FTU R-200.pdf

RECLOSER CONTROLLER for Distribution Automation (Model Name : FTU – R200)

JIN KWANG E & CORPORATION

705, Buk-ri, Namsa-myun, Yongin, Kyunggi-do, Korea

Tel Fax

+82-31-333-3444 +82-31-332-5300, 5301

Website

http://www.jinkwang.co.kr

E-mail

[email protected]

ISO 9001 certified

Recloser controller FTU- R200

CONTENTS 1.

2.

OVERVIEW................................................................................................................................................................................................. 8 1.1.

Protection of Distribution Lines ........................................................................................................... 8

1.2.

Function of Automatic Circuit Recloser ............................................................................................ 8

1.3.

Main Features of FTU-R200 ................................................................................................................... 9

Technical Data....................................................................................................................................................................................... 12 2.1.1. 2.1.2

Digital Processor .......................................................................................................................................12 Dual Processor Architecture ............................................................................................ 12

2.1.2Analog/Digital Conversion ......................................................................................................... 12 2.1.3.

DSP........................ ........................... ........................... ........................... ............................ 13

2.1.4.

CPU .................................................................................................................................... 13

2.1.5.

Functional Block Diagram ................................................................................................ 14

2.2.

Environmental Conditions.....................................................................................................................14

2.3.

Inputs/Outputs ..........................................................................................................................................15

2.4.

Measurement .............................................................................................................................................17

2.4.1.

Current ....................... ........................... ............................ ........................... ....................... 17

2.4.2.

Voltage ............................................................................. ........................... ....................... 17

2.4.3.

Power ................................................................................................................................. 18

2.4.4.

Power Factor ..................................................................................................................... 18

2.4.5.

Frequency .......................................................................................................................... 18

2.4.6.

Energy ................................................................................................................................ 18

2.4.7.

Harmonic ........................................................................................................................... 18

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2.4.8. 2.5.

4.

Demand Current and Power......................... ........................... ........................... ............. 19 Communication .........................................................................................................................................19

2.5.1.

Physical Layer .................................................................................................................... 19

2.5.2.

Protocol for scada ............................................................................................................ 19

2.6.

3.


Recording.....................................................................................................................................................20

2.6.1.

Event Recorder .................................................................................................................. 20

2.6.2.

Waveform Event Recorder ............................................................................................... 21

Construct and External Connection ............................................................................................................................................. 22 3.1.

Appearance & Dimension ....................................................................................................................22

3.2.

Connector ....................................................................................................................................................24

Front Panel Operations ..................................................................................................................................................................... 25 4.1.

Button & LED Description ....................................................................................................................26

4.1.1.

LCD Display ....................................................................................................................... 26

4.1.2.

FTU Status ......................................................................................................................... 26

4.1.3.

MENU/UP/DOWN/ENTER Buttons .................................................................................. 26

4.1.4.

Serial Port .......................................................................................................................... 26

4.1.5.

Ethernet/SCADA/Protection Communication Led ......................................................... 26

4.1.6.

Battery Test & Lamp Test ................................................................................................ 27

4.1.7.

Reset Button...................................................................................................................... 27

4.1.8.

Function Led ..................................................................................................................... 27

4.1.9.

RECLOSE/PROTECTION/GROUND Enable Buttons and LEDS .............. ........................ 28

4.1.10.

REMOTE/CONTROL LOCK Buttons and LEDS................................................. ............... 28

4.1.11.

SELECT/OPEN/CLOSE Buttons and LEDS......................... .......................... ..................... 28

4.2.

LCD Manipulation.....................................................................................................................................29

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4.2.1. 5.

LCD Menu ......................................................................................................................... 30

Protection Functions .......................................................................................................................................................................... 35 5.1.

6


Fault Detection ..........................................................................................................................................35

5.1.1

Definite Time Protection

............................................................................................. 36

5.1.2

High Current Trip (HCT)

.............................................................................................. 36

5.1.3

Single Shot Operation

5.1.4

TC Curve .......................................................................................................................... 37

5.1.5

Example of TC Curve Editing ....................... .......................... ........................... ............... 39

5.1.6

Auto Reclosing Sequence

5.1.7

Sequence Coodination

................................................................................................. 37

........................................................................................... 41

................................................................................................. 43

5. 2

Cold Load Pi ckup .................................................................................................................................44

5.3

Sensitive Earth Fault (SEF) Detection ..............................................................................................45

5.4

Directional Blocking................................................................................................................................. 46

5.5

Inrush Restraints .......................................................................................................................................47

5.6

Open Line Detection (Loss Of Phase)..............................................................................................47

5.7

Phase Sync. Check....................................................................................................................................48

5.8

Under Voltage Protection .....................................................................................................................48

5.9

Over Voltage Protection........................................................................................................................49

5.10

Under Frequency Protection................................................................................................................49

5.11

Multiple Protection Groups..................................................................................................................50

Configuration Setting......................................................................................................................................................................... 51 6.1

I/O Configuration .....................................................................................................................................51

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6.1.1

AC Rating .......................................................................................................................... 51

6.1.2

Demand Setting ................................................................................................................ 54

6.1.3

Wave Trigger ..................................................................................................................... 54

6.1.4

Close Interlock .................................................................................................................. 55

6.1.5

FI Reset Select ................................................................................................................... 55

6.1.6

Voltage Display ................................................................................................................. 55

6.2

8

Power Quality Measurement Funcion .............................................................................................55

6.2.1

Voltage & Current Unbalance......................................................................................... 55

6.2.2

Short-Duration Voltage Variation ................................................................................... 56

6.2.3

Voltage & Current THD Alarm ........................................................................................ 58

6.3

7


Communication .........................................................................................................................................58

6.3.1

Port Parameters ................................................................................................................ 58

6.3.2

DNP3.0 Parameters ....................... ........................... .......................... .......................... ..... 60

6.3.3

IEC Parameters .................................................................................................................. 61

Status Monitoring & Control.......................................................................................................................................................... 62 7.1

Switch Control............................................................................................................................................62

7.2

Switch Status Monitoring......................................................................................................................62

7.3

Battey Monitoring ....................................................................................................................................63

Measurements....................................................................................................................................................................................... 64 8.1

Basic Electric Quantities.........................................................................................................................64

8.2

Sequence Components..........................................................................................................................64

8.3

Harmonics....................................................................................................................................................65

8.4

Energy............................................................................................................................................................65

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8.5 9

10

11


Demand currents and power ..............................................................................................................66

Maintenance Software....................................................................................................................................................................... 67 9.1

Overview.......................................................................................................................................................67

9.2

Operation of FTUMan............................................................................................................................68

9.2.1

Menu .......................... ........................... ........................... ........................... ....................... 68

9.2.2

Toolbar .............................................................................................................................. 70

9.2.3

71 Statusbar.............................................................................................................................

9.2.4

Monitoring bar .......................... ........................... ........................... ........................... ........ 71

9.2.5

Function and configuration Setting ....................... ........................... ............................ ... 71

9.2.6

Event .................................................................................................................................. 74

9.2.7

Measurement .................................................................................................................... 82

9.2.8

Status ................................................................................................................................. 88

9.2.9

Waveform .......................................................................................................................... 89

I/O Configuration Tool ...................................................................................................................................................................... 91 10.1

Overview.......................................................................................................................................................91

10.2

Operation of IOConfig ..........................................................................................................................92

10.2.1

Menu .................................................................................................................................. 93

10.2.2

Toolbar .............................................................................................................................. 93

10.2.3

Input........................... ........................... ........................... ........................... ....................... 94

10.2.4

Output ............................................................................................................................... 95

DNP3.0 Index Configuration Tool ................................................................................................................................................ 96 11.1

Overview.......................................................................................................................................................96

11.2

Operation of DNPConfig......................................................................................................................97

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12


11.3.1

Menu .......................... ........................... ........................... ........................... ....................... 98

11.3.2

Toolbar .............................................................................................................................. 99

11.3.3

Configuration Tool Box .................................................................................................. 100

11.3.4

Binary Input ..................................................................................................................... 100

11.3.5

Binary Output .................................................................................................................. 102

11.3.6

Analog Input ................................................................................................................... 103

11.3.7

Counter ............................................................................................................................ 105

Waveform Evaluation Tool............................................................................................................................................................ 107 12.1

Overview.................................................................................................................................................... 107

12.2

Operation of EvalTool ........................................................................................................................ 108

12.2.1

Menu ................................................................................................................................ 109

12.2.2

110 Toolbar .............................................................................................................................

