csc-101 line protection ied protection guide

7/28/2019 CSC-101 Line Protection IED Protection Guide

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CSC-101

Line Protection IEDProduct Guide


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VersionV1.00Doc. Code: 0SF.492.050(E)

Issued Date2010.12Copyright owner: Beijing Sifang Automation Co., Ltd

Note: the company keeps the right to perfect the instruction. If equipments do not agree with

the instruction at anywhere, please contact our company in time. We will provide you with

corresponding service.

is registered trademark of Beijing Sifang Automation Co., Ltd.

We reserve all rights to this document, even in the event that a patent is issued and a differentcommercial proprietary right is registered. Improper use, in particular reproduction anddissemination to third parties, is not permitted.

This document has been carefully checked. If the user nevertheless detects any errors, he isasked to notify us as soon as possible.

The data contained in this manual is intended solely for the IED description and is not to be

deemed to be a statement of guaranteed properties. In the interests of our customers, weconstantly seek to ensure that our products are developed to the latest technological standardsas a result; it is possible that there may be some differences between the hardware/softwareproduct and this information product.

Manufacturer:Beijing Sifang Automation Co., Ltd.


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1

Overview

CSC-101 is selective, reliable and high

speed comprehensive transmission line

protection IED (Intelligent Electronic

Device) for overhead lines, cables or

combination of them. It is a proper

solution for following applications:

Overhead lines and cables up to

1000kV voltage level

All type of station arrangement, such

as 1.5 breakers arrangement, double

bus arrangement, etc.

Extremely long lines

Short lines

Heavily loaded lines

Satisfy the requirement for single and

/or three pole tripping

Communication with station automation

system

The IED provides a highly sensitive and

reliable distance protection with

innovative and proven quadrilateral

characteristic. In addition to separatedzone extension functionality, five

distance zones have fully independent

measuring and setting values which

gives high flexibility for all types of lines

and fault resistances. Many other

functions are integrated to provide a

complete backup protection library.

The wide application flexibility makes the

IED an excellent choice for both newinstallations and retrofitting of the

existing stations.


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Features

Protection and monitoring IED with

extensive functional library, user

configuration possibility and

expandable hardware design to meet

with users special requirements

Redundant A/D sampling channels and

interlocked dual CPU modules

guarantee the high security and

reliability of the IED

Single and/or three tripping/reclosing

Highly sensitive startup elements,

which enhance the IED sensitivity in all

disturbance conditions and avoid

maloperation

Current sudden-change startup

element

Zero sequence current startupelement

Over current startup element

Undervoltage startup element for

weak-infeed end of line

Three kinds of faulty phase selectors

are combined to guarantee the

correction of phase selection:

Current sudden-change phase

selector

Zero sequence and negative

sequence phase selector

Undervoltage phase selector

Four kinds of directional elements

cooperate each other so as to

determine the fault direction correctly

and promptly:

Memory voltage directional

element

Zero sequence component

directional element

Negative sequence component

directional element

Impedance directional element

Full scheme phase-to-phase andphase-to-earth distance protection with

five quadrilateral protection zones and

additional extension zone characteristic

(21, 21N)

Power swing function (68)

Proven and reliable principle of

power swing logic

Unblock elements during powerswing

All useful types of tele-protection

communication scheme (85)

Permissive Underreach Transfer

Trip (PUTT) scheme

Permissive Overreach Transfer

Trip (POTT) scheme

Blocking scheme

Inter-tripping scheme

Phase segregated tele-protection

communication scheme

Particular logic for tele-protection


Current reversal

Weak-infeed end


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Evolving fault logic

Sequence tripping logic

Contacts and/or up to two fiber optical

ports can be used for tele-protection


A complete protection functions library,

include:

Distance protection with

quadrilateral characteristic

(21,21N)


Tele-protection communicationscheme for distance protection

(85-21,21N)

Tele-protection communication

scheme with dedicated earth fault

protection (85-67N)

Overcurrent protection (50, 51,

67)

Earth fault protection (50N, 51N,67N)

Emergency/backup overcurrent

protection (50, 51)

Emergency/backup earth fault

protection (50N, 51N)

Switch-onto-fault protection

(50HS)

Overload protection (50OL)

Overvoltage protection (59)

Undervoltage protection (27)

Circuit breaker failure protection

(50BF)

Poles discordance protection

(50PD)

Dead zone protection (50SH-Z)

STUB protection (50STUB)

Synchro-check and energizing

check (25)

Auto-recloser function for single-

and/or three-phase reclosing (79)

Voltage transformer secondary

circuit supervision (97FF)

Current transformer secondary

circuit supervision

Self-supervision to all modules in the

IED

Complete IED information recording:tripping reports, alarm reports, startup

reports and general operation reports.

