
19
20
Curve
NI
P
R
T
V
VI
W
Y
Z
1
Setting No.
21
22
23
24
25
26
27
28
29
30
Curve
2
3
4
5
6
7
8
8*
9
11
Setting No.
31
32
33
34
35
36
37
38
39
40
Curve
13
14
15
16
18
N1
N2
N3
N4
F
Setting No.
41
42
43
44
45
46
47
48
49
50
Curve
G
H
J
LI
8+
17
KG
A*
SI
IM
Setting No.
51
52
53
54
55
56
57
58
Curve
IV
IE
U8
U2
C1
C2
C3
C4
33
Curve Type
Curve Name
Recloser Curves
A,A*,B,C,D,E,F,G,H,J,KP,KG,L,M,N,P,R,T,V,W,Y,Z, 1,2,3,4,5,6,7,8,8*,8+,9,11,13,14,15,16,17,18
IEC Standard Curve
Standard Inverse(NI),Very Inverse(VI),Extremely Inverse(EI) Long-time Inverse(LI),Short-time Inverse(SI)
ANSI/IEEE Standard Curve
Moderately Inverse(IM),Very Inverse(IV),Extremely Inverse(IE), Long-time Inverse(U8),Short-time Inverse(U2)
KEPCO Standard Curve
N1,N2,N3,N4
User Customized Curve
C1,C2,C3,C4
ü IEC, ANSI/IEEE, US STANDARD TC CURVE EQUATION T = TDM · {a / (Mb - 1) +g} TRESET = TDM · {t / (Mb - 1)} T : Operate Time, TDM : Multiplier Setting, TRESET : Reset Time
Curve Type
Standard
α
β
γ
τ
Standard Inverse(NI)
IEC
0.14
0.02
-
-
Very Inverse(VI)
13.5
1
-
-
Extremely Inverse(EI)
80.0
2
-
-
Short-time Inverse(SI)
0.05
0.04
-
-
Long-time Inverse(LI)
120
1
-
-
19.61
2
0.491
21.6
Extremely Inverse(IE)
28.2
2
0.1215
29.1
Moderately Inverse(IM)
0.0515
0.02
0.114
4.85
Very Inverse(IV)
IEEE
Short-time Inverse(U2)
CO2
0.2394
0.02
0.01694
2.261
Long-time Inverse(U8)
CO8
5.95
2
0.18
5.95
34
5.1.5. EXAMPLE OF TC CURVE EDITING
3-parameters are applied in the following order. The values below are examples. ü Time Multiplier : 1.5 ü Time Adder : 0.03 ü Minimum Response Time : 0.1 In the next figure, for example, the curve A is the basic curve. Assume the operating time of the basic curve (A) at 16 times pickup current is 0.04 sec. When applying Time Multiplier, curve ‘A’ changes its shape, that is, the curve becomes less steep in time axis and operation time becomes longer by a multiplier at the same current value like ‘B’ in the figure. The operating time at 16 times pickup becomes 0.06 sec. Then Time Adder shall be applied. The operating time of the resulting curve ‘C’ is 0.09sec. Finally Minimum Response Time cuts the curve part, which is shorter than this time. Then the actual operating time of the example at 16 times becomes 0.1sec.
Figure 5-1 TC Curve Editing Example 1
35
There are two additional definite time over-current elements in the controller. The next figure shows 3-stage over-current protection characteristics. The third stage is prepared for instantaneous protection. Therefore the harmonic restraint is not applied to third stage elements, but the second stage definite time over-current element.
Figure 5-2 TC Curve Editing Example 2
36
5.1.6. AUTO RECLOSING SEQUENCE
The FTU-R200 supports 3-shot reclosing with sequence coordination. For Permanent fault, under the condition of reclosing enabled, no other restraints such as cold-load, inrush and no High Current Trip, recloser will be locked out to open the Reclosing Count repeating trip and reclose according to the preset settings. Range
Def.
Step
Unit
Operation Count
1~5
4
1
Instantaneous Count
0~5
2
1
Operation Count
1~5
4
1
Instantaneous Count
0~5
2
1
Reclose Interval 1st
0.5~180.0
0.6
0.1
sec
Reclose Interval 2nd
1~180
2
1
sec
Reclose Interval 3rd
1~180
15
1
sec
Reclose Interval 4th
1~180
15
1
sec
Reset Time
3~300
30
1
sec
1~5
4
1
Reclose Interval 1st
0.5~180.0
0.6
0.1
sec
Reclose Interval 2nd
1~180
2
1
sec
Reclose Interval 3rd
1~180
15
1
sec
Reclose Interval 4th
1~180
15
1
sec
Reset Time
3~300
30
1
sec
Comment
Phase
Earth
Phase/ Earth Reclosing
SEF Reclosing Operation Count
37
For example in the below figure, the reclosing sequence is organized in 2F2D, which means the Recloser protection function operates as Instantaneous(Fast) element during first 2 reclosing shots and operates as Time-Delayed element during last 2 reclosing shots. This composition also can be configured.
Figure 5-3 Permanent Fault: 3 shot Reclosing & 2F2D
For temporary fault, if the fault is removed before the preset Reclosing Count and no fault is detected during the preset Reset Time, then the reclosing sequence is initialized to normal operation standby mode. When a fault is detected again during the Reset Time, the Recloser will be locked out after the remaining reclosing counts excluding the previously operated reclosing counts.
Figure 5-4 Temporary Faults: Fault Removal during 1st Reclosing Interval
38
5.1.7. SEQUENCE COORDINATION
Recloser can be equipped with two types of TC trip curves depending on reclosing shot. The curves are called as fast and delay element and can be set separately with different kinds of curves. For example, if the total operation count is set to 4 and fast operation count is set to 2, recloser trips two times by fast element curve first and trips by delay element before lockout. The setting is normally called as “2F2D”. Sequence coordination function can be used in the case which more than one recloser is used in series in the same distribution line. The purpose of the function is to synchronize to use the fast and delay element for recloser in series during reclosing sequence. For explanation, assume that two reclosers are installed in the line as the following picture.
Figure 5-5 2 reclosers are installed in the line
When a fault is occurred in the load-side of recloser B, the fast element of A and B sees the fault simultaneously. But normally B trips first before A reaches the trip point according to TC curve setting based on the time coordination between A and B. After B trips the fault, B waits dead time and prepare 2nd trip element (fast element also for 2nd trip in this case) before first reclosing. In this situation, A also detects the fault. But A didn’t trip the line. Instead of tripping, A detected the de-energized line before tripping. In this case B also prepares the protection element as the 2nd trip element (fast element). If the fault is sustained, the same sequence is repeated. So A and B goes to the 3rd trip element (delay element) together. The third tripping can be done by B if the delay elements of A and B are coordinated. If the sequence coordination of A is not enabled, A will trip by fast element before B trips by delay element because the fast element is set faster than the delay element normally. That’s not desired situation. In conclusion, the sequence coordination function is that source-side recloser monitors load-side reclosing sequence and follows the same protection element as load-side recloser.
Seq. Coordination Active
Range
Def.
OFF/ON
OFF
Step
Unit
Comment
39
5.2. COLD LOAD PICKUP
Cold Load Pickup is the function which allows load current larger than the pickup value of inverse-time overcurrent protection to be carried on without fault detection during set interval. It’s achieved by adjusting the pickup value with the multiplier during the interval. This function is useful to avoid unwanted trip of the line in which loads with big starting current like arc furnace are connected. This function is enabled when the line is energized only after recloser lockout or outage more than 180sec. After coldload time, the coldload function is completed. If the measured current is larger than the multiples of pickup, FTU regards the situation as an actual fault. In that case trip and reclosing sequence is same as normal operation. During reclosing sequence before lockout, coldload pickup is not any more applied. I
Pickup * X (multiplier)
Pickup Line current
t
Coldload duration
5-6 Example of Cold Load sequence
The setting parameters of Coldload pickup function is as the following. Range
Def.
Step
Pickup Multiplier
1~10
2
1
Duration
0~180
0
1
Pickup Multiplier
1~10
2
1
Duration
0~180
0
1
Unit
Phase Detection
min
Earth Detection
40
min
Comment
5.3. INRUSH RESTRAINT
Inrush Restraint is to prevent mis-operation of fault detection elements due to inrush current at the situation of energization of the line. Inrush current may be caused by magnetizing of transformers on the line and charging current of capacitors. Inrush restraint can be achieved by two methods. Inrush multiplier and time can be applied to restrain the operation of fault detection at the time of closing (manual or automatic) or energizing of the line. The current larger than the multiplier during the inrush time is regarded as a fault. So normal tripping and reclosing is performed. Alternative method is 2nd harmonic current based restraint. Inrush situation is determined by monitoring by 2nd harmonic components in the current. When transformers in the line are energized, magnetizing causes inrush current. The current involves large 2nd harmonic current relatively. So to distinguish inrush situation from fault while the current flows larger than the pickup value, the percentage of 2nd harmonics current to fundamental frequency current can be used. The restraint by multiplier is applied to inverse time overcurrent element and the restraint by 2nd harmonic is applied to inverse time overcurrent and definite time element, not to high current element. The setting parameters of Inrush restraint function is as the following. Range
Def.