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1.

1.1.


OVERVIEW

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 re-activate the faulted section. In case of temporary fault, the fault can be removed by itself according to highspeed 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.

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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) Batter Test External Trip and Close By contact input(Optional) Enable or disable reclosing, protection and Ground function

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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

Status Monitoring 10 Contact Inputs Open Line Detection Fault Indication Recloser, Protection, Ground Protection, Switch Open/Closed Over Voltage, Under Voltage, Under Frequency Handle Locked Gas Pressure Low External AC Power Loss Battery Discharged Enclosure Door Open Spare (3 Points : Optionally external trip and close command)

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Event Recording Event recording with time-stamp I/O,

Functional,

System,

Fault

Current,

Demand

Daily Max Current & Power Waveform Recording 8 Fault Waveforms 8 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 DNP3.0 over TCP/IP SCADA Port IEC60870-5-101 IEC60870-5-104 Maintenance Port

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Modbus-RTU

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Current

&

Power,

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2.


TECHNICAL DATA

2.1.1.

DIGITAL PROCESSOR

2.1.2

DUAL PROCESSOR ARCHITECTURE



32-bit RISC type micro-controller with on-chip flash program memory



32-bit floating-point Digital Signal Processor



Dual-Port Memory for communication between two processors



Data Memoty(SRAM)



Non-volatile Memory(1Mbytes) for storing events and parameters



Flash Mamory for stroring fault and PQM Waveforms



Real Time Clock

2.1.2ANALOG/DIGITAL CONVERSION



16-bit A/D Converter



Sampling rate : 128 samples/cycle



Anti-aliasing analog filter



One gain channel for each current input : effective 16-bit resolution for current measurements

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2.1.3.

2.1.4.


DSP 

Correction of analog input error



Fast Fourier Transform : phasor calculation



Electric quantities calculation & Fault Decision

CPU 

Status monitoring & Control Command



Local Human-Machine Interface



Event Recording



Remote Communication(DNP3.0, IEC60870-5-101 and IEC60870-5-104)



Self Diagnosis

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2.1.5.


FUNCTIONAL BLOCK DIAGRAM

Figure 2-1 Functional Block Diagram

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

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Dielectric withstand Impulse voltage


IEC 60255-5, 2kV IEC 60255-5, 6kV for current input circuit IEC 60255-5, 4kV for voltage, power input & Contacts I/O Ω

Insulation resistance

IEC 60255-5, >500M

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

2.3.

(DC500V)

INPUTS/OUTPUTS

Binary Contacts Input : 10 Points

DC 24V Baised 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

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Binary Contacts Output : 6 Points Pulse width of output is variable Signal & Contact rating DC24V Aux. Relay Contact Contact Relay : Switch Open, Close, Battery Test, Spare PhotoMOS Relay : Switch Open, Close for



Contact Relay Rating

Rated Current

16A

Rated Voltage/Max. Breaking Voltage AC

250Vac/440Vac

Max. Breaking Capacity AC

4,000VA

Make Current (Max. 4s at duty cycle 10%)

30A

Dielctring Strength



Coil-Contacts

5,000Vrms

Open Contact Circuit

1,000Vrms

Mechnical Life

> 30 x 106 operations

Operate Time

typical 7ms

PhotoMOS Relay Rating

Rated Load Current

120mA

Rated Load Voltage

350Vac

I/O isolation Voltage

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

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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

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

±0.5%

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, V0LS,

True RMS

Va, Vb, Vc, Vr, Vs, Vt

Phase Angle Difference(°)

∠Va - ∠Vr

Reading Range

0.1~26kV

Accuracy

±0.5%

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2.4.3.


POWER

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)


Reading Range

-32767~32767

Accuracy

±1%

2.4.4.

POWER FACTOR

A-Phase, B-Phase, C-Phase, 3-Phase Total Lead/Lag Display Reading Range

0~1.0

Accuracy

±2%

2.4.5.

FREQUENCY

Reading Range

45 ~ 55Hz (System Frequency : 50Hz) 55 ~ 65Hz (System Frequency : 60Hz) ±0.02%

Accuracy

2.4.6.

ENERGY

Positive kWh


Negative kWh


Capacitive Positive kVARh


Capacitive Negative kVARh


Inductive Positive kVARh


Inductive Negative kVARh


Reading Range

0~65535(Rollover)

Accuracy

±2%

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)

st 2nd~31 Harmonic RMS(A, kV)

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I

a, Ib, Ic,

Va, Vb, Vc

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2.4.8.


DEMAND CURRENT AND POWER

Configurable Demand Interval st 2nd~31 Harmonic

RMS(A, kV)

5, 10, 15min (Default 15min) I

a, Ib, Ic,

Pa, Pb, Pc, P3ph, Qa, Qb, Qc, Q3ph

Daily Max Current and Power are Stored

2.5.

COMMUNICATION

2.5.1.

PHYSICAL LAYER

2.5.1.1

RS232C

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

Suppots Modam Control

CTS, DCD Signal Timeout Configurable RTS Off-delay Configurable

Optical Isolation ESD, Transient Noise Protection

2.5.1.2 RS232C/RS485C RS232C Mode

Rx(2), Tx(3), GND(4), GND(5)CTS(8),

RS485C Mode

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

2.5.2.

PROTOCOL FOR SCADA

2.5.2.1

DNP3.0

10/100 Base-T

①

Support DNP3.0 Subset Level 3

②

Class of each point is settable(Using DNP3.0 Index Configuration Tool)

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③

Supports multi-frame transmission(multi-frame interval is configurable)

④

Enable/Disable unsolicited message class

⑤

Supports file transfer functionfor 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(254), Analog Input(127), Counter(19)

⑧

Supports direct operate or select befor operate(SBO) for control output

⑨

Supports report by exception for analog values

⑩

Protocol frame monitorwas built in FTU(Using data terminal on maintenance connector)

2.5.2.2

IEC60870-5-101

IEC 60870-5-101 is primarily used with relatively slow transmission media on the asynchronous V.24 interface. The standard promises baud rates of up to 9600 bit/s, with much higher baud rates (<115200 bit/s) actually being used. X.24/X.27 interfaces with baud rates up to 64000 bit/s, also part of the standard's description, could not establish themselves and are rarely used.

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 connectionoriented secure data transmission.

2.6. 2.6.1.

RECORDING 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

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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 fuction 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

1023

System Events

Setting change, Reset, Self Dignosis

255

Fault I Events

Latest fault current, phase and time

255

PQM Events

Operated status of PQM Function

255

Each phase daily average load current, active power

1023

Demand I,P,Q Events

and reactive powe with time Max. I,P,Q Events

Each phase daily Peak load current, active power and

1023

reactive powe with time

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 fuction follows the COMTRADE file format rule.

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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.

Figure 3-1 Front Panel Drawing of FTU

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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

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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

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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.

Figure 4-1 Front Panel Sheet of FTU-R200

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4.1. 4.1.1.


BUTTON & LED DESCRIPTION LCD DISPLAY

4 lines * 20 characters LCD is used and through MENU/UP/DOWN/ENTER buttons, operators can survey all data and corrent set values.

4.1.2.

FTU STATUS

These LED’s indicate status of FTU-R200.

4.1.3.

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)

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 femail-type connector. RS232C

4.1.5.

Rx(2), Tx(3), GND(5), MODE(9)

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

SCADA Tx

Transmitting communication data

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SCADA RTS

Data transmission request

Protection Rx

Communication data are received from another FTU by CAN communication.

Protection Tx

Transmitting communication data to another FTU by CAN communication.