Any kinds of reports can be stored up

to 2000 and be memorized in case of

power disconnection

Remote communication

Tele-protection contacts for power

line carrier protection interface

Up to two fiber optical ports for

remote communication applied to

protection function, like

tele-protection

Vast range fiber internal modem,

applied singlemode optical fiber

cable

External optical/electrical

converter, which support

communication through SDH or

PCM, for G.703 (64kbit/s) and

G.703E1 (2048kbit/s)

Up to three electric /optical Ethernet

ports can be selected to communicate

with substation automation system by

IEC61850 or IEC60870-5-103

protocols

Up to two electric RS-485 ports can be


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selected to communicate with

substation automation system by

IEC60870-5-103 protocol

Time synchronization via

network(SNTP), pulse and IRIG-Bmode

Configurable LEDs (Light Emitting

Diodes) and output relays satisfied

users requirement

Versatile human-machine interface

Multifunctional software tool CSmart for

setting, monitoring, fault recording

analysis, configuration, etc.


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Functions

Protection functions

Description ANSI Code

IEC 61850

Logical Node

Name

IEC 60617

graphical symbol

Distance protection

Distance protection 21, 21N PDIS Z

3I >>

3I >>>

Earth fault protection 50N, 51N, 67N PEFM

I0INV>

I0>>

I0>>>

Emergency/backup overcurrent protection 50,51 PTOC3IINV>

3I >

Emergency/backup earth fault protection 50N,51N PTOCI0INV>

I0 >

Switch-onto-fault protection 50HS PSOF3I >HS

I0>HS

Overload protection 50OL PTOC 3I >OL

Voltage protection

Overvoltage protection 59 PTOV3U>

3U>>

Undervoltage protection 27 PTUV3UBF


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I2>BF

Dead zone protection 50SH-Z

STUB protection 50STUB PTOC 3I>STUB

Poles discordance protection 50PD RPLD

3I< PD

I0>PD

I2>PD

Synchro-check and energizing check 25 RSYN

Auto-recloser 79 RREC OI

Single- and/or three-pole tripping 94-1/3 PTRC

Secondary system supervision

CT secondary circuit supervision

VT secondary circuit supervision 97FF

Monitoring functions

Description

Redundant A/D sampling data self-check

Phase-sequence of voltage and current supervision

3I0 polarity supervision

The third harmonic of voltage supervision

Synchro-check reference voltage supervision

Auxiliary contacts of circuit breaker supervision

Broken conductor check

Self-supervision

Logicality of setting self-check

Fault locator

Fault recorder

Station communication

Description

Front communication port


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Isolated RS232 port

Rear communication port

0-2 isolated electrical RS485 communication ports

0-3 Ethernet electrical/optical communication ports

Time synchronization port

Communication protocols

IEC 61850 protocol

IEC 60870-5-103 protocol


Description

Communication port

Contact(s) interface for power line carrier

0 2 fiber optical communication port(s)

Communication distance

Up to 100kM

Connection mode

Direction fiber cable connection

Digital communication network through converter

IED software tools

Functions

Reading measuring value

Reading IED report

Setting

IED testing

Disturbance recording analysis

IED configuration

Printing


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Function arrangement

Figure 1 Function arrangement


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Protection functions

Startup elements

The startup elements basically work as

sensitive detector to all type of faults. As

soon as fault or disturbance happens,

the highly sensitive startup elements will

operate immediately and initiate all

necessary protection functions for

selective clearance of the fault.

The control circuit of tripping relays is

controlled by the startup elements. Only

when one of the startup elements is

triggered, the tripping relays can be

energized to trip. Thus, the maloperation,

due to fatal internal hardware fault, is

avoided in this way.

Based on different principle, there arefour kinds of startup elements listed

below, which are used to enhance the

sensitivity, and to guarantee the security

in case of IEDs internal hardware faults.