Step
Unit
1~10
2
1
0~30.00
0.20
0.01
1~10
2
1
0~30.00
0.20
0.01
sec
Range
Def.
Step
Unit
5~50
20
1
%
Detection Time
0.02~1.00
0.02
0.01
sec
Function In Use
OFF/ON
ON
Comment
Phase Detection Pickup Multiplier Duration
sec
Earth Detection Pickup Multiplier Duration
2nd Harmonic
Comment
41
5.4. SENSITIVE EARTH FAULT (SEF) DETECTION
On the non-grounded network, it is hard to detect fault current because ground current of non-grounded network is much low. Therefore, FTU-R200 is designed to measure zerosequence values from either external core Balanced Current Transformer (or ZCT) or Residual Connection of 3 Phase Current Transformers to detect earth fault in the nongrounded network. This function is generally called SEF detection. In case of earth fault in the non-grounded network, since very small fault current due to line capacitance component flows into the fault point from both sides, SEF detection also considers the fault direction even in the radial network. Maximum Torque Angle is for setting the phase difference between zero-sequence voltage and zero-sequence current, and the protection zone is between -90° and +90° on the basis of Maximum Torque Angle. And it can be used for alarm or Trip.
Figure 5-7 Phase Diagram of SEF Range
Def.
Step
Unit
0.1~20
5.0
0.1
A
Pickup Voltage(-3V0)
0~80
30
1
%
Max. Torque Angle
0~345
90
15
Degree
0.1~30.0
1.0
0.1
sec
0.00~10.00
0.00
0.01
sec
NO/YES
YES
OFF/ALARM/TRIP
OFF
Pickup Current(3I0)
Detection Time Reset Time 2nd Harmonic Block Function In Use
42
Comment
0: Current Element ONly
The following picture describes fault current flows and phasor diagram in faulted section and un-faulted section of ungrounded distribution lines. The zero sequence current direction in faulted section is opposite to the current in un-faulted section. So the direction of zero sequence current compared to zero sequence voltage can be used to discriminate fault direction. Like the following diagram, the maximum torque angle 90o is normally used for detection of earth fault in ungrounded network. Va(0o)
3Vo
Va(0o)
Va’
3Vo
Va’
Faulted Feeder Section
Unfaulted Feeder Section
Vc(120o) Vc(120o)
Vb(240o)
Vc’
Io (CLR)
Vb(240o) Vc’
Vb’
Vb’
Io (No CLR, Multi-feeder) Io=0 (No CLR, Single Feeder) Max. Torque Angle (90o) -Vo
-Vo Operating Zone
Y-D
Max. Torque Angle (90o) Operating Zone
G/S
G/S
G/S
G/S
Figure 5-8 Diagram for earth fault in ungrounded network
In ungrounded system, core balance CT shall be used to measure small earth fault current. This function may be overriden or duplicate by earth fault detection function with directional element enabled in grounded network.
43
5.5. DIRECTION DETECTION
Direction detection is to restrict fault indication only on faults to a designated side of the Recloser. By using this function, the fault indication can respond only to fault currents from main source, not from dispersed sources in consumer area of the distribution line. As a result, the faulted section in the line can be discriminated precisely. Positive sequence voltage and current are used to detect the direction of phase fault. And zero sequence voltage and current are used to detect the direction of ground fault. The following picture describes the angular relationship between sequence voltage and current. The final decision of direction is from the combination of two elements. Thresholds are used to avoid to get wrong direction due to small sequence values.
Figure 5-9 Angular relationship between sequence voltage and current Range
Def.
Step
Unit
3V1 Threshold
0~100
20
1
%
3I1 Threshold
0~100
20
1
%
3I1 Max. Torque Angle
0~355
300
5
Degree
-3V0 Threshold
0~100
20
1
%
3I0 Threshold
0~100
20
1
%
3I0 Max. Torque Angle
0~355
330
5
Degree
44
Comment
The following picture shows the phasor diagram of 3 phase voltages and currents of single-phase earth fault situation in grounded network. In the example, the zero sequence current (3Io) is produced dominantly by A-phase fault current. It shows the maximum torque angle 330o is proper to decide the fault direction. Positive sequence voltage (V1) and current (I1) are used for phase-to-phase fault with same principle as -3Vo and 3Io.
Figure 5-10 Phasor diagram for single-phase earth fault in grounded system
5.6. NEGATIVE PHASE SEQUENCE (NPS) DETECTION
Negative Phase Sequence detection is an additional over current element and allows more reliable detection of unbalanced load condition such as broken conductor.
I2 / I1Pickup Level Detection Time I1 Threshold 2nd Harmonic Block Function In Use
Range
Def.
Step
Unit
30~100
80
1
%
0.10~300.00
10.00
0.01
sec
5~100
10
1
A
NO/YES
YES
OFF/ARAMP/TRIP
OFF
Comment
45
5.7. OPEN LINE DETECTION (LOSS OF PHASE)
Open line can be detected by under voltage characteristics. When the voltage on one or two phases drops below the ‘Volt OFF Level’ setting, the ‘Delay Time’ starts running. If the voltage on those phases stays below ‘Volt OFF Level’ setting until the ‘Delay Time’ timer expires, the Loss of Phase will be detected. If the voltage on detected phase rises to the ‘Volt ON Level’ setting, the Loss of Phase is released immediately. Range
Def.
Step
Unit
Volt ON Level
50~90
80
5
%
Volt OFF Level
35~75
50
5
%
Delay Time
0.1~30.0
0.4
0.1
sec
Function In Use
OFF/ON
ON
Comment
5.8. PHASE SYNC. CHECK
FTU-R200 monitors the phase angle difference between source and load side voltages of Recloser. If the angle difference is larger than the setting and maintains longer than the set time, then alarm is generated. The alarm is useful to close Recloser safely which is installed at the tie point of two feeders from the separated substation. The result of phase synchronization check can be used for interlocking close operation by setting. (Please refer to “Close interlock” in the configurations.) Range
Def.
Step
Unit
5~60
30
1
Degree
Delay Time
0.1~30.0
0.1
0.1
sec
Function In Use
OFF/ON
ON
Phase Difference
46
Comment
5.9. UNDER VOLTAGE PROTECTION
Figure 5-11 Functional Diagram for Under Voltage Protection Range
Def.
Step
Unit
Pickup Level
0.30~0.95
0.80
0.01
PU
Delay Time
0.1~180.0
1.0
0.1
sec
OFF/ARAMP/TRIP
OFF
Function In Use
Comment
5.10. OVER VOLTAGE PROTECTION
Figure 5-12 Functional Diagram for Over Voltage Function Range
Def.
Step
Unit
Pickup Level
1.05~1.50
1.20
0.01
PU
Delay Time
0.1~180.0
1.0
0.1
sec
OFF/ARAMP/TRIP
OFF
Function In Use
Comment
47
5.11. UNDER FREQUENCY PROTECTION
Range
Def.
Step
Unit
Pickup
47.00~59.98
49.80
0.01
Hz
Delay Time
0.03~10.00
0.10
0.01
sec
OFF/ARAMP/TRIP
OFF
Function In Use
Comment
5.12. OVER FREQUENCY PROTECTION
Range
Def.
Step
Unit
Pickup
50.02~63.00
60.20
0.01
Hz
Delay Time
0.03~10.00
0.10
0.01
sec
OFF/ARAMP/TRIP
OFF
Function In Use
48
Comment
5.13. ANALOG ALARM
The FTU has five configurable alarm analogue types: phase current, ground current, negative phase sequence current, and phase voltage and system power. Each analogue type has a configurable high alarm value as well as a configurable low alarm value. If an analogue value passes the alarm threshold the binary alarm will become active. If, after a HI Alarm, all analogues of the same type are below the high alarm reset threshold then the HI binary alarm will be turned off. If, after LOW Alarm, analogues of the same type are above the low alarm reset threshold and all other, then the LOW binary alarm will be turned off. Alarming can be ON or OFF via configuration of the FTU. Range
Def.
Step
Unit
Comment
Phase Current
1~16000
16000
1
A
A/B/C phase current
Ground Current
1~16000
16000
1
A
NPS Current
1~16000
16000
1
A
Phase Voltage
1~38000
38000
1
V
A/B/C phase voltage
System Power
1~54000
54000
1
K
KVA, KVAR and KW
Function In Use
OFF/ON
OFF
Phase Current
0~15999
0
1
A
A/B/C phase current
Ground Current
0~15999
0
1
A
NPS Current
0~15999
0
1
A
Phase Voltage
0~37999
0
1
V
A/B/C phase voltage
System Power
0~53999
0
1
K
KVA, KVAR and KW
Function In Use
OFF/ON
OFF
Analog High Alarm
Analog Low Alarm
49
5.14. MULTIPLE SETTING GROUPS
The FTU-R200 supports up to 4 Setting Groups, each of which can be configured with completely separate characteristics with different setting parameters. One of setting groups can be assigned to be used as parameters of functions for forward or reverse power flow condition respectively. And FTU-R200 supports Automatic Setting Group Selection which is used to change the setting group depending on the direction of power flow automatically.