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 LED’s indicate if the lines to source side and load side are activated or deactivated. LED’s are on, when the line voltage goes up the set ‘Voltage ON Level’ and LED’s are off, when the voltage goes down the set ‘Voltage OFF Level’. Under Voltage LED’s indicate if the voltage reaches under the setting value.

Sync.Fail LED is on, when the phase angle difference between source-side voltage (Va) and loadside voltage (Vr) is over the setting value. In this case, Close control command should be inhibited. Fault Indicator LED’s on, when a fault related to each faulted phase occurs. For earth fault of non-gronded networks, SEF LED is on. Reclose Ready LED is on, when the reclosing action is normally operated. This represents the normal stand-by status for reclosing action.

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Reclose Progress LED is indicates the status that reclosing action is normally processed according to the preset tripping and reclosing operation sequences. Reclose Lockout LED is on, when the reclosing action is locked out to open according to the operation sequences or the Recloser is opened by the manual control command.

4.1.9.

RECLOSE/PROTECTION/GROUND ENABLE BUTTONS AND LEDS

Push the enable buttons and makes the respective LED’s on to fulfill the Reclosing and Protection functions. These buttons are toggled between Enable and Disable. RECLOSE ENABLE button enables or disables the Reclosing Function. In disable mode, the Recloser is locked out right the 1st trip. PROTECTION ENABLE button enables or disables Phase Fault Detection and Earth Fault Detection Functions, simultaneously. GROUND ENABLE button enables or disables Earth Fault Detection Function only.

4.1.10.

REMOTE/CONTROL LOCK 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. CONTROL LOCK button enables or disables the Recloser switching operation. If Control Lock LED is on, Recloser switch is not operated.

4.1.11.

SELECT/OPEN/CLOSE BUTTONS AND LEDS

These buttons are used to locally control (OPEN/CLOSE) the Recloser. Before local control command, check first if the control position is LOCAL. SELECT button is a two-phase safety & confirmation check machanism, and this concept is similar to SBO ( Select Before Operate) in communication protocol. To manually and locally control the Recloser, SELECT button shuld be

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pushed down to make the corresponding LED on, and this SELECT function can be expanded to the scheme of Multiple Recloser Control in the future. 

SELECT → CLOSE Push this button to control the Recloser manually to be closed. After closing, normal fault detection functions are re-performed. In case that Cold Load Pickup function is off or the load current is below the Cold Load Pickup Level, normal Phase & Ground Fault Detection is functined. SELECT→OPEN



Manual open control opens the Recloser and makes the switch locked out to open.

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 

To toggle between Main Menu Display from Initial Display



To come back to Parent Menu from Child Menu



Be

careful,

because

all

the

set

value

changes

are

canceled

when this button is pushed down during the change of set values ENTER



To select and enter into each menu item



To enter the changed set value and configuration



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)



After changing the set values, be sure to save the changed values in the Set Value Change Save Menu.

UP



To move up the cursor in the menu tree



To increment the set values



The set values are rolled up and UP button at the highest value goes to the lowest value

DOWN



To move down the cursor in the menu tree



To decrement the set values



The set values are rolled down and DOWN button at the lowest value goes to the highest value

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4.2.1.


LCD MENU

Figure 4-2 LCD Menu Tree Diagram of FTU-R200

4.2.1.1 INITIAL DISPLAY [Initial Display] shows up the reclosing status.

f or

D AS>

S e que n c e

:

0

R/ C

:

CL O S E

S t a t us [

H O ME

[ HO ]

]

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].

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I a : 00 0 0 0 A

0 0 . 0 / 0 0 . 0

I b : 0 0 00 0A

00 . 0/

I c : 00 0 0 0 A

00 . 0

0 0 . 0 / 0 0 . 0

I n : 000 0 0 A

RS T >

Figure 4-4 Current / Voltage Measurement Display Reclosing Sequence

0, 1, 2, 3 and 4

Total Reclosing Shot 3 Times

0[HO], 1~3[SR], 4[LO] 

HO



SR

Home Sequence Running



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)

Diagnosis Fail

If diagnosis failure happens, [FAIL] message will appear in the right side of [HOME] or will change into .

4.2.1.2

MAIN MENU DISPLAY

[ MA I N

M E NU

]

1. F unct

i on

Set

2 . Conf

i gur

at

t i ng i on

3 . Di s p l a y 4 . E v e nt

L i s 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.

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Main Menus

Sub Items

Function Setting

Group1, Group2, Group3, Group4, Group Setting

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

[ Set t i n g

Me n u ]

1. G r o u p 1 2. G r o u p 2 3. G r o u p 3 4. G r o u p 4 5 . Gr ou p

S e t t i ng

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. 

CAUTION: Be careful not to push down MENU buttons repeatedly! Then, the newly changed set values are neither saved nor applied.

Save

Ch a ng e d Yes

/

S e t

?

No

Figure 4-7 Set Value Change Save Display

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Se t t i ng

Savi

ng !

Figure 4-8 ENTER to Yes

[

MA I N

>1 . F u nc

M E NU

t i on

2 . Co nf

i gur

]

S e t t i ng a t i on

3 . Di s p l a y Figure 4-9 ENTER to No

4.2.1.4

CONFIGURATION

[ C ONF I G

M E NU

]

1 . I / O 2 . C om m un i c a t i on 3. E ve n t 4 . 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. 

CAUTION: Be careful not to push down MENU buttons repeatedly! Then, the newly changed set values are neither saved nor applied.

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4.2.1.5


DISPLAY

[

DI S P L A Y

M E NU ]

1 .Me a s u r e m e n t s 2. St a t

u s

3. C ou n t 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 VE N T 1 . I /O

L I S T

]

E v e n t s

2 . Fu n c

t i o n e

3 . S y s t e m ev 4 . F aul

s s

t s

ev

ent

5 . De m a nd

I

e v e nt

6 . De m a nd 7 . De m a n d

P e v e nt s Q e v e n t s

8 . Max

t s

ven

e nt

I

ev

9 . Ma x .

.

P

e v e nt

ent

s

10. Ma x .

Q e v e nt

s

s

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

1023

System Events

Setting change, Reset, Self Dignosis

255

Fault I Events

Latest fault current, phase and time

255

Demand I,P,Q Events

Each phase daily average load current, active power

1023

and reactive powe with time Max. I,P,Q Events

Each phase daily Peak load current, active power and reactive powe with time

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5.


PROTECTION FUNCTIONS

5.1.

FAULT DETECTION

FTU detects the Phase & 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. And high current trip element can be used for instantaneous trip. It is definite time characteristics. During cold-load condition, pickup multiplied by cold-load multiplier. During the cold-load condition, time-delayed curve is applied instead of fast curve. This function can be enabled or disabled by cold-load multiplier. Earth fault detection function can be enabled or disabled by ‘Ground Protection Enable’. Phase Fault

Earth Fault Step

Range

Def.

Range

Unit

Def.

Pickup Current

10~900

400

5~900

60

Inrush Block

NO/YES

YES

NO/YES

YES

1~58

1-A

1~58

2-B

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

0.00~1.00

0.00

0.00~1.00

0.00

0.01

sec

RDMT/RIDMT

RDMT

RDMT/RIDMT

RDMT

0.00~100.00

0.00

0.00~100.00

0.00

1

A

Fast Operation Time Curve Type

Min. Response Time Reset Type Reset Definite Time

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Phase Fault Range

Earth Fault Def.

Range

Step

Unit

Def.

Delayed Operation Time Curve Type

1~58

20-1

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

0.00~1.00

0.00

0.00~1.00

0.00

0.01

sec

RDMT/RIDMT

RDMT

RDMT/RIDMT

RDMT

0.00~100.00

0.00

0.00~100.00

0.00

Time Reset Type

RDMT(Definite Time) RIDMT(Inverse Time)

Reset Definite

0.01

sec

Time

5.1.1

Definite Time Protection

Definite Time is an alternative to Inverse Time Protection. It works by tripping the recloser at a fixed time after pick-up. Range

Def.