Sudden-change currentstartup element

Sudden-change phase to phase or zero

sequence current elements are the main

startup element that can sensitively

detect most of faults. The criteria are as

follows: _or _

where:

i=|| i (K) - i (K-T) | - |i (K-T) - i

(K-2T) ||

: AB,BC or CA, e.g. iAB= iA-iB

K: The present sample

T: The sample quantity of one power cycle

3i0: Sudden-change zero sequence

current

I_Abrupt: The setting value of current

sudden-change elements

Zero sequence current startupelement

Zero sequence current startup element is

applied to improve the fault detection

sensitivity at the high resistance earth

faults. As an auxiliary startup element, it

operates with a short time delay.

Overcurrent startup element

If overcurrent protection function is

enabled, over current startup element is

used to improve the fault detection

sensitivity. As an auxiliary startup

element, it operates with short timedelay.

Low-voltage startup element

When one end of the protected line is a

weak-source system, and the fault

sudden-change phase to phase current

is too low to startup the IED, low-voltage

startup element can be in service to

startup the tele-protection

communication scheme with weak-echo

logic.


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Phase selector

The IED applies different phase

selectors to determine the faulty phase tomake tripping or auto-recloser initiation

correctly. There are three kinds of phase

selectors based on different principle for

different fault stages.

Sudden-change currentphase selector

It operates as soon as the

sudden-change current startup elementstarts up. It makes a phase selection for

fast tripping by comparison amongst

changes of phase-phase currents, iAB,

iBC and iCA.

Symmetrical componentphase selector

During the whole period of fault, the

phase selector checks the angle

between negative sequence current andzero sequence current vectors to

determine faulty phases. In addition,

phase to phase faults will be

discriminated through impedance

characteristic.

Low voltage phase selector

Both current sudden-change phase and

symmetric component phase selector

are not applicable for weak-infeed end of

protected line, so low-voltage phase

selector is employed in this condition

without VT failure. Theoretically, when

one, two or three phase voltages reduce,

the relevant phase(s) is selected as

faulty phase.

Directional elements

Four kinds of directional elements are

employed for reliable determination of

various faults direction. The related

protection modules, such as distance

protection, tele-protection schemes and

overcurrent and earth fault protections,

utilize the output of the directional

elements as one of their operating

condition. All the following directional

elements cooperate with the mentioned

protection functions.

Memory voltage directionalelement

The IED uses the memory voltage and

fault current to determine the direction of

the fault. Therefore transient voltage ofshort circuit conditions doesnt influence

the direction detection. Additionally, it

improves the direction detection

sensitivity for symmetrical or

asymmetrical close-in faults with

extremely low voltage. Butit should be

noted that the memory voltage cannot be

effective for a long time. Therefore, the

following directional elements work as

supplement to detect direction correctly.

Zero sequence componentdirectional element

Zero-sequence directional element has

efficient features in the solidly grounded

system. The directional characteristic

only relates to zero sequence impedance

angle of the zero sequence network ofpower system, regardless of the quantity


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of load current and/or fault resistance

throughout the fault. The characteristic of

the zero sequence directional element is

illustrated in Figure 2.

Figure 2 Direction detection characteristic of

zero sequence directional element

where:

0_Char: The settable characteristic angle

Negative sequencecomponent directionalelement

Negative sequence directional element

can make an accurate directional

discrimination in any asymmetric fault.

The directional characteristic only relates

to negative sequence impedance angle

of the negative sequence network of

power system, regardless the quantity of

load current and/or fault resistance

throughout the fault. The characteristic of

the negative sequence directional

element is illustrated in Figure 3.


negative sequence directional element

where:


Impedance directionalelements

The characteristic of the impedance

directional element (shown in Figure 4) is

same with that of distance protection.


impedance directional element

where:

RSET: The resistance setting of relevant


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zone of distance protection

XSET: The reactance setting of relevant zone

of distance protection

n: Multiplier for reverse directional element,

which make the reverse directional

element more sensitive than forward

one

Distance protection (21, 21N)

The transmissionline distance protection

provides a five zones full scheme

protection with all phase to phase faults

and phase to earth fault loops

independently for each zones. Zone

arrangement illustrated in Figure 5.