Normal Setting Group Alternative Setting Group Active Alternative Setting Group
50
Range
Def.
Step
1~4
1
1
OFF/ON
OFF
1~4
1
1
Unit
5.15. LOOP AUTOMATION SCHEME
While recloser is used as tie breaker and the function “OT(Open Tie) closing” is enabled, recloser can be closed automatically when one side of recloser is deenergized. The parameter “OT Source Side”in the following table indicates source side. “OT Source Side” =”BOTH” : If any side of recloser is deenergized and sustained during “OT Closing Time”, recloser will be closed automatically “OT Source Side” =”ABC” : ABC -> RST When only RST side of recloser isdeenergized, recloser will be closed. Thus the source from ABC side will energize the distribution line. “OT Source Side” =”RST” : RST -> ABC When only ABC side of recloser isdeenergized, recloser will be closed. Thus the source from RST side will energize the distribution line.
Recloser has also auto-sectionalizing function. If the function is enabled (“Section On”), recloser will open automatically after “Section Open time” when the line is deenergized with closed.
Range
Def.
Step
0(Off)/1(On)
0
1
Section Open time
0~240
OFF
1
OT Closing On/Off
0(Off)/1(On)
0
1
OT Source Side
BOTH(0), ABC(1), RST(2)
0
1
OT Closing Time
0~600
5
1
Section On/Off
Unit
sec
sec
51
6. CONFIGURATION SETTING 6.1. I/O CONFIGURATION 6.1.1. AC RATING Range
Def.
Step
Unit
Line Configuration
Y-G/DELTA
Y-G
System Frequency
50/60
Rated Voltage (L-L) Reference Voltage (L-N)
50
10
Hz
1000~40000
22000
10
V
Phase to Phase
1000~30000
12700
10
V
Phase to Earth
Reference Phase
A/B/C
A
CT Ratio
1~5000
1000
FWD/REV
FWD
1.0~5000.0
1000.0
NCT Direction
FWD/REV
FWD
Phase Rotation
A-B-C/A-C-B
A-B-C
INT_6CVT/ EXT_3PT/EXT_4PT
INT_6CVT
NOT USED/ 110V/SQRT(3)/ 115V/SQRT(3)/ 120V/SQRT(3)
NOT USED
CT Direction NCT Ratio
VT Type VT Secondary Voltage
Comment
1
0.1
“Line Configuration” shall be set according to the power system grounding. The parameter will affect the calculation of 3-phase total harmonic distortion. “System Frequency” shall be set correctly. If it is set wrongly, the measurement can’t be performed properly. “Rated Voltage” is the rated line-to-line voltage of power system. This parameter is the reference for voltage monitoring such as undervoltage protection, sag, swell, etc. “Reference Voltage” is the primary voltage of voltage sensor at predefined secondary voltage. This parameter is used internally as reference value for voltage measurements. Always voltage sensors shall be configured with line-to-ground for appropriate measurements.
52
“Reference Phase” : This parameter makes change of phase denotation of 3-phase voltages and currents input terminal of FTU. For example, if the parameter is set with “B”, B terminal of voltage and current inputs is for A-phase measurement. C is for B-phase. A is for C. “CT direction”/”NCT direction : Using this parameter, the polarity of current transformer can be compensated. “Phase Rotation” shall be set with “A-C-B” when the transposed line is connected to recloser. It’s important because it affects the sequence component calculation of 3 phase voltages and currents.
6.1.2. WAVEFORM TRIGGER Range
Def.
16/32/64/128
128
Pre-1st Cycle
1~5
Post-2nd Cycle Pre-2nd Trigger Cycle
Sample Record Frequency
Step
Unit
2
1
Cycle
1~5
2
1
Cycle
1~10
10
1
Cycle
Comment
Waveform on a fault or disturbance event will be recorded on non-volatile memory. Waveform recording will be triggered by pickup first(1st trigger) and be closed by 2nd trigger at the time of reset of the pickup. Recorded sample frequency can be adjusted. If 128 samples/cycle is selected, 20 cycles waveform will be recorded. If 16 samples/cycle is selected, 160 cycles will be recorded.
6.1.3. DEMAND SETTING
Block Interval Rolling Interval
Range
Def.
15/30/60
30
1/5/15/30/60
30
Step
Unit
Comment
The FTU calculates and stores average of currents and active, reactive powers during the demand interval, which is configurable as 15, 30 or 60 minutes. Please refer to the description of the demand function in section 8.
53
6.1.4. ENERGY PROFILE Range
Def.
MONTHLY/WEEKLY
MONTHLY
Demand Reset Day
MON~SUN
MON
Demand Reset Date
1~28
1
Profile Type
Step
Unit
1
Date
Comment
Energy and peak demand data will be stored monthly or weekly as profile. “Profile Type” -
Weekly : FTU will store energy data and peak data weekly at noon of “Demand Reset Day”.
-
Monthly : FTU will store energy data and peak data monthly at noon of “Demand Reset Date”.
6.1.5. FI RESET METHOD
FI Reset Select
Range
Def.
MANUAL/AUTO
MANUAL
0~12
0
FI Time Out
Step
Unit
1
Hour
Comment
“FI Reset Select” - Manual : FI is latched until FI reset button on the front panel is pressed or the reset command is issued from master station or maintenance software. - Auto : When the line (voltage) is restored without fault current (pickup), FI will be reset 2 second after. Manual reset also is allowed in this mode. “FI Time Out “ 0 : This function is not used. non-zero : FI will be reset automatically in the set time after FI was indicated at any condition regardless of “FI Reset select”.
6.1.6. CLOSE INTERLOCK
54
The following close interlock conditions can be enabled or disabled. When the close command is issued manually or automatically, the interlock condition will be checked before closing. So live load or phase sync. failure between both sides voltages will block the close operation if the condition is enabled with “Yes”. “Live Load” status means that both sides of recloser contact are energized. If the condition is enabled, the closing operation would be allowed while at least one side of recloser is deenergized. Sync. failure condition will be effective only when “Live Load” is disabled. It means that at “LiveLive” condition FTU will check the status of “Phase Synch. Check” function for secure closing. Range
Def.
Live Load
NO/YES
NO
Sync. Fail
NO/YES
YES
Step
Unit
Comment
6.1.7. VOLTAGE DISPLAY
FTU shows 3-phase currents and voltages on LCD. The voltage values displayed on this summarized measurements can be selected through setting with phase voltages or line-toline voltages.
Voltage Display
Range
Def.
L-N/L-L
L-N
Step
Unit
Comment L-N : Line to Earth L-L : Line to Line
I I I I
a b c n
: : : :
0 0 0 0
0 0 0 0
0 0 0 0
0 0 0 0
0 0 0 0
A A A A
0 0 0
Figure 6-1 Summarized measurements display on LCD
6.1.8. AUTOMATIC BATTERY CHECK
Checking Cycle
Range
Def.
Step
Unit
0~30
0
1
Day
Comment
55
Checking Time (Hour)
0~23
0
1
Hour
Checking Time (Min)
0~59
0
1
Min
Battery test function can be initiated automatically through setting. “Checking Cycle” : Test period (unit: days), “0” : automatic checking is disabled. “Checking Time (Hour)”, “Checking Time (Min)” : The time which the test function is executed.
6.1.9. FI TYPE SELECT
FI Type Select
Range
Def.
TRIP/FPI
TRIP
Step
Unit
Comment
FTU-R200 supports two kinds of fault indicator according to setting -
Trip Indicator : 3-stage OC & EF elements indicates their starting(fault pickup) status when trip output is initiated from any phase element. (* indicates only operating status of each phase element in the firmware earlier than V3.03)
-
Fault Passage Indicator : When line is de-energized after pickup before operating of OC elements, FTU will indicates FI with started OC status. When FTU outputs trip by OC or E/F elements, FPI will operate same as “Trip Indicator”. FPI without trip also will produce fault current event with started phase marked and record fault waveform. FPI without trip will make starting event, but no operating event.
6.1.10. CLOSING DELAY
Closing Delay
Range
Def.
Step
Unit
0~300
0
1
sec
Comment
FTU-R200 supports delayed closing for manual close operation through the button on the front panel or FTUMan. It allows time for local operator to exit the Recloser perimeter).
56
6.2. POWER QUALITY MONITORING FUNCTION 6.2.1. VOLTAGE & CURRENT UNBALANCE
Voltage or current unbalance (or imbalance) is detected by monitoring the negative sequence value relative to the positive sequence value of 3-phase voltages and currents. Range
Def.