Step

Unit

Comment

Phase Detection Active

OFF/ON

OFF

Pickup Current

50~10000

1000

1

A

Detection Time

0.00~1.00

0.00

0.01

sec

Earth Detection Active

OFF/ON

OFF

Pickup Current

50~10000

1000

1

A

Detection Time

0.00~1.00

0.00

0.01

sec

5.1.2

High Current Trip (HCT)

Very high valued current can cause serious damage to the Recloser and the resultant fault spread-out, therefore HCT element should operate faster than Instantaneous or Time-Delayed TC curve’s operation time and its priority must be higher than the normal auto-reclosing sequence.

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HCT can be configured up to 4 times for phase fault and earth fault, respectively. HCT Count setting value ‘0’ means HCT element disabled. Range

Def.

Step

Unit

0~4

0

1

Pickup Current

50~10000

2000

1

A

Detection Time

0.00~1.00

0.00

0.01

sec

Comment

Phase Detection Operation Count

‘0' means disable.

Earth Detection Operation Count

0~4

0

1

Pickup Current

50~10000

2000

1

A

Detection Time

0.00~1.00

0.00

0.01

sec

5.1.3

‘0' means disable.

Single Shot Operation

In Single Shot Operation is used to provide an appropriate protection curve when non-reclosing operation is required, for example, when closing onto a fault. In Single Shot Operation the controller goes directly to lockout after one trip and will not autoreclosing.

Single Shot Time

5.1.4

Range

Def.

Step

Unit

0~180

10

1

sec

Comment

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 characteristrics, 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 follwing parameters are related to change and editing of TC curve’s characteristics. 

Time Multiplier

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

Time Adder



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

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

Moderately Inverse(IM),Very Inverse(IV),Extremely Inverse(IE),

Curve

Long-time Inverse(U8),Short-time Inverse(U2)

KEPCO Standard Curve

N1,N2,N3,N4

User Customized Curve

C1,C2,C3,C4

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


IEC, ANSI/IEEE, US STANDARD TC CURVE EQUATION T = TDM

{ / (M - 1) + }

TRESET = TDM

{ / (M - 1)}

T : Operate Time, TDM : Multiplier Setting, TRESET : Reset Time

Curve Type Standard Inverse(NI)

α

Standard IEC

β

γ

τ

0.14

0.02

-

-

Very Inverse(VI)

13.5

1

-

-

Extremely Inverse(EI)

80.0

2

-

-

Short-time Inverse(SI)

0.05

0.04

-

-

120

1

-

-

19.61

2

0.491

21.6

Long-time Inverse(LI) Very Inverse(IV)

IEEE

Extremely Inverse(IE)

28.2

2

0.1215

29.1

Moderately Inverse(IM)

0.0515

0.02

0.114

4.85

0.2394 5.95

0.02 2

0.01694 0.18

2.261 5.95

Short-time Inverse(U2) Long-time Inverse(U8)

5.1.5

CO2 CO8

EXAMPLE OF TC CURVE EDITING

3-parameters are applied in the follwing order. The values in the parenthesis are examples. 

Time Multiplier : 1.5



Time Adder : 0.03



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

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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 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

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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 coldload, 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

Operation Count

1~4

4

1

Instantaneous Count

0~4

2

1

Unit

Comment

Phase

Earth Operation Count

1~4

4

1

Instantaneous Count

0~4

2

1

Phase/ Earth Reclosing Reclose Interval 1st

0.5~180.0

Reclose Interval 2nd

1~180

Reclose Interval 3rd

1~180

Reset Time

0.6

0.1

sec

2

1

sec

15

1

sec

3~180

30

1

1~4

4

1

sec

SEF Reclosing Operation Count Reclose Interval 1

st

0.5~180.0

Reclose Interval 2nd

1~180

Reclose Interval 3rd

1~180

Reset Time

0.6

3~180

0.1

sec

2

1

sec

15

1

sec

30

1

sec

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.

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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

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5.1.7


Sequence Coodination

In case that there are over 2 Reclosers which operate in serial connections, Sequence Coordination function prevents unnecessary trip of source-side Recloser by instantaneous element due to load-side fault. When this function is set to on and the fault is restored to normal state by load-side Recloser during source-side Recloser’s time-delayed operation, source-side Recloser only increments the reclosing counts without tripping. However, source-side Recloser performs tripping at the last reclosing count. If the Reclosing function is disabled, Sequence Coordination function is no longer carried out.

Seq. Coordination Active

Range

Def.

OFF/ON

OFF

Step

Unit

Comment

For Sequence Coordination, the following setting items should be issued and checked precisely between serially connected Reclosers. 

Identical Protection Characteristics such as TC Curves, Total Operation Count, Instantaneous Operation Count



Identical Reclosing Interval(Dead Time)



Source-side TC Curve Time Delay Over 100msec than Load-side



Source-side Reset Time longer than Load-side longest Reclosing Interval (to Prevent Source-side Recloser reset during Load-side Reclosing action)

Figure 5-5 Operation of Sequence Coordination

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5. 2


Cold Load Pickup

Cold Load Pickup is the phenomenon that takes place when a distribution circuit is re-energized following an extended outage of that circuit. Cold load pickup is a composite of two conditions: inrush and loss of load diversity. The magnitude of cold load pickup current is a combination of non-diverse cyclic load current, continuously operating load current, transformer magnetizing current, capacitor inrush current, etc. The combination can result in current levels that are significantly higher than normal peak load levels. Cold load pickup current can be high enough to cause instantaneous overcurrent and/or time overcurrent relays to operate. Cold load pickup is primarily an overcurrent condition. If degraded voltage is also a concern, then the application of voltage sensitive relays should also be considered.

Figure 5-6 Cold Load Pickup Current Shape In Cold Load Pickup mode, without changing operational characteristics, pickup level is changed by the times of Cold Load Multiplier (0~10) and the characteristics of time-delayed element operate even if the setting is in the Instantaneous element. If the transient current goes down and retrains below the pickup level within Cold Load Duration, then the normal sequence mode is restored after Cold Load Restore Time. The Cold Load Restore Time is fixed value of 30msec. These setting exist for both phase fault and earth fault separately, and the value ‘0’ of Cold Load Multiplier means Cold Load Pickup Function disabled. Normaly Reclosing Sequence mode is applied.

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Range

Def.

Step

0~10

2

1

0.00~60.00

3.00

0.01

0~10

2

1

0.00~60.00

3.00

0.01

Unit

Comment

Phase Detection Pickup Multiplier Duration Time

‘0' means disable. sec

Earth Detection Pickup Multiplier Duration Time

5. 3

‘0' means disable. sec

S ENSITIVE E ARTH F AULT ( SE F ) DETECTION

On the non-grounded network, it is hard to detect fault current because ground current of nongrounded network is much low. Therefore, FTU-R200 is designed to measure zero-sequence values from either external core Balanced Current Transformer (or ZCT) or Residual Connection of 3 Phase Current Transformers to detect earth fault in the non-grounded 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

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Range

Def.

Step

Unit

Pickup Current(3I0)

2~20

5

1

A

Pickup Voltage(-3V0)

10~80

30

1

%

90

15

Degree

Max. Torque Angle

0~345

Detection Time

0.1~30.0

1.0

Inrush Block

NO/YES

YES

OFF/ALARM/TRIP

OFF

Function In Use

5. 4

0.1

Comment

Rated Phase Voltage Leading

sec

DIRECTIONAL BLOCKING

Directional Blocking is a protection feature that restricts tripping on faults to a designated side of the recloser. It prevents nuisance tripping if particular network conditions are causing ‘False’ earth faults. In radial systems Directional Blocking prevents nuisance tripping by blocking faults in the reverse direction and only responding to faults in the foward direction. Protect for faults in the forward and reverse direction. A forward fault may use a different timecurrent curve and setting to a reverse fault (i.e. these are individually selectable). Both the forward protection and reverse protection are operating at the same time. This is an additional protection feature. Range

Def.