Additionally, one extension zone is

employed to co-operate with

auto-recloser and tele-protection

schemes.

R

Zone 1

X

Zone 2

Zone 3

Zone 4

Zone 5

Zone 4 Reverse

(optional)

Zone 5 Reverse

(optional)

Zone Ext.

Figure 5 Distance protection zones

arrangement

Individual settings of resistive and

reactive reach for phase to phase and

phase to earth fault of each zone give

flexibility for application on overhead

lines and cables of different types and

lengths, considering different fault

resistance for phase to phase and phase

to ground short circuits.

Characteristic of distance

protection

The IED utilizes quadrilateral characteristic

as shown in Figure 6.

X

R

X_ZSet

R_ZSet

_ZTop

_ZBottom

_ZLeft_ZRight

Figure 6 Characteristics of distance protection

where:

R_ZSet: R_ZnPP or R_ZnPE;

X_ZSet: X_ZnPP or X_ZnPE;

R_ZnPP: Resistance reach setting for

phase to phase faultSubscript n means

the number of protection zone.

Subscript PP means phase to phase

fault

R_ZnPE: Resistance reach setting for

phase to earth fault. Subscript X means

the number of protection zone.

Subscript PE means phase to earth fault

X_ZnPP: Reactance reach setting for phase

to phase fault


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X_ZnPE: Reactance reach setting for phase

to earth fault

_ZTop: The upper boundary angle of the

characteristic in the first quadrant is

designed to avoid distance protection

overreaching when a close-in fault

happens on the adjacent line

_ZBottom: The bottom boundary angle of

the characteristic in the fourth quadrant

improves the reliability of the relay to

operate reliably for close-in faults with

arc resistance

_ZRight: The right boundary angle of

characteristic in the first quadrant is

used to deal with load encroachment

problems

_ZLeft: The left boundary angle of the

characteristic in the second quadrant

considers the line impedance angle

which generally is not larger than 90.

Thus this angle guarantees the correct

operation of the relay

Extended operatingcharacteristic

To ensure the correct operation at close-in

faults, a rectangle zone covering the

original point is added to the quadrilateral

characteristic. The rectangular offset

characteristic (illustrated in Figure 7) is

calculated automatically according to the

related distance zones settings.Furthermore, the memory voltage direction

element, the zero sequence directional

element, and the negative sequence

direction element are applied to determine

the direction together.

Figure 7 Extended polygonal distance protection

zone characteristic

Reverse zone characteristic

In addition to the forward characteristic

zones mentioned above, the IED

provides two optional reverse zone

characteristics to protect connected

busbar as a backup protection. The

reverse zone characteristic can be set for

zones 4 and 5 individually. This reverse

characteristic has been shown in Figure

8.

Figure 8 Characteristic distance protection

reverse zone

Switch-onto- fault protection


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function

Under either auto reclosing or manual

closing process, the protection function

is able to discriminate these conditions to

give an instantaneous tripping once the

circuit breaker is closed on permanent

faulty line.


The IED provides a high reliable power

swing detector which discriminates

between fault and power swing with

different algorithm.

Power swing blocking logic

According to the slow behavior of power

swing phenomenon, once one of the two

following conditions is met, the protection

program will switch to power swing logic

process:

Without operation of sudden-change

current startup element, all

phase-to-phase impedances, ZAB,

ZBC

and ZCA

enter into the largest

zone of distance protection

Without operation of sudden-change

current startup element, all phase

currents are bigger than the power

swing current setting

In addition, according to the

experimental results of power swing, it is

not possible for impedance vector to

come into protected zones in 150 msafter triggering of the current

sudden-change startup element. After

150 ms, the protection program will be

switched to power swing logic process if

no tripping is issued.

Therefore, according to the above

condition, the IED program enters the

power swing logic process and the

distance protection is blocked until

removing of the mentioned conditions or

until a fault occurrence in the protected

line.

Power swing unblockinglogic

The unblocking logic provides possibility

for selective tripping of faults on

transmission lines during system

oscillations, when the distance protection

function is normally blocked. In order to

unblock distance protection and

therefore, fast clearing of the faults, the

following elements are in service to

discriminate between an internal fault

and power swing conditions.