Step
Unit
Detection Level
0~100
30
1
%
Detection Time
0.1~60.0
1.0
0.1
sec
Detection Level
0~100
30
1
%
Detection Time
0.1~60.0
1.0
0.1
sec
Comment
Voltage Unbalance
Current Unbalance
6.2.2. SHORT-DURATION VOLTAGE VARIATION
There are three types of short-duration voltage variations, namely, instantaneous, momentary and temporary, depending on its duration. Short-duration voltage variations are caused by fault conditions, energization of large loads, which require high starting currents or loose connections in power wiring. Depending on the fault location and the system conditions, the fault can generate sags, swells or interruptions. The fault condition can be close to or remote from the point of interest. During the actual fault condition, the effect of the voltage is of short-duration variation until protective devices operate to clear the fault. 6.2.2.1. SAG
A sag (also known as dip) is a reduction to between 0.5 and 0.99 pu in RMS voltage or current at the power frequency for a short period of time from 0.5 to 10 cycles. A 10% sag is considered an event during which the RMS voltage decreased by 10% to 0.9 pu. Voltage sags are widely recognized as among the most common and important aspects of power quality problems affecting industrial and commercial customers. They are particularly troublesome. Since they occur randomly and are difficult to predict. Voltage sags are normally associated with system faults on the distribution system, sudden increase in system loads, lightning strikes or starting of large load like induction motors. It is not possible to eliminate faults on a system. One of the most common causes of faults occurring on high-voltage transmission systems is a lightning strike. When there is a 57
fault caused by a lightning strike, the voltage can sag to 50% of the standard range and can last from four to seven cycles. Most loads will be tripped off when encounter this type of voltage level. Possible effect of voltage sags would be system shutdown or reduce efficiency and life span of electrical equipment, particularly motors. Equipment sensitivity to voltage sag occurs randomly and has become the most serious power quality problem affecting many industries and commercial customers presently. An industrial monitoring program determined an 87% voltage disturbances could be associate to voltage sags. Most of the fault on the utility transmission and distribution system are single line-to-ground faults (SLGF). Range
Def.
Step
Unit
Detection Level
0.50~0.99
0.90
0.01
PU
Detection Time
0.5~10.0
2.0
0.5
Cycle
Comment
6.2.2.2. SWELL
A swell (also known as momentary overvoltage) is an increase in RMS voltage or current at the power frequency to between 1.01 and 1.5 Pu for duration from 0.5 to 10 cycles. Swells are commonly caused by system conditions, switching off a large load or energizing a large capacitor bank. A swell can occur during a single line-to-ground fault (SLGF) with a temporary voltage rise on the unfaulted phases. They are not as common as voltage sags and are characterized also by both the magnitude and duration. During a fault condition, the severity of a voltage swell is very much dependent on the system impedance, location of the fault and grounding. The effect of this type of disturbance would be hardware failure in the equipment due to overheating. Range
Def.
Step
Unit
Detection Level
1.01~1.50
1.20
0.01
PU
Detection Time
0.5~10.0
2.0
0.5
Cycle
58
Comment
6.2.2.3. INTERRUPTION
An interruption occurs when there is a reduction of the supply voltage or load current to between 0.1 and 0.49 pu for duration from 0.5 to 10 cycles. Possible causes would be circuit breakers responding to overload, lightning and faults. Interruptions are the result of equipment failures, power system faults and control malfunctions. They are characterized by their duration as the voltage magnitude is always less than 10% of the nominal. The duration of an interruption can be irregular when due to equipment malfunctions or loose connections. The duration of an interruption due to a fault on the utility system is determined by the utility protective devices operating time. Range
Def.
Step
Unit
Detection Level
0.10~0.49
0.10
0.01
PU
Detection Time
0.5~10.0
2.0
0.5
Cycle
Comment
6.2.3. VOLTAGE & CURRENT THD ALARM
The Total Harmonic Distortion, or THD, of a signal is a measurement of the harmonic distortion present and is defined as the ratio of the sum of the powers of all harmonic components to the power of the fundamental frequency. Range
Def.
Step
Unit
Alarm Level
0.5~100.0
0.0
0.1
%
Detection Time
0.2~60.0
0.4
0.2
sec
Alarm Level
0.5~100.0
0.0
0.1
%
Detection Time
0.2~60.0
0.4
0.2
sec
Comment
Voltage
Current
59
6.3. COMMUNICATION 6.3.1. PORT PARAMETERS 6.3.1.1. SCADA PORT
Serial Port Speed
Range
Def.
1200/2400/4800/9600/19200
9600
1~65534
1
DNP or DNPTCP
DNP or DNPTCP
Slave Address Protocol
Step
Unit
1
/IEC101/IEC104/MODBUS Select Port
RS232C/RS485
RS232C
6.3.1.2. MODEM CONTROL
Line
Range
Def.
HALF-DUFLEX
FULL-DUFLEX
Step
Unit
/ FULL-DUFLEX
RTS Off Delay
10~500
50
5
ms
CTS Timeout
1~255
2
1
sec
DCD Timeout
0.1~30.0
5.0
0.1
sec
NOT USED/USED
USED
0~200
0
5
ms
NONE/ODD/EVEN
EVEN
Step
Unit
RTS/CTS Control CTS to Message Delay Parity (Applicable only to IEC)
6.3.1.3. TCP/IP Range IP Address Subnet Mask Gateway 60
Def. 0.0.0.0 255.255.255.0 0.0.0.0
6.3.1.4. PSTN CONFIGURATION
The PSTN function is applicable only to DNP3.0.
PSTN MODEM Phone Number #1~#10
Range
Def.
NOT USED/PPP/ DIAL-UP/SMS
NOT USED
Step
Unit
20 Digit
Auto Hang-up Time
0~255
30
1
sec
Dial Timeout
10~255
90
1
sec
Attempt Delay
10~3600
60
10
sec
Max Attempts
1~5
3
1
Range
Def.
Step
Unit
UTC Offsets (Hour)
-12~13
5
1
Hour
UTC Offsets (Min)
0~59
30
1
Min
Range
Def.
Step
Unit
LOCAL/UTC
LOCAL
Range
Def.
Step
Unit
DISABLE/ENABLE
DISABLE
1~24
1
1
Hour
6.3.1.5. TIME ZONE
6.3.1.6. UTC OPTION
Mode
6.3.1.7. SNTP OPTION
Mode Cyclic Period
61
6.3.1.8. PPP CONFIGURATION Range APN(Access Point Name)
40 Digit
User Name
40 Digit
Password
40 Digit
Def.
Fixed Our IP Address
0.0.0.0
Fixed Their IP Address
0.0.0.0
Fixed DNS-1 IP Address
0.0.0.0
Fixed DNP=2 IP Address
0.0.0.0
Step
Unit
Step
Unit
6.3.1.9. SMS MESSAGE CONFIGURATION Range Switch Name
Def.
20 Digit
FI
DISABLE/ENABLE
DISABLE
Open/Close
DISABLE/ENABLE
DISABLE
Door Open
DISABLE/ENABLE
DISABLE
AC Fail
DISABLE/ENABLE
DISABLE
62
6.3.2. DNP3.0 PARAMETERS Range
Def.
Step
D/L Retries
0~2
0
1
D/L Timeout
1~255
30
1
D/L Confirm
NO/YES/SOMETIMES
SOMETIMES
A/L Retries
0~2
1
1
A/L Timeout
1~255
40
1
sec
NO/YES
NO
Unsolicited Class 1 Delay Time
0~60
5
1
sec
Unsolicited Class 2 Delay Time
0~60
5
1
sec
Unsolicited Class 3 Delay Time
0~60
5
1
sec
Arm Timeout
1~255
15
1
sec
Unsolicited Address
0~65534
65534
1
Multi Frame Interval
10~500
100
10
Unsolicited Class 1
DISABLE/ENABLE
DISABLE
Unsolicited Class 2
DISABLE/ENABLE
DISABLE
Unsolicited Class 3
DISABLE/ENABLE
DISABLE
Analog Event Mode
SOE/MOST RECENT
SOE
Initial Unsolicited MSG
Unit
sec
ms
63
6.3.3. IEC PARAMETERS Range
Def.
Step
Unit
Analog Value Type
Normalized/Scaled
Scaled
Analog Event Mode
SOE/MOST RECENT
SOE
A/L Cyclic Period
0~60
0
1
sec
Arm Timeout
1~255
15
1
sec
M_SP Cyclic
DISABLE/ENABLE
DISABLE
M_DP Cyclic
DISABLE/ENABLE
DISABLE
M_ME Cyclic
DISABLE/ENABLE
ENABLE
M_SP Start Address
1~10000
100
1
C_SC Start Address
1~10000
200
1
M_DP Start Address
1~10000
300
1
C_DC Start Address
1~10000
400
1
M_ME Start Address
1~10000
1000
1
C_SE Start Address
1~10000
2000
1
M_IT Start Address
1~10000
4000
1
Link Address Size
0~2
2
1
Common Address Size
1~2
2
1
Object Address Size
1~3
2
1
COT Size
1~2
1
1
NONE/CP24/CP56
CP56
NO/YES
YES
UNBALANCED/BALANCED
UNBALANCED
t0 Connection timeout
1~255
30
1
sec
t1 Response timeout
1~255
15
1
sec
t2 S-Frame Period
1~255
10
1
sec
t3 Test Period
1~255
20
1
sec
IEC101 PARAMETERS
Time Marker Single NACK Control Link Mode
IEC104 PARAMETERS
64
7. STATUS MONITORING & CONTROL 7.1. SWITCH (RECLOSER) STATUS MONITORING
FTU has 10 binary inputs. These inputs can be assigned to monitor switch open/close, gas and lock status of switch (Recloser) body through auxiliary contacts. FTU scans these contacts input every 5 milliseconds. Switch open/close status is determined by double binary inputs, normally open and closed contacts. All input status are shown on LCD or FTUMan and are transmitted to master station on its request. Changed status can be transmitted unsolicitedly with or without time and are recorded on non-volatile memory as events with time tag in history buffer orderly. For each contact input, on-delay time can be applied. It’s adjustable within 10~500ms by 5ms step. The time is used to debounce the contact input and suppress unnecessary events. And each input can be used to affect control action, block open or close control, or force to trip or close main switch or recloser.The following picture is an example window of I/O configuration tool. Here the name for each input can be configured. Configured name is shown also on LCD display. Invert mask can be used to invert the active state of the corresponding input.