OFF/FWD/REV/ALL

FWD

Step

Unit

Phase Detection Trip Direction Threshold 3V1 Threshold 3I1 Max. 3I1 Torque Angle

0~100

20

1

%

0~100

20

1

%

0~355

60

5

Degree

Earth Detection Trip Direction Threshold -3V0 3I0 Threshold Max. 3I0 Torque Angle

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OFF/FWD/REV/ALL 0~100

FWD

20

1

0~100 0~355

%

20 60

1 5

% Degree

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Comment

ISO 9001 certified

5. 5


INRUSH RESTRAINTS

Inrush Restraint works by raising the phase and earth currents for a short period of time to allow the inrush current to subside. Inrush current is an over-current higher than pickup current level, which is mainly caused by transformer’s excitation current at closing action. To distinguish inrush current from load current, 2nd harmonics percentage is adopted as a criterion. When, in the setting, ‘Fault Detection-Inrush Block’ is set to ‘Yes’ and ‘Fault Detection-Inrush Detection-Function In Use’ is set to ‘ON’, inrush current over pickup level is considered as normal load current and reclosing sequence is not processed. This Function can be used to detect magnetizing inrush condition by comparing 2nd harmonic component to fundamental frequency component of current. Range Harmonic 2nd

20

Step

1

%

Detection Time

0.02~1.00

0.02

0.01

Function In Use

OFF/ON

ON

5. 6

5~50

Def.

Unit

Comment

sec

OPEN LINE DETECTION (LOSS OF PHASE)

Open Line is detected by Under Voltage characteristics at unbalanced condition. 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 ‘Vol 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

%

0.1

sec

Delay Time

0.1~30.0

0.4

Function In Use

OFF/ON

ON

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5. 7


PHASE SYNC. CHECK

Range

Def.

Step

Unit

Phase Difference Dalay Time

5~60 0.1~30.0

30 0.1

1 0.1

Degree sec

Function In Use

OFF/ON

ON

5. 8

Comment

UNDER VOLTAGE PROTECTION

As the supplied voltage to load lowers down, there occur the weakness of illumination intensity and shortening of life span for lighting load, and the damage to motors because of the overcurrent flow. To cope with this situation of damages to equipment, under-voltage protection (UV) is used. UV of FTU supports the delay time element. Furthermore, UV can be used to generate only alarm signal to operator instead of trip signal to Recloser.

Figure 5-8 Functional Diagram for Under Voltage Protection Range

Def.

Step

Pickup Level

0.30~0.95

0.80

0.01

PU

Delay Time

0.0~180.0

1.0

0.1

sec

OFF/ARAMP/TRIP

OFF

Function In Use

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Unit

Comment

ISO 9001 certified

5. 9


OVER VOLTAGE PROTECTION

On the other hand, as the supplied voltage goes up behind the regular load voltage, there occur some problems of equipment deterioration, insulation breakdown, equipment life span shortening, etc. Over Voltage Protection (OV) manages this situation. OV of FTU supports the delay time element. OV also can be used to generate only alarm signal to operator instead of trip signal to Recloser.

Figure 5-9 Functional Diagram for Over Voltage Function

Range

Def.

Step

Pickup Level

1.05~1.50

1.20

0.01

PU

Delay Time

0.0~180.0

1.0

0.1

sec

OFF/ARAMP/TRIP

OFF

Function In Use

Unit

Comment

5.10 UNDER FREQUENCY PROTECTION Under Frequency protection (UF) element is used into expenditure that detect under frequency and separated load or generator. Under Frequency demands for power increase or occurs in control failure of generator. Under Frequency protection element acts in case of voltage more than ‘Voltage OFF Level’ is approved to Voltage A-Phase. UF of FTU supports the delay time element. Furthermore, UV can be used to generate only alarm signal to operator instead of trip signal to Recloser.

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Pickup Dalay Time Function In Use


Range

Def.

Step

Unit

47.00~59.98

49.80

0.01

Hz

0.03~10.00

0.10

0.01

sec

OFF/ARAMP/TRIP

OFF

Comment

5.11 MULTIPLE PROTECTION GROUPS The FTU-R200 supports up to 4 Protection Groups, each of which can be confiqured with completely separate protection characteristics with different inverse time curves and setting currents. The number of protection group avaliable to the operator can be configured. And FTU-R200 support Automatic Protection Group Selection. Automatic Protection Group Selection is used to change the protection group depending on the direction of power flow. This allows the Recloser to be correctly graded with devices downstream regardless of the power flow direction.

Default Group ADGS(Automatic Default Group Selection) Function Reverse Group

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Range

Def.

Step

1~4

1

1

OFF/ON

OFF

1~4

1

50 / 111

1

Unit

ISO 9001 certified


6

CONFIGURATION SETTING

6. 1

I/O CONFIGURATION

6.1.1

AC RATING

Range

Def.

Step

Unit

Line Configuration

Y-G/DELTA

Y-G

Systme Frequency

50/60

Rated Voltage (L-L) Reference Voltage (L-N)

50

40

Hz

1000~30000

22900

10

V

Phase to Phase

1000~30000

13200

10

V

Phase to Earth

Reference Phase

A/B/C

A

CB Operating Time

0~35

1

1

ms

1

CT Ratio CT Direction NCT Ratio

1~5000

1000

FWD/REV

FWD

1.0~5000.0

133.3

NCT Direction

FWD/REV

FWD

Phase Rotation

A-B-C/A-C-B

A-B-C

Sample Record Frequency

16/32/64/128

128



Comment

0.1

SWITCH INSTALLATION

The FTU-R200 provides a function to set ‘Reference Phase’ and the ‘CT Direction’ according to the switch installation position and the current flowing direction. Figure 6-1 shows the general and ‘assumed-default’ case of switch installation, in which the distribution lines with current A, B, C are connected to the phase A, B, C terminals of the switch, and the current is flowing A/B/C to R/S/T of the switch. In this case, the ‘Referece Phase’ setting value should ‘A’, which means that the phase of current flowing into the phase A terminal of the switch is ‘A’, In addition, the ‘CT Direction’ setting value should be ‘Foward’ , which means that the current is flowing in the direction from the phase A/B/C terminals to the R/S/T terminals of the switch.

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Figure 6-1 Switch installation position and the current flowing direction – Case 1 Figure 6-2 shows another case of switch installation, in which the distriburion lines with current A, B, C are connected to the phase A, B, C terminals of the switch, and the current is flowing from R/S/T to A/B/C of the switch. In this case, the ‘Referece Phase’ setting value should ‘A’ , which means that the phase of current flowing into the phase A terminal of the switch is ‘A’, In addition, the ‘CT Direction’ setting value should be ‘Reverse’ , which means that the current is flowing in the direction from the phase R/S/T terminals to the A/B/C terminals of the switch.

Figure 6-2 Switch installation position and the current flowing direction – Case 2

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Figure 6-3 shows another case of switch installation, in which the distriburion lines with current A, B, C are connected to the phase C, B, A terminals of the switch, and the current is flowing from R/S/T to A/B/C of the switch. In this case, the ‘Referece Phase’ setting value should ‘C’ , which means that the phase of current flowing into the phase A terminal of the switch is ‘C’, In addition, the ‘CT Direction’ setting value should be ‘Reverse’ , which means that the current is flowing in the direction from the phase R/S/T terminals to the A/B/C terminals of the switch.

Figure 6-3 Switch installation position and the current flowing direction – Case 3 Figure 6-4 shows another case of switch installation, in which the distriburion lines with current A, B, C are connected to the phase C, B, A terminals of the switch, and the current is flowing from A/B/C to R/S/T of the switch. In this case, the ‘Referece Phase’ setting value should ‘C’ , which means that the phase of current flowing into the phase A terminal of the switch is ‘C’, In addition, the ‘CT Direction’ setting value should be ‘Forward’ , which means that the current is flowing in the direction from the phase A/B/C terminals to the R/S/T terminals of the switch.