Asymmetric faults detection element

The zero and negative sequence

current are always the key features of

the asymmetric fault. By comparison

amongst the positive, negative and

zero sequence component of phase

current, the element distinguishes the

asymmetric fault from power swing.

Three phase fault detection element

Based on the experimental results

and practical proof, the change rate

of measuring resistance and the

change vector of measuring

impedance are combined to detect

the three phase fault during the

power swing.


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Tele-protection communication scheme fordistance protection (85-21)

To achieve non-delayed and selectivetripping on 100 % of the line length for all

faults, the communication scheme logic

is provided for distance protection. The

communication schemes are as follows:

Permissive Overreach Transfer Trip

(POTT)

Permissive Underreach Transfer Trip

(PUTT)

Blocking scheme

Following protection logic are used to

ensure correct operation under some

special fault conditions:

Current reversal logic

Weak-infeed end and echo logic

Evolving fault logic


Direct Transfer Trip

The function is provided to cooperate

with related local protection IED, such as

busbar protection, breaker failure

protection, etc., to trip the opposite end

circuit breaker.

Phase segregated


To guarantee correct phase selection at

all times for simultaneous faults on the

parallel lines, the phase segregated

communication scheme logic can be

employed to support single-pole tripping

for faults occurring anywhere at all times

on entire length of the parallel lines.

Tele-protection communication scheme forearth fault protection (85-67N)

To achieve highly sensitive and selective

tripping on 100 % of the line length for all

faults, especially at the high resistance

earth faults. It always works as

complement to tele-protection fordistance protection with a short time

delay. Permissive transfer trip

communication scheme is applied

The protection provides dedicated

current and time elements independent

of the earth fault protection.

Following protection logic are used to

ensure correct operation under some

special fault conditions.

Current reversal logic

Weak-infeed end logic


Direct Transfer Trip

The function is provided to cooperate

with related local protection IED, such as

busbar protection, breaker failure

protection, etc., to trip the remote end

circuit breaker.

Phase segregatedcommunication scheme

To guarantee correct phase selection at


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all times for simultaneous faults on the

parallel lines, the phase segregated

communication scheme logic can be

employed to support single-pole tripping

for faults occurring anywhere at all times

on entire length of the parallel lines

Overcurrent protection (50, 51, 67)The protection provides following

features:

Two definite time stages

One inverse time stage

11 kinds of IEC and ANSI inverse time

characteristic curves as well as

optional user defined characteristic

Settable directional element

characteristic angle, to satisfy the

different network conditions and

applications

Each stage can be set individually as

directional/non-directional

Each stage can be set individually for

inrush restraint

Cross blocking function for inrush

detection

Settable maximum inrush current

VT secondary circuit supervision for

directional protection. Once VT failure

happens, the directional stage can be

set to be blocked

Inrush restraint function

The protection relay may detect large

magnetizing inrush currents during

transformer energizing. In addition to

considerable unbalance fundamental

current, inrush current comprises large

second harmonic current which does not

appear in short circuit current. Therefore,

the inrush current may affect the protection

functions which operate based on the

fundamental component of the measured

current. Accordingly, inrush restraint logic

is provided to prevent overcurrent

protection from maloperation.

Furthermore, by recognition of the inrush

current in one phase, it is possible to set

the protection in a way that not only the

phase with the considerable inrush current,

but also the other phases of theovercurrent protection are blocked for a

certain time. This is achieved by

cross-blocking feature integrated in the

IED.

The inrush restraint function has a

maximum inrush current setting. Once the

measuring current exceeds the setting, the

overcurrent protection will not be blocked

any longer.

Characteristic of directionelement

The direction detection is performed by

determining the position of current vector

in directional characteristic. In other word,

it is done by comparing phase angle

between the fault current and the

reference voltage, Figure 9 illustrates the

direction detection characteristic for

phase A element.


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Forward

Ph_Char

Bisector


overcurrent protection directional element

where:

Ph_Char: The settable characteristic angle

The assignment of the applied measuring

values used in direction determination has

been shown in Table 1for different types of

faults.

Table 1 Assignment of applied current and

reference voltage for directional element

Phase Current Voltage

AaI

bcU

BbI

caU

CcI

abU

For three-phase short-circuit fault,

without any healthy phase, memoryvoltage values are used to determine

direction clearly if the measured voltage

values are not sufficient. The detected

direction is based on the memory voltage

of previous power cycles.