Figure 7-1 Binary Input configuration
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7.2. SWITCH CONTROL
FTU has 4 binary contacts output and 2 high-speed output command. These output are used to control Switch or output alarms. Switch (Recloser) can be controlled from remote or local operator place. Operator place can be changed only at local front panel. ‘REMOTE CONTROL’ push button is to select the operator place. Operator place is toggled between local and remote by pushing button. LED is lit if remote position is selected. FTU begins with remote position at power-up. Control is allowed only at the position selected. Local switch control requires two-step operation. It’s for security of operation. ‘SELECT’ button should be pushed before ‘CLOSE’ or ‘OPEN’. SELECT LED is lit if SELECT operation is valid. SELECT can be canceled by pushing SELECT button again or automatically after SBO timeout without operation. CLOSE or OPEN operation is valid while this LED is lit. Pushing CLOSE or OPEN button outputs switch control signal with fixed time pulse which is configurable. Switch status change input which is auxiliary contacts of switch stops continuing to output pulse. There are some interlock conditions to inhibit FTU from outputting pulse signal. Gas low, Switch handle lock, same status of switch auxiliary contacts ‘a’, ‘b’ are those. And there is “control lock” button. Control lock mode inhibits switch operation and reclosing after tripping a fault. So it’s useful as “Work tag” when the maintenance work is being done. The status is toggled when the button is pushed. Close or open pulse width shall be set longer than switch operating time. Remote switch control is possible by using SCADA protocol DNP3.0 or IEC60870-5-101, IEC60870-5-104 FTU supports SBO (Select Before Operate) or Direct operate. If the operator place is set to ‘Local’, remote control commands are refused. Pulse width of remote control command shorter than setting will be overridden by local configuration
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7.3. BATTERY & BATTERY CHARGER MONITORING
FTU monitors external Lead-acid battery through the control unit, which are mounted on inner back-side wall of control box. The control unit contains microprocessor based battery charger. It measures battery terminal voltage and charging voltage. So it can check charger over-voltage and battery fail or battery low status while external AC supply is off. So it provides battery voltage values and alarm status which is the result of continuous check. Provided information details are like the followings. -
External AC power loss
-
Battery low
-
High battery voltage alarm
-
Battery failed alarm
-
Battery charger overvoltage alarm
-
Grounded battery (optional if required)
The conrol unit has also the over-discharge protection. If over-discharge condition occurred, the control unit sends alarm signal “Battery Low” to RTU and disconnect battery in order to protect battery cell damage after 1-minute delay. The delay enables RTU to send alarm state to remote station via communication. Battery test function is provided. This function is performed by disconnecting charging voltage to battery and connecting dummy load to battery. The test control command can be issued at local or remote. And also automatic test is available through setting.
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8. MEASUREMENTS 8.1. BASIC ELECTRIC QUANTITIES
FTU-R200 has 4 currents and 6 voltages input. DSP digitizes these signals using 16 bits A/D converter and calculates various electric quantities numerically from those digitized data. As a result, FTU gives true RMS, all power and energy values for 3-phase voltages and currents. FTU presents also phasor quantities calculated through fundamenatal power frequency components extracted by FFT (Fast Fourier Transform) algorithm. FFT is performed every millisecond using 128 samples for 1 cycle. True RMS is calculated every cycle. All electrical quantities are provided with the average value for 200ms (10cycle for 50Hz, 12cycle for 60Hz). Analog filters and digital filters are used to minimize the effects of high frequency noise in the input signals. And the calibration is performed in the factory before delivery using precise current and voltage signal generator. The calibration compensates the measurements error caused by the components in the circuit of input. Provided electric quantities are listed in the following. Currents (Ia, Ib, Ic, In)
RMS, Phase Angle, True RMS
Voltage (Va, Vb, Vc, Vr, Vs, Vt)
RMS, Phase Angle, True RMS
Apparent Power
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Active Power
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Reactive Power
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Power Factor
A-Phase, B-Phase, C-Phase, 3-Phase Total,
Va-Vr Phase Angle Difference Current, Voltage Unbalance Frequency, Temperature
In the above items listed, active power, reactive power values are signed integer. Sign represents power flow or if loads are inductive or capacitive. Also power factor has lead/lag state value separately. Currents and voltages have phase angles, which are relative phase angles compared to the reference Va. These angles are useful to monitor the phase sequence and imbalance of distribution line.
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8.2. SEQUENCE COMPONENTS
FTU provides the sequence components of 3-phase currents and voltages. They are positive sequence current (I1) and voltage (V1), negative sequence current (I2) and voltage (V2), and zero sequence voltage (V0) which are calculated by 3-phase phasor quantities. This information can be used to monitor imbalance of distribution line.
8.3. HARMONICS
FTU provides 2nd to 31st harmonic magnitudes and THDs (Total Harmonic Distortion) for each phase. THD is the total harmonic percentage to the fundamental frequency component. FTU also calculates and provides 3-phase THD. These values may be used to monitor the power quality of distribution line.
8.4. ENERGY
FTU provides active energy, reactive energy for each phase or 3-phase total. Also import, export energy are accumulated on separate registers. Units of energy are kWh, kVarh, which represent primary distribution line energy flow. The values are accumulated on 32-bit and 16-bit kWh, kVarh counters which rollovers. The 32-bit register is for local display and the 16-bit register is to transmit energy data to SCADA like the following picture.
Figure 8-1 Structure of energy counter
Normally in order to accumulate energy values, SCADA system reads 16-bit energy counter in FTU periodically and calculates increments between two readings and adds the increments to energy register in SCADA. DNP3.0 or IEC protocol supports the function of counter objects to accumulate energy value easily. For example “freeze and clear” function is useful to accumulate energy pulse increments. 69
Reactive energy is also accumulated on separate registers according to the quadrant of power like the following figure 8-2. So 24 energy counters are provided as in the figure 8-3.
Figure 8-2 Four-quadrant power flow directions
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Figure 8-3 Energy counters
8.5. DEMAND CURRENTS AND POWER
FTU supports block demand and rolling demand. If block and rolling interval are same, FTU calculates demand values based on block interval. It is block demand mode. For rolling demand, rolling interval will be subinterval within block interval. So FTU calculates demand values based on N rolling intervals every rolling interval. Here N is the value corresponding to block interval devided by rolling interval. Types of demand values are phase currents and active, reactive powers. -
Block interval
15/30/60
minutes
-
Rolling interval
1/5/15/30/60 minutes
For example, suppose that block interval is 15min. and rolling interval is 5min. In this case, rolling demand values are calculated every 5min based on the data during most recent 15min.
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Figure 8-4 block demand and rolling demand
The demand values are recorded up to 6143 intervals. The length corresponds to 63 days based on 15 min. demand. Also peak demand values are recorded daily up to 1023 days. And weekly or monthly data are recorded through automatic demand reset according to settings up to 63 amounts. Manual reset also is available. Weekly/monthly data contains the following information. All energy and power data are saved with each phase and 3-phase total data. Reset time (date & time) Import(Forward) Active Energy
Export(Reverse) Active Energy
kWh
Import Inductive energy
Export Inductive energy
kVarh
Import Capacitive energy
Import Capacitive energy
kVarh
Peak current with time stamp (Ia,Ib,Ic,In) Peak positive Active power with Peak negative Active power with kW time tamp time tamp Peak positive positive Inductive Peak negative Inductive energy kVar energy with time stamp with time stamp Peak positive positive Capacitive Peak negative Capacitive energy kVar energy with time stamp with time stamp
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8.6. INTERRUPTER DUTY MONITOR
FTU shows the estimated life of the interrupter contact through calculation using trip current. The function gives the remaining counts for interrupter to trip at 1 kA. And FTUMan shows the curve of the interrupter duty. The allowable trip counts at 1kA will be decreased by ( I_trip(kA))2
Figure 8-5 interrupter duty monitor
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9. MAINTENANCE SOFTWARE 9.1. OVERVIEW
FTU-R200 has a dedicated setting and operation tool, FTUMan. This tool is operated on PC or Notebook, and through RS232C port on front panel of FTU. For this communication, MODBUS protocol is used. It supports the following features. ü Setting & Configuration changes ü Event & Waveform load ü Measurement & Status display ü Waveform File upload and convert ü SCADA monitors protocol data frame between devices
Figure 9-1 Overview of FTUMans
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9.2. OPERATION OF FTUMAN 9.2.1. MENU 9.2.1.1. FILE New
Closes the current file and allows the creation of a new file
Open
Closes the current file and opens a standard window file selection dialog. An existing FTU File (*.f2s) can be selected and opened.