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Figure 66-4 Switch installation position and the current flowing direction – Case 4

6.1.2

DEMAND SETTING

The FTU calculates and stores average of currents and active, reactive powers during the demand interval, which is configurable as 5, 10 or 15 minutes. The buffer has 1023 demands. Also FTU stores daily peak demand up to 1023.

Block Interval Roll Interval

6.1.3

Range

Def.

15/30/60

15

1/5/15/30/60

15

Step

Unit

Comment

WAVE TRIGGER

Sample Record Frequency Cycle Pre-1st Cycle Post-2nd nd Pre-2 Trigger

Cycle

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Range

Def.

16/32/64/128

128

Step

Unit

1~5

2

1

Cycle

1~5

2

1

Cycle

1~10

10

1

Cycle

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6.1.4


CLOSE INTERLOCK Range

Def.

Live Load

NO/YES

YES

Sync. Fail

NO/YES

YES

Range

Def.

6.1.5

Unit

Comment

Step

Unit

Comment

FI RESET SELECT

FI Reset

6.1.6

Step

MANUAL/AUTO

MANUAL

VOLTAGE DISPLAY

The controller supports two voltage display of LCD.

Voltage Display

Range

Def.

L-N/L-L

L-N

Step

Unit

Comment L-N : Phase to Earth L-L : Phase to Phase

6. 2 6.2.1

POWER QUALITY MEASUREMENT FUNCION VOLTAGE & CURRENT UNBALANCE

Voltage unbalance (or imbalance) is a condition in which the maximum deviation from the average of the three-phase voltages or currents, divided by the average of the three-phase voltage or currents, expressed in percentage. Voltage unbalance can be the result of blown fuses in one phase of a three-phase capacitor bank. Severe voltage unbalance greater than 5% can cause damage to sensitive equipments.

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Range

Def.

Step

Unit

Comment

Voltage Unbalance 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

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 cycle. A 10% sag is considered an event during which the RMS voltage decreased by 10% to 0.9 pu. Voltage sags are widely recorgnized as among the most common and inportant aspects of power quality problems affecting industrial and commercial customers. They are particularly troublesome. Since they occur randomly and are difficult to predict. Volatge 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 occuring on high-volatage transmission systems is a lightning strike. When there is a 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

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sags would be system shutdown or reduce effciency 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

Detection Level

0.50~0.99

0.90

0.01

PU

Detection Time

0.5~10.0

2.0

0.5

Cycle

6.2.2.2

Unit

Comment

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 inpedance, 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

6.2.2.3

Comment

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 cycle. 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

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be irregular when due to equipment malfuctions 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

Detection Level

0.10~0.49

0.10

0.01

PU

Detection Time

0.5~10.0

2.0

0.5

Cycle

6.2.3

Unit

Comment

VOLTAGE & CURRENT THD ALARM

The Total Harmonic Distortion, or THD, of a sigmal 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

6. 3

COMMUNICATION

6.3.1

PORT PARAMETERS

6.3.1.1

SERIAL PORT

Speed Slave Adderss Protocol Port

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Range

Def.

1200/2400/4800/9600/19200

1200

1~65534

1

DNP/IEC101/IEC104

DNP

RS232C/RS485

RS232C

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Step

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Unit

ISO 9001 certified

6.3.1.2

DIAL UP

Dial-up Mode Phone Number Auto Hang-up Time

6.3.1.3


Range

Def.

Step

Unit

DISABLE/ENABLE

DISABLE

20 Digit 0~255

5

1 1

sec

Range

Def.

Step

Unit

-

0.0.0.0

TCP/IP PORT

IP Address Subnet Mask

-

255.255.255.0

Gateway

-

0.0.0.0

DNP Port

0~65535

20000

1

IEC Port

0~65535

2404

1

Range

Def.

Step

Unit

2-WIRE/4-WIRE

4-WIRE

10~500

50

10

ms

6.3.1.4

MODEM CONTROL

Line RTS Off Delay CTS Timeout

1~255

2

1

sec

DCD Timeout

0.1~30.0

5.0

0.1

sec

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6.3.2


DNP3.0 PARAMETERS

D/L Retries D/L Timeout D/L Confirm A/L Retries A/L Timeout Initial Unsolicited MSG

Range

Def.

Step

0~2

0

1

1~255 NO/YES/SOMETIMES

30 SOMETIMES

1

Unit

sec

0~2

1

1

1~255

40

1

sec

NO/YES

NO

Unsolicited Class 1 Delay Time

0~60

5

1

sec


0~60

5

1

sec


0~60

5

1

sec

1~255

15

1

sec

0~65534

65534

1 10

Arm Timeout Unsolicited Address Multi Frame Interval

10~500

100

Unsolicited Class 1

DISABLE/ENABLE

DISABLE

Unsolicited Class 2

DISABLE/ENABLE

DISABLE

Unsolicited Class 3

DISABLE/ENABLE

DISABLE

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ms

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6.3.3


IEC PARAMETERS Range

Def.

Step

Unit

0~60

0

1

sec

Arm Timeout Single Point Class

1~255 CLASS1/CLASS2

15 CLASS1

1

sec

Double Point Class

CLASS1/CLASS2

CLASS1

Measured Point Class

CLASS1/CLASS2

CLASS2

Link Address Size

0~2

2

1

Common Address Size

1~2

2

1

Object Address Size

1~3

2

1 1

Cyclic Period

IEC101 PARAMETERS

COT Address Size

1~2

1

NONE/CP24/CP56

CP56

NO/YES

YES

t0 Off Line Poll Period

1~255

30

1

sec

t1 Ack Period

1~255

15

1

sec

t2 SFrame Period

1~255

10

1

sec

t3 Test Period

1~255

20

1

sec

Time Marker Single NACK Control IEC104 PARAMETERS

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7

STATUS MONITORING & CONTROL

7. 1

SWITCH CONTROL


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-R200 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. 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-R200 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

7. 2

SWITCH STATUS MONITORING

FTU monitors switch open/close, gas and lock status through auxiliary contacts. FTU scans these contacts input every 5 milliseconds. Switch open/close status is determined by double binary input, normally open and closed contacts. Changes of all input status are saved as events with time tag in history buffer. For each contact input, on-delay time can be applied. It’s adjustable within 10~500ms by 5ms step.

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7. 3


BATTEY MONITORING

FTU monitors external Lead-acid battery through the control unit, which are mounted on inner back-side of control box. Battery voltage is supervised continuously during external AC supply loss. If over-discharge condition occurred, the control unit sends alarm signal 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. Also while AC supply is applied, battery test control activates this function with connecting dummy battery load during test pulse, which is configurable. The test control command can be ordered at local or remote.

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8

MEASUREMENTS

8. 1

BASIC ELECTRIC QUANTITIES

FTU has 3-phase currents and 6 voltages input. DSP digitizes these signals and calculates various electric quantities. These are basically based on fundamental frequency components. DSP use FFT (Fast Fourier Transform) algorithm to get the components. Also DSP calculates true RMS of 3phase currents and voltages which include system frequency components and 2nd~31th harmonics. Actually harmonic components over than 31th are attenuated by analog filters. Electric quantities calculated 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


Active Power


Reactive Power


Power Factor


Va-Vr Phase Angle Difference Current, Voltage Unbalance Frequency, Temporature 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.

8. 2

SEQUENCE COMPONENTS

FTU provides the sequence components of 3-phase currents and voltages. They are positive sequence current (I ) and voltage (V ), negative sequence current (I ) and voltage (V ), and zero 1

1

2

2

sequence voltage (V0) which are calculated by 3-phase phasor quantities. This information can be used to monitor imbalance of distribution line.

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8. 3


HARMONICS

FTU extracts harmonic components from 3-phase current and voltage signals by using FFT (Fast Fourier Transform). It 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 register. Units of energy are kWh, kVarh, which represent primary distribution line energy flow. The values are represented by 16-bit rollovers kWh, kVarh counters which are available at remote or local. Power calculation for energy is based on the fundamental frequency component. It’s not for billing purpose, but for load management. Proper energy accumulation needs that SCADA read energy counter with reset from FTU and accumulate it on SCADA’s local register by periods shorter than the expected rollover time of the counter.