Earth fault protection (50N, 51N, 67N)

The earth fault protection can be used to

clear phase to earth faults as system

back-up protection.

The protection provides following

features:



11 kinds of the IEC and ANSI inversetime characteristic curves as well as


Zero sequence directional element

Negative sequence directional element

is applied as a complement to zero

sequence directional element. It can be

enabled/disabled by setting

Each stage can be set individually asdirectional/non-directional

Settable directional element

characteristic angle, to satisfy the

different network conditions and

applications

Each stage can be set individually for

inrush restraint


VT secondary circuit supervision for

directional protection function. Once

VT failure happens, the directional

stage can be set to be blocked

CT secondary circuit supervision for

earth fault protection. Once CT failure

happens, all stages will be blocked

Zero-sequence current is measured

from earth phase CT

Directional element


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The earth fault protection adopts zero

sequence directional element which

compares the zero sequence system

quantities:

3I0, current is measured from earthphase CT

3U0, the voltage is used as reference

voltage. It is calculated from the sum of

the three phase voltages

Forward

0_Char

Bisector

0_Ref3U

0

-3I0

3I 090


zero sequence directional element

where:


For earth fault protection, users can

choose negative sequence directional

element as the complement of zero

sequence directional element. It can be

used in case of too low zero sequencevoltage due to some fault condition e.g.

the unfavorable zero-sequence voltage.

The negative sequence directional

element characteristic is shown in Figure

11.


negative sequence directional element

where:


Furthermore, under the VT failure

situation, it can be set to block directional

earth fault protection.


The protection relay may detect large

magnetizing inrush currents during

transformer energizing. In addition to

considerable unbalance fundamental

current, Inrush current comprises large

second harmonic current which doesnt

appear in short circuit current. Therefore,

the inrush current may affect the protection

functions which operate based on the

fundamental component of the measuredcurrent. Accordingly, inrush restraint logic

is provided to prevent earth fault protection

from mis-tripping.

Since inrush current cannot be more than a

specified value, the inrush restraint

provides an upper current limit in which

blocking does not occur.


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Emergency/backup overcurrent protection(50, 51)

In the case of VT Fail condition, alldistance zones and protection functions

related with voltage input are out of

service. In this case, an emergency

overcurrent protection comes into

operation.

Additionally, the protection can be set as

backup non directional overcurrent

protection according to the users

requirement.


features:

One definite time stage


11 kinds of IEC and ANSI inverse

characteristics curve as well as


Inrush restraint function can be set for

each stage separately

Cross blocking of inrush detection

Settable maximum inrush current.

Emergency/backup earth fault protection(50N, 51N)

In the case of VT Fail condition, all

distance zones and protection functionsrelated with voltage input are out of

operation. An emergency earth fault

protection comes into operation.

Additionally, the protection can be set as

backup non directional earth fault

protection according to the users

requirement.


features:

One definite time stage


11 kinds of IEC and ANSI inverse

characteristics curve as well as


Inrush restraint can be selected

individually for each stage


CT secondary circuit supervision for

earth fault protection. Once CT failure

happens, all stages will be blocked

Zero-sequence current is measured

from 3-phase currents summation

Switch-onto-fault protection (50HS)

The protection gives a trip when the

circuit breaker is closed manually onto ashort circuited line.

The protection provide following

features:

One definite time overcurrent stage


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One definite time earth fault protection

stage

Inrush restraint can be selected

Cross blocking for inrush detection


Manual closing binary input detection

Overload protection (50OL)

The IED supervises load flow in real time.

If each phase current is greater than the

dedicated setting for a set delay time, the

protection will issue alarm.

Overvoltage protection (59)

The overvoltage protection detects

abnormally network high voltageconditions. Overvoltage conditions may

occur possibly in the power system during

abnormal conditions such as no-load,

lightly load, or open line end on long line.

The protection can be used as open line

end detector or as system voltage

supervision normally.

The protection provides following features:


Each stage can be set to alarm or trip

Measuring voltage between

phase-earth voltage and phase-phase

(selectable)

Settable dropout ratio

Undervoltage protection (27)

One voltage reduction can occur in the

power system during faults or abnormal

conditions.


features:


Each stage can be set to alarm or trip

Measuring voltage between

phase-earth voltage and phase-phase

selectable.