Save
Saves the current file to the hard drive. If the file is new and this is the first time it has been saved, the Save As dialog will be opened allowing the user to type in a name before saving.
Save As
Opens a standard Windows Save As dialog box. This allows an existing file to be saved under a new name.
Exit
Closes the current file and exits the tool.
9.2.1.2. COMM Comm.Config
Opens a window for communication configuration dialog.
Comm.Connection
Starts communication with FTU
Comm.Disconnection
Stops connecting with FTU
Figure 9-2 Comm. Configuration Window
ü
Port
ü
Baud Rate Make to the transmission medium per second of in a digitally signal
ü
Retry
Set up the count if it failed to connect
ü
Timeout
Set up the time to connect
Select a serial Port of Laptop
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9.2.1.3. OPTION ü
Select Model
The he FTUMan is used for FTU FTU-X200 Series. Default device model is FTU FTU-R200. If changed for setting another model,, select device type. And nd check current device model, see the status bar.
Figure 9-3 Select Device Window
ü
Change Password
The FTUMan has password for changed setting and command control, and it can modified ! Default password is ‘ftuman’. Maximum length of password: 10 Characters Characters. When lost password, input ‘ftuman’ and can re-set the password.
ü
Default Model
Figure 9-4 Select Device Window
The FTUMan support supportss the various model in country, user and version. So, when initially installed, it may different from current model. It is disappears when connect the device. But, if want to use off off-line, need to select the “Default Model”. ! For more information about this, please contact us.
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9.2.1.4. COMMAND ü
Setting Group Copy The Function Group can be copied. Select Source and destination group, then press OK to be copied. It does not mean write to FTU.
Figure 9-5 Setting Group Copy Window
ü
Clock Setting
Set RTC Time of FTU
Figure 9-6 Clock Setting Window
Device Time
Gets the current time per 1 second from FTU.
Setting Time
The operator can set aside time.
Use System Time
The operator can use PC’s time.
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ü
Write
Write RTC time to FTU-R200
Close
Close this window
Factory Initialization
Reset to factory defaults. Warning: Restoring FTU to factory defaults will erase all previous setting, configuration and event.
Figure 9-7 Factory Initialization Message Window
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9.2.1.5. TOOLS Protocol Monitoring
Protocol monitoring command activation or deactivation.
DNP3.0 Index Configuration
Run the DNPConfig program for DNP index configuration. The DNPConfig is explained in the Section 11.
IEC 60870 Index Configuration
Run the IECConfig program for DNP index configuration. The IECConfig is explained in the Section 13.
Waveform Evaluation Tool
Run the EvalTool program for analysis waveform data. The EvalTool is explained in the Section 12.
9.2.1.6. VIEW Toolbar
Show or hide the toolbar.
Status Bar
Show or hide the status bar.
Monitoring Bar
Show or hide the monitoring bar. The monitoring bar shows communication status with FTU.
9.2.1.7. HELP
The Help Menu opens a window for FTUMan’s program version and information.
9.2.2. TOOLBAR
Figure 9-8 Toolbar of FTUMan
Read
Read data from FTU.
Write
Write data to FTU.
About
Opens a window for FTUMan’s program version and information.
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9.2.3. STATUSBAR
Figure 9-9 Status Bar
MODEL
Model Name
F/W
Firmware Version
PORT
Serial Port Number and Speed
MODE
Communication Status
9.2.4. MONITORING BAR
Figure 9-10 Monitoring Bar
Some performance is finished Reads data from FTU Writes the setting value on FTU When Factory Initialization occurs. Error of connection or operation Connect or Disconnect between PC and FTU When the time set is completed
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9.2.5. FUNCTION AND CONFIGURATION SETTING
In Function and Configuration window, existing setting values of FTU can be viewed through ‘Upload’ button, or setting values are edited and downloaded to FTU by clicking ‘Download’ button to apply new setting values to FTU. In some cases, operators require to save and reuse these edited setting values. To satisfy this request, FTUMan tool has ‘New’, ‘Open’ and ‘Save’ menu items in File Menu. The file extension name is ‘f2s’. If you set up the ADGS (Auto Detection Group Setting) Function ‘ON’, you can check the current direction ‘Forward’ or ‘Reverse’. Function has 5 contents, 4 setting groups and active group setting. Each group has protection setting value for FTU. Configuration has 3 contents for I/O, PQM and communication. Communication separated 3 contents, for Port, DNP3.0 and IEC protocol parameter to communication for SCADA. In tree view, if you choose some content, icon will be replaced with a red icon from a blue icon. And show setting parameters related content.
Figure 9-11 Tree View for Function and Configuration
How to edit the setting value? Click the content in tree view and editing value using double-click or Enter-Key. If you changed value, the text color is changed in red.
Figure 9-12 before the Change
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Figure 9-13 after the Change
And, in event window has a following pop-up menu. In the Tree View, select ‘FUNCTION’ or ‘CONFIGURATION’ or all sub contents, and press the right-click popup menu is available. If you click ‘Read’ Button, the setting parameters related selected contents in the tree view reads from FTU. Also, if you click ‘Write’ Button, the setting parameters related selected contents in the tree view writes to FTU. Figure 9-14 Pop-up Menu for Event Window
Figure 9-15 Input Password Dialog
When the Factory Initialization or all of information are changed, Input Password Window will be appeared. Note: Default Password is ‘ftuman’.
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9.2.6. EVENT
In Event window, operators can list up all the event records, which are stored in the memory of FTU by clicking ‘Read’ button. Also 9 kinds of events are stored. Each event type of event can be separately uploaded from FTU. Time Resolution for event recording is 5 msec and scanning interval is 1 msec. And, in event window has a following pop-up menu. In the Tree View, select ‘EVENT’ and press the right-click pop-up menu is available.
Figure 9-16 Pop-up Menu for Event Window
Read
Reads the selected events in the tree view.
Clear All Events
Delete all event stored.
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9.2.6.1. I/O EVENT
Figure 9-17 I/O Event Window
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Index
Event sequence number, the recent events that occurred is displayed on top.
Date & Time
Event occurred time.
Description
Information of generated binary event.
Status
Occurred contact points and binary status, OFF/ON/AUTO
9.2.6.2. FUNCTION EVENT
Figure 9-18 Function Event Window
Index
Event sequence number, the recent events that occurred is displayed on top.
Date & Time
Event occurred time.
Description
Operation of protection functions.
Status
Occurred function event status, OFF/ON.
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9.2.6.3. SYSTEM EVENT
Figure 9-19 System Event Window
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Index
Event sequence number, the recent events that occurred is displayed on top.
Date & Time
Event occurred time.
Description
Information of generated event like set value changed, triggered by power reset and system error or self-diagnosis.
Status
Occurred event position and detailed description of system error or self-diagnosis.
9.2.6.4. FAULT EVENT
Figure 9-20 Fault Event Window
Index
Event sequence number, the recent events that occurred is displayed on top.
Date & Time
Event occurred time.
OC
Detecting over-current.
SEF
Detecting Sensitive Earth Fault.
NOC
Detection Negative Phase Current Sequence.
TRIP
Detection Trip Signal.
UV / OV
Detecting Under/ Over Voltage.
DIR
Fault current direction.
Inrush
Detecting inrush restraint.
Ia, Ib, Ic, In, V0
Fault current and zero-sequence voltage
Group
Current setting group 87
9.2.6.5. PQM EVENT
Figure 9-21 PQM Event Window
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Index
Event sequence number, the recent events that occurred is displayed on top.
Date & Time
Event occurred time.
Description
The occurrence history of power quality function change.
Value
RMS value of voltage when moment voltage change occurs. Unit: kV
Duration
Duration time of moment voltage change by msec. Unit: msec
9.2.6.6. DEMAND CURRENT EVENT
Demand Current Event displays daily average demand current in the list and waveform. When the ‘show graph’ check box is unchecked, Demand current are listed as in the window.
Figure 9-22 Demand Current Event Window
Index
Event sequence number, the recent events that occurred is displayed on top.
Date & Time
Event occurred time.
Ia, Ib, Ic, In
Demand current of each phase and neutral.
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9.2.6.7. DEMAND POWER EVENT
Demand Power Event displays daily average demand active and reactive power in the list and waveform. When the ‘show graph’ check box is unchecked, Demand power are listed as in the window.
Figure 9-23 Demand Power Event Window
Index
Event sequence number, the recent events that occurred is displayed on top.
Date & Time
Event occurred time.
kWa, kWb, kWc, kW3ph
3-phase total and each phase kW.
kVARa, kVARb, kVARc, kVAR3ph
3-phase total and each phase kVAR.
9.2.6.8. DAILY MAXIMUM CURRENT EVENT
Details are similar to section 9.2.6.6. Demand Current Event. 9.2.6.9. DAILY MAXIMUM POWER EVENT
Details are similar to section 9.2.6.7. Demand Power Event. 90
9.2.7. MEASUREMENT
Operators can monitor all kinds of measurement values such as current, voltage, sequence value, power and energy, etc. And, FTU-R200 has the function of Harmonic Analysis, therefore up to 31st harmonics RMS value and THD for current and voltage are measured and displayed. Lastly, counter values and accumulation data are displayed. FTUMan has 6 kinds of Measurements window. The measurement value updates per 1 second. 9.2.7.1. BASIC VALUE
Operators can check the basic value like load or source voltage, current including RMS, Phase Angle and True RMS also apparent, active and reactive power. And it shows unbalance frequency, temperature and so on.