Figure 8-1 Four-quadrant power flow directions

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8. 5


DEMAND CURRENTS AND POWER

FTU calculates and stores average of currents and active, reactive powers during the demand interval, which is configurable as 5, 10, or 15 minutes. The buffer has 1023 demands. Also FTU stores daily peak demand up to 1023.

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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-R200. For this communication, MODBUS protocol is used. It supports the follwing features. 

Setting & Configuration changes



Event & Waveform load



Measurement & Status display



Waveform File upload and convert



SCADA monitors protocol data frame between devices

Figure 9-1 Overview of FTUMans

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9. 2

OPERATION OF

9.2.1

MENU

9.2.1.1

FILE


FTUMAN

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

9.2.1.2

Closes the current file and exits the tool.

COMM Comm.Config

Opens a window for communication configuration dialog.

Comm.Connection

Starts communication with FTU-R200

Comm.Disconnection

Stops connecting with FTU-R200

Figure 9-2 Comm. Configuration Window 

Port

Select a serial Port of Laptop



Baud Rate



Retry Set up the count if it failed to connect



Timeout

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Make to the transmission medium per second of in a digitally signal

Set up the time to connect

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9.2.1.3


COMMAND 

Clock Setting

Set RTC Time of FTU-R200

Figure 9-3 Clock Setting Window



Device Time

Gets the current time per 1 second from FTU-R200.

Setting Time

The operator can set aside time.

Use System Time

The operator can use PC’s time.

Write

Write RTC time to FTU-R200

Close

Close this window

Factory

Reset to factory defaults.

Initialization

Warning: Restoring FTU-R200 to factory defaults will erase all previous setting, configuration and event .

Fiqure 9-4 Factory Initialization Message Window

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9.2.1.4


TOOLS Protocol Monitoring

Protocol monitoring command activation or deactivation.

IO Configuration

Run the IOConfig program for I/O setting. The IOConfig is explained in the Section 10.

9.2.1.5

DNP3.0

Run the DNPConfig program for DNP index configuration.

Index Configuration Waveform

The DNPConfig is explained in the Section 11. Run the EvalTool program for analysis waveform data.

Evaluation Tool

The EvalTool is explained in the Section 12.

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-R200.

9.2.1.6

HELP

The Help Menu opens a window for FTUMan’s program version and information.

9.2.2

TOOLBAR

Below the menu is a toolbar with 9 buttons.

Figure 9-5 Toolbar of FTUMan Upload

Read input or ouput data from FTU-R200.

Download

Write input or ouput data to FTU-R200.

About

Opens a window for FTUMan’s program version and information.

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9. 2 .3

ecloser controller FTU- R 00

STATU BAR

Fiq re 9-6 Status Bar

9. 2 .4

MODEL F/W

Model Name Fir ware Versio

PORT

Seriial Port Num er and Spee

MODE

Co munication Status

MONIT ORING BAR

Figure 9-7 Monitoring Bar

So e performance is finished Reads data from FTU-R200 Wir es the settin value on FTU-R200 Wh n Factory Initialization oc urs. Error of connection or operation Connect or Disconnect betwe n PC and FTU-R200 Wh n the time s et is complet d

9. 2 .5 I

FUNCTI ON AND C ONFIGURA

ION SETTI

G

Function and Configur tion windo , existing setting values of FTU-R20

can be vi wed

thr ugh ‘Upload’ button, or setting values are edited and downloaded to FTU-R200 by cli king ‘Do nload’ butt n to apply n w setting values to FTU- 200.

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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-R200. Configuration has 3 contents for I/O, PQM and communication.

Communication

seperated

3

contens, 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 9-8 Tree View for Funtion and Coufiguration 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 9-9 before the Change

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Figure 9-10 after the Change And, in event window has a following pop-up menu. In the Tree View, select ‘FUNCTION’or ‘CONFIGURATION’ or all sub contens, and press the right-click pop-up menu is avaliable. If you click ‘Upload’ Button, the setting parameters related selected contents in the tree view reads from FTU-R200. Also, if you click ‘Download’ Button, the setting

parameters

related

selected

contents in the tree view writes to FTUR200.

Figure 9-11 Pop-up Menu for Event Window

Figure 9-12 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-R200 by clicking ‘Upload’ button. Also 8 kinds of events are stored. Each event type of event can be separately uploaded from FTU-R200 and can save to CSV format file. 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 avaliable.

Figure 9-13 Pop-up Menu for Event Window Upload

Reads the selected events in the tree view.

Clear All Events

Delete all event stored.

Clear Fault Events

Delete only fault events.

Save to CSV File

Current event saves to CSV (Comma-Saperated Values file) file format.



CSV File

A Comma-Seperated Values (CSV) file is used for the digital storage of data structed in a table of lists form, where each associated item (member) in a group is in association with others also seperated by the commas of its set. Each line in the CSV file corresponds to a row in the table. Within a line, fields are seperated by commas, each field belonging to one table column. Since it is a common and simple file format, CSV files are often used for moving tabular data between two different computer programs, for example between a database program and a spreadsheet program.

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9.2.6.1


I/O EVENT

Figure 9-14 I/O Event Window 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

Occured contact points and binary status, OFF/ON/AUTO

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9.2.6.2


FUNCTION EVENT

Figure 9-15 Function Event Window Index


Date & Time


Description

Operation of protection functions.

Status

Occurred function event status, OFF/ON.

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9.2.6.3


SYSTEM EVENT

Figure 9-16 System Event Window Index


Date & 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 selfdiagnosis.

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9.2.6.4


FAULT EVENT

Figure 9-17 Fault Event Window Index


Date & Time


OC

Detecting over-current.

SEF

Detecting Sensitive Earth Fault.

UFR

Detecting Under Frequency.

DIR

Fault current direction.

Inrush

Detecting inrush restraint.

Ia, Ib, Ic, In, V0 Group

Fault current and zero-sequency voltage Current setting group

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9.2.6.5


PQM EVENT

Figure 9-18 PQM Event Window Index


Date & Time


Description

The occurance 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

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9.2.6.6


DEMAND CURRENT EVENT

Figure 9-19 Demand Current Event Window Index


Date & Time


Ia, Ib, Ic, In

Demand current of each phase and neutral.

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9.2.6.7


DEMAND POWER EVENT

Figure 9-20 Demand Power Event Window Index


Date & Time


kWa, kWb, kWc, kW3ph

3-phase total and each phase kW.

kVARa, kVARb,

3-phase total and each phase kVAR.

kVARc, kVAR3ph

9.2.6.8

DAILY MAXIMUM CURRENT EVENT

For more details, similar in section 9.2.5.6. Demand Current Event. 9.2.6.9

DAILY MAXIMUM POWER EVENT

For more details, similar in section 9.2.5.7. Demand Power Event.

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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 31 st 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 Mesurement window. The measurement value updates per 1 second. 9.2.7.1

BASIC VALUE

Operators can check the basic value like load or source volatage, current including RMS, Phase Angle and True RMS also apparent, active and reactive power. And it shows unbalance frequency, temperature and so on.

Figure 9-21 Basic Mesurement 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.

Fiqure 9-22 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.

Fiqure 9-23 Power Winodw

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9.2.7.4


ENERGY

FTU-R200 provies imported or exported energy according to conductive, inductive energy of each phase or 3-phase total.

Fiqure 9-24 Energy Window

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9.2.7.5


HARMONICS

It displays THD and each harmonics value of voltage and current. It shows from 2nd to 31st per 1 second.

Fiqure 9-25 Harmonics Window

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9.2.7.6


COUNTER

It basically shows restart, fault, PQM and THD counter and total interruption time.

Fiqure 9-26 Counter Window Restart

Show restarts time and its count.

Fault Counter

Show the total fault count of each, neutral phase and Switch Trip.

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.

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9.2.8


STATUS

In status window, all the status indications and command are displayed.

Figure 9-27 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 99-28 Commnad Window

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9.2.9


WAVEFORM

In waveform window displays Fault and PQM waveforms list stored in FTU-R200. FTU-R200 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-R200.