Current criteria supervision

Circuit breaker aux. contact

supervision

VT secondary circuit supervision, the

undervoltage function will be blocked

when VT failure happens

Settable dropout ratio

Breaker failure protection (50BF)

The circuit breaker failure protection is

designed to detect failure of the circuit

breaker during a fault clearance. It

ensures fast back-up tripping of

surrounding breakers by tripping relevant

bus sections.


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The protection can be single- or

three-phase started to allow use with

single or three-phase tripping

applications.

Once a circuit breaker operating failureoccurs on a feeder/transformer, the bus

section which the feeder/transformer is

connected with can be selectively

isolated by the protection. In addition a

transfer trip signal is issued to trip the

opposite end circuit breaker of the

feeder.

In the event of a circuit breaker failure

with a busbar fault, a transfer trip signalis issued to trip the remote end circuit

breaker of the feeder.

The current criteria are in combination

with three phase current, zero and

negative sequence current to achieve a

higher security.

The function can be set to give single- or

three phase re-tripping of the local breaker

to avoid unnecessary tripping of

surrounding breakers in the case of the

circuit breaker with two available trip coils.

Additionally, during single pole tripping,stage 1 is able to re-tripping three phase

with settable delay time after single phase

re-tripping failure.

Two trip stages (local and surrounding

breaker tripping)

Transfer trip command to the remote

line end in second stage

Internal/ external initiation

Single/three phase CBF initiation

Selectable CB Aux contacts checking

Current criteria checking (including

phase current, zero and negative

sequence current)

Dead zone protection (50SH-Z)

The IED provides this protection function

to protect dead zone, namely the area

between circuit breaker and CT in the

case that CB is open. Therefore, by

occurrence of a fault in dead zone, the

short circuit current is measured by

protection relay while CB auxiliary

contacts indicate the CB is open.

Internal/external initiation

Self-adaptive for bus side CT or line

side CT

When one bus side CT of feeder is

applied, once a fault occurs in the dead

zone, the IED trips the relevant busbar

zone. Tripping logic is illustrated in

Figure 12.


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Figure 12 Tripping logic when applying bus

side CT

When one line side CT is applied, when

a fault occurs in the dead zone,protection relay sends a transfer trip to

remote end relay to isolate the fault.

Tripping logic is illustrated in Figure 13.

Figure 13 Tripping logic when applying line

side CT

STUB protection (50STUB)

The VT is mostly installed at line side of

transmission lines. Therefore, for the cases

that transmission line is taken out of

service and the line disconnector is

opened, the distance protection will not be

able to operate and must be blocked.

The STUB protection protects the zone

between the CTs and the open

disconnector. The STUB protection is

enabled when the open position of the

disconnector is connected to IED binary

input. The function supports one definite

stage which related concept is shown in

Figure 14.


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Figure 14 Tripping logic of STUB protection

Poles discordance protection (50PD)

The phase segregated operating circuit

breakers can be in different positions

(close-open) due to electrical or

mechanical failures during the systemnormal operation.

The protection operates based on

information from auxiliary contacts of the

circuit breaker with additional criteria.

The protection performs following

features:

3 phase CB Aux contacts supervision

Current criteria checking (including

phase current, zero and negative

sequence current)

Synchro-check and energizing check (25)

The synchro-check function checks theboth side voltages of the circuit breakerfor synchronism conditions.

The synchronization function ensures the

stability of the network in three phase

reclosing condition. To do this, the two

side voltages of the circuit breaker are

compared in terms of magnitude, phase

angle and frequency differences.

Additionally, closing can be done safely

in conditions that at least one side of the

CB has dead voltage.

Available for automatic reclosing

(internally or externally)

Based on voltage/ angle/ frequency

difference

Synchro-check modes:

Synch-check

Energizing check, and synch-check ifenergizing check failure


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Override

Modes of energizing check:

Dead V4 and dead V3Ph

Dead V4 and live V3Ph

Live V4 and dead V3Ph

Synchro-check reference

voltage supervision

If the automatic reclosing is set for

synchronization check or energizing

check, during the automatic reclosing

period, the synchronization condition of

the voltages between both sides of CB

cannot be met, an alarm will be issued

after default time delay.