Figure 9-24 Basic Measurements Window
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9.2.7.2. SEQUENCE VALUE
It shows zero, positive and negative sequence of source or load voltage and current.
Figure 9-25 Sequence Value Window
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9.2.7.3. POWER
You can check active, reactive and apparent power of each phase or 3-phase. It also shows lag of each phase or lead. FTU provides imported or exported energy according to conductive, inductive energy of each phase or 3-phase total.
Figure 9-26 Power Window
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9.2.7.4. HARMONICS
It displays THD and each harmonics value of voltage and current. It shows from 2nd to 31st per 1 second.
Figure 9-27 Harmonics Window
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9.2.7.5. COUNTER
It shows restart and fault counts
Figure 9-28 Counter Window
Restart
Show restarts time and its count.
Fault Counter
Show the fault count and Switch Trip.
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9.2.7.6. PQM COUNTER
It PQM and THD counter and total interruption time.
Figure 9-29 PQM Counter Window
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PQM Counter
Show the short-duration voltage variation event count.
Total Interruption Time
Show the total interruption time.
THD Counter
Show the each or total phase’s current and voltage THD counts.
9.2.7.7. STATUS
In status window, all the status indications and command are displayed.
Figure 9-30 Status Window
When operator supervises some command in status window, this window generated. Upper box shows device name, bottom box displays command name. If you click the ‘OK’ button, command will be operated and window will be disappeared.
Figure 9-31 Command Window
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9.2.8. WAVEFORM
In waveform window displays Fault and PQM waveforms list stored in FTU. FTU can record and store the data for up to 8 faults, up to 6 PQM and 1 waveform by manual triggering. And each waveform has the data of 20 cycles at 128 samples. How to upload waveforms are as follow. First, by using the ‘Upload’ command reads a list of stored waveforms on the FTU.
Figure 9-32 Waveform List Uploaded
To import the waveform from FTU, select a row and double click, you upload the following message window appears.
Figure 9-33 Message Window 98
If you click the ‘OK’ button, opens standard Windows Save As dialog box and enter the file name, and click the Save button. And then will start uploading waveform. The following window shows the progress for uploading.
Figure 9-34 Progress Window
The file is stored in the COMTRADE file format by converting. The stored file is available the waveform analysis by EvalTool. The EvalTool is explained in the Section 12. And, in waveform window has a following pop-up menu. In the Tree View, select ‘WAVEFORM’ and press the right-click pop-up menu is available.
Figure 9-35 Pop-up Menu for Waveform Window
Upload
Read waveform list from FTU.
Manual Trigger
Capture current waveform by manual triggering.
Clear Fault Waveforms
Delete all fault waveform stored.
Clear PQM Waveforms
Delete all PQM waveform stored.
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10. I/O CONFIGURATION TOOL 10.1. OVERVIEW
The ‘IOConfig’ tool allows FTU users to customize I/O mapping.
Figure 10-1 Overview of IOConfig Tool
The I/O mapping is created using this tool and saved to an IO File (*.iom).
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10.2. OPERATION OF IOCONFIG
To start the IOConfig Tool selects ‘Tools – IOConfig’. When you run the IOConfig Tool, main screen is displayed as shown in following figure. There are two pages in the IOConfig Tool.
Figure 10-2 Main Screen of IOConfig Tool
10.2.1. MENU
The File Menu has the following options. New
Closes the current file and allows the creation of a new file
Open
Closes the current file and opens a standard window file selection dialog. An existing IO File (*.iom) can be selected and opened.
Save
Saves the current file to the hard drive. If the file is new and this is the first 101
time it has been saved, the Save As dialog will be opened allowing the user to type in a name before saving. Save As
Opens a standard Windows Save As dialog box. This allows an existing file to be saved under a new name.
Exit
Closes the current file and exits the tool.
The Comm. Menu is explained in the Section 9.2.1.2 Comm. The View Menu is explained in the Section 9.2.1.6 View. The Help Menu opens a window for IOConfig’s program version and information. 10.2.2. TOOLBAR
Figure 10-3 Toolbar of IOConfig
Read
Read input or output data from FTU.
Write
Write input or output data to FTU.
About
Opens a window for IOConfig’s program version and information.
Once you Press the Read or Write button, the following window appears. This window determines the types of data read or write.
Figure 10-4 Select Widow
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10.2.3. INPUT
FTU has 10 inputs. Input is created by filling the fields on the Input tab. Each column is defined as follows.
Figure 10-5 Input Tab
Name
Input name is defined. Type of the characters is limited to 11 characters. Note: 0~3 of 4 input points is fixed.
Debounce Time
The minimum time to retain status change. Like, it prevents making useless information against chattering in the point
Invert
Specifies whether the point will be inverted.
Blk.Open
To open blocked
Blk.Close
To close blocked
Ext.Trip
To trip using external input
Ext. Close
To close using external input
10.2.4. OUTPUT
FTU has 4 relay outputs and 2 photoMOS relay outs. Output is created by filling the fields on the Output tab. Each column is defined as follows.
Figure 10-6 Output Tab
Name
Output name is defined. Type characters are limited to 11 characters. Only index number of 3 is changed.
Pulse Time
Set a pulse command. 103
11. DNP3.0 INDEX CONFIGURATION TOOL 11.1. OVERVIEW
Custom DNP3.0 point index maps can now be created and loaded into FTU directly from DNPConfig. The mappings is created using the tool and saved to a DNP3.0 mapping file (*.d3m).
Figure 11-1 Overview of DNPConfig
11.2. OPERATION OF DNPCONFIG
To start the DNPConfig Tool selects ‘Tools – DNP3.0 Index Configuration’ from the FTUMan menu. When you run the DNPConfig Tool, main screen is displayed as shown in following figure. There are 4 pages, Binary Input, Binary Output, Analog Input and Counter, in the DNPConfig Tool.
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Figure 11-2 Main Screen of DNPConfig
The DNPConfig tool allows the user to build custom mappings to suit their own application. Points are added by selecting point from the Configuration Tool. Points are deleted by selecting a row and pressing ‘Delete’. You can choose to either shift all the rows below up one, or leave the entire row blank.
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The maximum configurable points are like the followings. ü Up to 128 Binary Inputs ü Up to 32 Binary Outputs ü Up to 512 Analog Inputs ü Up to 128 Counters 11.2.1. MENU
The File Menu has the following options. New
Closes the current file and allows the creation of a new file
Open
Closes the current file and opens a standard window file selection dialog. An existing DNP File (*.d3m) can be selected and opened.
Save
Saves the current file to the hard drive. If the file is new and this is the first time it has been saved, the Save As dialog will be opened allowing the user to type in a name before saving.
Save As
Opens a standard Windows Save As dialog box. This allows an existing file to be saved under a new name.
Exit
Closes the current file and exits the tool.
The Comm. Menu is explained in the Section 9.2.1.2 Comm. The View Menu is explained in the Section 9.2.1.6 View. The Help Menu opens a window for DNPConfig’s program version and information.
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11.2.2. TOOLBAR
Figure 11-3 Toolbar of DNPConfig
Tool
Shows or hides a window the DNP3.0 Configuration tool box.
Read
Read input or output data from FTU.
Write
Write input or output data to FTU.
About
Opens a window for DNPConfig’s program version and information.
Pressing Read or Write button, the following window appears. This window determines the types of data read or write.
Figure 11-4 Select Widow
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11.2.3. CONFIGURATION TOOL BOX
The configuration tool box panel is launched by clicking the Tool button.
Figure 11-5 Configuration Tool Box
The toolbox contains every available point for FTU. The toolbox displays different points depends on which tab selected. For example, if the Counters tab is selected then only accumulators will be displayed on the list.
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11.2.4. BINARY INPUT
Binary inputs are used to report the status of binary points.
Figure 11-6 Binary Input Tab
Index
Specifies the DNP ID Number of the point Range : 0 to 127
Name
The name of the points as defined in the configuration tool box. ü
Selecting the cell then double clicking a point in the configuration tool box.
Class 0~3
The DNP3.0 class of the point. The default class can be modified by checking from the checkbox.
COS
Select event type, COS(Change of state) or SOE(Sequence of Events)
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ü
DNP3.0 Classes
There are four classes in DNP3.0. These are defined as follows:
0
Class 0 is not an event class. It is used when reporting current (static) data values and not changes of state events. Note: Setting a point to Class 0 will prevent the controller’s protocol handler from reporting change of state events for that point to the master station. The point still remains accessible through static data polls.
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1
Class 1 used to report high priority events. Events in this class take precedence.
2
Class 2 used to report medium priority events.
3
Class 3 used to report low priority events.
11.2.5. BINARY OUTPUT
Binary Outputs are used to perform operations on the Recloser and change setting.
Figure 11-7 Binary Output Tab
Index
Specifies the DNP ID Number of the point Range : 0 to 31
Name
The name of the points as defined in the configuration tool box. ü
Selecting the cell then double clicking a point in the configuration tool box.