Figure 9-29 Waveform List Uploaded To import the waveform from FTU-R200, select a row and double click, you upload the following message window appears.

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Figure 9-30 Message Window 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 follwing window shows the progress for uploading.

Figure 9-31 Progress Window The file is stored in the COMTRADE file format by converting. The stored file is avalilable 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, selectWAVEFORM ‘ ’ and press the rightclick pop-up menu is avaliable.

Fiqure 9-32 Pop-up Menu for Waveform Window Upload

Read waveform list from FTU-R200.

Manual Trigger

Capture current waveform by manual triggerring.

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 ‘IO Config’ tool allows FTU users to custom I/O mappings.

Figure 10-1 Overview of IOConfig Tool The I/O mapping is created using the tool and saved to an IO File (*.iom). Once a valid file has been created, it is linked to the Recloser device. The IOConfig tool is intended to be used off-line only. Mappings are created, saved and linked to FTUMan while disconnected from the FTU. Once these tasks have been completed the user connects to the device and writes the new mapping into the Recloser. 

Warning: Make sure the IOConfig Tool is closed after a mapping has been edited. If the Tool is left open while the Automatic Data Retriaval feature is running it may attempt to update a mapping file that is already open in the Tool. This will either cause the read

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


operation to fail or result in a situation where the newly read file differs from the file open within the Tool.

10.2 OPERATION OF

IOCONFIG

To start the IOConfig Tool selects ‘Tools – IO Configration’ from the FTUMan menu. When you run the IOConfig Tool, main screen is displayed as show in following figure. There are two tabbed pages in the IOConfig Tool.

Figure 10-2 Main Screen of IOConfig Tool

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10.2.1


MENU

The File Menu has the following options. New


Open

Closes the current file and opens a standard window file selection dialog. An

Save

existing IO File (*.iom) can be selected and opened. 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


Exit


The Comm Menu is explained in the Section 9.2.1.2 Comm. The View Menu is explained in the Section 9.2.1.5 View. The Help Menu opens a window for IOConfig’s program version and information.

10.2.2

TOOLBAR

Below the menu is a toolbar with 9 buttons.

Figure 10-3 Toolbar of IOConfig Upload


Download


About

Opens

a

window

for

IOConfig’s program version and

information. Once you Press the Upload or Download button, the follwing window appears. This window determines the types of data read or write.

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Figure 10-4 Select Widow

10.2.3

INPUT

FTU-R200 has 10 inputs. Input is created by filling the fields on the Input tab. Each column is defined as follows.

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 Ext.Trip

To close blocked To trip using external input

Ext. Close

To close using external input Figure 10-5 Input Tab

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10.2.4


OUTPUT

FTU-R200 has 4 relay outputs and 2 photoMOS relay outs. Output is created by filling the fields on the Output tab. Eash 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.

Control Output

Select type of PhotoMOS or Contact Relay for OPEN and CLOSE.

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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 The DNPConfig tool is intended to be used off-line only. Mappings are created, saved and linked to FTUMan while disconnected from the FTU. Once these tasks have been completed the user connects to the device and writes the new mapping into the Recloser. 

Warning: Make sure the DNPConfig Tool is closed after a mapping has been edited. If the Tool is left open while the Automatic Data Retriaval feature is running it may attempt to update a mapping file that is already open in the Tool. This will either cause the read

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operation to fail or result in a situation where the newly read file differs from the file open within the Tool.

11.2 OPERATION OF

DNPCONFIG

To start the DNPConfig Tool selects ‘Tools – DNP3.0 Index Configration’ from the FTUMan menu. When you run the DNPConfig Tool, main screen is displayed as show in following figure. There are 4 tabbed pages, Binaty Input, Binary Output, Analog Input and Counter, in the DNPConfig Tool.

Figure 11-2 Main Screen of DNPConfig

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The DNPConfig tool allows the user to build custom mapplings to suit their own application. Points are added by selecting a row inPID Columns on one of the tabbed pages then double clicking point from the Configuration Tool Box or entering index number in configuration tool box defined. Points are deleted by selecting a row and pressing ‘Delete’ on the keyboard or entering ‘0’. The PID Number ‘0’ means is not used anymore. You can choose to either shift all the rows below up one, or leave the entire row blank. The DNPConfig tool allows the following. 

Up to 128 Binary Input



Up to 32 Binary Output



Up to 512 Analog Input



Up to 128 Counter



11.3.1

MENU

The File Menu has the following options. New


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


Exit


The Comm Menu is explained in the Section 9.2.1.2 Comm. The View Menu is explained in the Section 9.2.1.5 View. The Help Menu opens a window for DNPConfig’s program version and information.

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TOOLBAR

Figure 11-3 Toolbar of DNPConfig Tool

Shows or hides a window the DNP3.0 Configuration tool box.

Upload


Download


About

Opens a window for DNPConfig’s program version and information.

Pressing Upload or Download button, the follwing window appears. This window determines the types of data read or write.

Figure 11-4 Select Widow

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CONFIGURATION TOOL BOX

The configutation tool box panel is launched by clicking the Tool button.

Figure 11-5 Configuration Tool Box The toolbox contains every available point for FTU-R200. 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.

11.3.4

BINARY INPUT

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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

PID

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Specifies number as defiend in the configuration tool box.

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Recloser controller FTU- R200 The PID Number’s ‘0’ meaning is not used anymore. Range : 0 to 59

Name

The name of the points as defiend in the configuration tool box. This field can be changed in two ways: 

Selecting the cell then double clicking a point in the configuration tool box.



Class 0~3

Entering PID number as defiend in 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)

Invert

Specifies whether the point will be inverted. If the point is inverted it will be transmitted when the condition is false than true.



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.

11.3.5

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.

BINARY OUTPUT

Binary Outputs are used to perform operations on the Recloser device and change setting.

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Figure 11-7 Binary Output Tab Index


PID

Specifies number as defiend in the configuration tool box. The PID Number ‘0’ means is not used anymore. Range : 0 to 10

Name





11.3.6


ANALOG INPUT

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Analog Points are used to transmit analog data such as line currents, voltages and contact life. Analog intputs are created by adding points as required, then modifying the parameters from defaults if necessary.

Figure 11-8 Analog Input Tab

Index


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Recloser controller FTU- R200 Specifies number as defiend in the configuration tool box. The PID Number ‘0’ means is not used anymore. Range : 0 to 331

Name





Class 0~3



COS


Scale

The scale is used to multiply the reported analog value by the amount enterd. For example, scaling the I a 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: 1,10,100,1000

Deadband

Display the deadband value for the point. The analog point value must change by more than the deadband amount before it is reported.

11.3.7

COUNTER

Counters are used to count data and events such as Trips, Protection Pickups, Faults and Accumulated kWh.

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Figure 11-9 Counter Tab

Index


PID

Specifies number as defiend in the configuration tool box. The PID Number’s ‘0’ means are not used anymore.

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Range : 0 to 66






Class 0~3



COS

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

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at tracker position are presented. If 2 trackter 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 asCOMTRADE file format and compatible with other analyzing tool. 

COMTRADE file

Comtrade (COMmon format for Transient Data Exchange for power systems) is a file format for oscilloscops data. It is used by many leading coñpanies for the oscilloscops used in high voltage substations. It has been standardised by the IEEE.

Figure 1212-1 Overview of EvalTool

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.

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Figure 12-2 Main Screen of EvalTool 12.2.1

MENU

The File Menu has the following options. Open

Closes the current file and opens a standard window file selection dialog. An existing Data File (*.dat) can be selected and opened.

Exit


The Option Menu has the following options. Graph

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Opens analog and digital graph select window..

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Figure 12-3 Graph Select Window Harmonic

Open a window for voltage and current harmonics.

Fiqure 12-4 Haramonic 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.

12.2.2

TOOLBAR

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Figure 12-5 Toolbar of EvalTool 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

Shirink image

Zoom All

Enlarge all image

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FTU R-200.pdf

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