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11.2.6. ANALOG INPUT
Analog Points are used to transmit analog data such as line currents, voltages and contact life. Analog inputs are created by adding points as required, then modifying the parameters from defaults if necessary.
Figure 11-8 Analog Input Tab
Index
Specifies the DNP ID Number of the point Range : 0 to 511
Name
The name of the points as defined in the configuration tool box. ü
Class 0~3 112
Selecting the cell then double clicking a point in the configuration tool box.
The DNP3.0 class of the point. The default class can be modified by
checking from the checkbox. COS
Select event type, COS(Change of state) or SOE(Sequence of Events)
Scale
The scale is used to multiply the reported analog value by the amount entered. For example, scaling the Ia RMS value by a multiple of ten will change the reported value from zero decimal points to one decimal point (i.e:9 to 9.0) Default Value: 1, Range: 0.01,0.1,1,10,100
Deadband
Display the deadband value for the point. The analog point value must change by more than the deadband amount before it is reported.
11.2.7. COUNTER
Counters are used to count data and events such as Trips, Protection Pickups, Faults and Accumulated kWh.
Figure 11-9 Counter Tab 113
Index
Specifies the DNP ID Number of the point Range : 0 to 127
Name
The name of the points as defined in the configuration tool box. ü
114
Selecting the cell then double clicking a point in the configuration tool box.
Class 0~3
The DNP3.0 class of the point. The default class can be modified by checking from the checkbox.
COS
Select event type, COS(Change of state) or SOE(Sequence of Events)
12. WAVEFORM EVALUATION TOOL 12.1. OVERVIEW
The Waveform data upload from FTU-R200 through the above setting program are analyzed in this evaluation tool. Graphs of currents/voltages and operation of protection elements are displayed, and instantaneous/RMS current and voltage values, phase angles and time information at tracker position are presented. If 2 trackers one is moving with left mouse button and the other with right mouse button are used, time difference between two points is presented and it becomes the ruler for correct operation of protection element as setting. And, harmonics up to 31st and THD (Total Harmonic Distortion) also show up. Recorded waveforms can be uploaded to FTUMan in local site. After uploading stored to the COMTRADE file format. These waveform data saved as COMTRADE file format and compatible with other analyzing tool. ü
COMTRADE file
Comtrade (Common format for Transient Data Exchange for power systems) is a file format for oscilloscopes data. It is used by many leading companies for the oscilloscopes used in high voltage substations. It has been standardized by the IEEE.
Figure 12-1 Overview of EvalTool 115
12.2. OPERATION OF EVALTOOL
To start the EvalTool selects ‘Tools – Waveform Evaluation Tool’ from the FTUMan menu. The tool has meter view and scroll view for graph.
Figure 12-2 Main Screen of EvalTool
12.2.1. MENU
The File Menu has the following options.
116
Open
Closes the current file and opens a standard window file selection dialog. An existing Data File (*.dat) can be selected and opened.
Exit
Closes the current file and exits the tool.
The Option Menu has the following options. Graph
Opens analog and digital graph select window..
Figure 12-3 Graph Select Window
Harmonic
Open a window for voltage and current harmonics.
Figure 12-4 Harmonic List Window
Move
Change the position of the screen.
Zoom
The screen to yellow line center to shrink or enlarge the size.
The Help Menu opens a window for EvalTool’s program version and information.
117
12.2.2. TOOLBAR
Figure 12-5 Toolbar of EvalTool
118
Graph
Show the entire graph
Harmonic List
Check the harmonic list
Move-First
Move to the beginning graph
Move-Double left
Show the prior 2-step
Move-Left
Show the prior 1-step
Move-Right
Show the posterior 1-step
Move-Double right
Show the posterior 2-step
Move-End
Move to the last graph
Zoom In
Enlarged image
Zoom out
Shrink image
Zoom All
Enlarge all image
13. IEC INDEX CONFIGURATION TOOL 13.1. OVERVIEW
Custom IEC 60870 point index maps can now be created and loaded into FTU directly from IECConfig. The mappings is created using the tool and saved to a IEC mapping file (*.icm).
Figure 13-1 Overview of IECConfig
13.2. OPERATION OF IECCONFIG
To start the IECConfig Tool selects ‘Tools – IEC 60870 Index Configuration’ from the FTUMan menu. When you run the IECConfig Tool, main screen is displayed as shown in following figure. There are 4 tabbed pages, MSP, CSC, MME and MIT, in the IECConfig Tool.
119
Figure 13-2 Main Screen of IECConfig
The IECConfig tool allows the user to build custom mappings to suit their own application. Points are added by selecting point from the Configuration Tool. Points are deleted by selecting a row by popup menu. The maximum configurable points are like the following. ü Up to 128 MSP Points ü Up to 32 CSC Points ü Up to 512 MME Points ü Up to 128 MIT Points 13.2.1. MENU
The File Menu has the following options. New
120
Closes the current file and allows the creation of a new file
Open
Closes the current file and opens a standard window file selection dialog. An existing IEC Config File (*.icm) can be selected and opened.
Save
Saves the current file to the hard drive. If the file is new and this is the first time it has been saved, the Save As dialog will be opened allowing the user to type in a name before saving.
Save As
Opens a standard Windows Save As dialog box. This allows an existing file to be saved under a new name.
Exit
Closes the current file and exits the tool.
The Comm Menu is explained in the Section 9.2.1.2 Comm. The Option Menu is explained in the Section 9.2.1.3 Option The View Menu is explained in the Section 9.2.1.6 View. The Help Menu opens a window for IECConfig’s program version and information.
13.2.2. TOOLBAR
Figure 13-3 Toolbar of IECConfig
Tool
Shows or hides a window the IEC 60870 Configuration tool box.
Read
Read input or output data from FTU.
Write
Write input or output data to FTU.
About
Opens a window for IECConfig’s program version and information.
121
Pressing Read or Write button, the following window appears. This window determines the types of data read or write.
Figure 13-4 Select Widow
13.2.3. CONFIGURATION TOOL BOX
The configuration tool box panel is launched by clicking the Tool button. The toolbox contains every available point for FTU. The toolbox displays different points depends on which tab selected. For example, if the Counters tab is selected then only accumulators will be displayed on the list.
Figure 13-5 Configuration Tool Box
122
13.2.4. MSP POINT
MSP points are used to report the single-point information.
Figure 13-6 MSP Point Tab
Index
Specifies the IEC protocol index. Range : 0 to 127
Name
The name of the points as defined in the configuration tool box. ü
Selecting the cell then double clicking a point in the configuration tool box.
GE
Assigned global interrogation group
G1~G8
Assigned to specific interrogation group 1~8
13.2.5. CSC POINT
CSC points are used to perform operations on Single Command.
Figure 13-7 CSC Point Tab
Index
Specifies the IEC protocol index. Range : 0 to 31
Name
The name of the points as defined in the configuration tool box. ü
Selecting the cell then double clicking a point in the configuration tool box.
123
13.2.6. MME POINT
MME points are used to transmit measured scaled value. MME Points are created by adding points as required, then modifying the parameters from defaults if necessary.
Figure 13-8 CSC Point Tab
Index
Specifies the IEC protocol index. Range : 0 to 511
Name
The name of the points as defined in the configuration tool box. ü
124
Selecting the cell then double clicking a point in the configuration tool box.
GE
Assigned global interrogation group
G1~G8
Assigned to specific interrogation group 1~8
Cyclic
Select cyclic data transmission.
Scale
The scale is used to multiply the reported analog value by the amount entered. For example, scaling the Ia RMS value by a multiple of ten will change the reported value from zero decimal points to one decimal point (i.e:9 to 9.0) Default Value: 1, Range: 0.01,0.1,1,10,100
Deadband
Display the deadband value for the point. The analog point value must change by more than the deadband amount before it is reported.
13.2.7. MIT POINT
MIT points are used to interrogate totals.
Figure 13-9 CSC Point Tab
Index
Specifies the IEC protocol index. Range : 0 to 127
Name
The name of the points as defined in the configuration tool box. ü
Selecting the cell then double clicking a point in the configuration tool box.
GE
Assigned global interrogation counter group
G1~G4
Assigned to specific interrogation counter group 1~4
125
APPENDIX 1. TC(TIME-CURRENT) CHARACTERISTIC CURVES
Figure A1- 1
126
A, B, C, D Curves
Figure A1- 2
EI, NI, VI, LI, SI Curves
127
Figure A1- 3
128
E, L, M, N Curves
Figure A1- 4
KP, P, R, T Curves
129
Figure A1- 5
130
V, W, Y, Z Curves
Figure A1- 6
1, 2, 3, 4 Curves
131
Figure A1- 7
132
5, 6, 7, 8 Curves
Figure A1- 8
8*, 9, 11, 13 Curves
133
Figure A1- 9
134
14, 15, 16, 18 Curves
Figure A1- 10
Ni, N2, N3, N4 Curves
135
Figure A1- 11
136
F, G, H, J Curves
Figure A1- 12
8+, 17, KG, A* Curves
137
Figure A1- 13
138
IM, IV, IE, U8, U2 Curves