Auto-recloser (79)

For restoration of the normal service

after a fault an auto reclosing attempt is

mostly made for overhead lines.

Experiences show that about 85% of

faults have transient nature and will

disappear after an auto reclosing attempt

is performed. This means that the line

can be re-energized in a short period.

The reconnection is accomplished after a

dead time via the automatic reclosing

function. If the fault is permanent or short

circuit arc has not been extinguished, theprotection will re-trip the breaker. Main

features of the auto-recloser are as

follows:

4 shots automatic recloser (selectable)

Individually settable dead time for three

phase and single phase fault and for

each shot

Internal/external AR initiation

Single/three phase AR operation

CB status supervision

CB Aux. contact supervision

Cooperation with internal synch-check

function for reclosing command


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Secondary system supervision

Current transformer secondarycircuit supervision

Open or short circuited CT cores can

cause unwanted operation of some

protection functions such as earth fault

current and negative sequence current

functions.

Interruption of the CT secondary circuit is

detected based on zero-sequence current.

Once CT failure happens, each stage of

earth fault protection is blocked.

Voltage transformer secondarycircuit supervision

A measured voltage failure, due to a

broken conductor or a short circuit fault in

the secondary circuit of voltage transformer,

may result in unwanted operation of the

protection functions which work based on

voltage criteria. VT failure supervision

function is provided to block these

protection functions and enable the backup

protection functions. The features of the

function are as follows:

Symmetrical/asymmetrical VT failure

detection

3-phase AC voltage MCB monitoring

1-phase AC voltage MCB monitoring

Zero and negative sequence current

monitoring

Applicable in solid grounded,

compensated or isolated networks


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Monitoring functions

Phase-sequence of voltage andcurrent supervision

The phase-sequence of three phase

voltage and current are monitored in the

normal condition to determine that the

secondary circuit of CT or VT is connected

with IED correctly.

3I0 polarity supervision

The IED compare the magnitude and

phase angle of the calculated zero

sequence current with the measured one

to determine that the polarity is connected

in a right way.

The third harmonic of voltagesupervision

If the third harmonic voltage is excessive,

the alarm without blocking protection willbe given with delay time for checking of the

secondary circuit of voltage transformer.

Auxiliary contacts of circuitbreaker supervision

Current flowing through the transmission

line and connected CB aux. contacts are

monitored in phase segregated. Therefore,

the conflict condition is reported as alarm.

For example, If CB aux. contacts indicate

that CB is open in phase A and at the same

time flowing current is measured in this

phase, related alarm is reported.

Broken conductor detection

The main purpose of the broken conductor

detection function is to detect the broken

conductors on protected transmission lines

and cables. Detection can initiate an alarmor tripping.

Self-supervision

All modules can perform self-

supervision to its key hardware

components and program, as soon as

energizing. Parts of the modules are

self-supervised in real time. All internal

faults or abnormal conditions will

initiate an alarm. The fatal faults among

them will result in the whole IED

blocked

The sampled data from the redundant

A/D sampling channels compare with

each other in real time. If the difference

exceeds the specified threshold, it will

be considered as analog input channel

fault and the protection will be blocked

immediately

CPU module and communication

module perform real time

inter-supervision. Therefore

communication interruption between

them is detected and related alarm will

be given

CRC checks for the setting, program

and configuration, etc.

Fault locator

The built-in fault locator is an impedance

measuring functiongiving the distance

from the IED measuring location to the

fault position in km. The IED reports fault

location after the IED tripping.


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Station communication

Overview

The IED is able to connect to one or

more substation level systems or

equipments simultaneously, through the

communication ports with

communication protocols supported.

(Shown in Figure 15)


There is a serial RS232 port on the front

plate of all the IEDs. Through this port,

the IED can beconnected to the

personal computer for setting, testing,

and configuration using the dedicated

Sifang software tool.

RS485 communication ports

Up to 2 isolated electrical RS485

communication ports are provided to

connect with substation automation

system. These two ports can work in

parallel for IEC60870-5-103.

Ethernet communicationports

Up to 3 electrical or optical Ethernet

communication ports are provided to

connect with substation automation system.

These two out of three ports can work in

parallel for protocol, IEC61850 or

IEC60870-5-103.

Figure 15 Connection example for multi-networks of station automation system

Note: All four ports can work in parallel

Communication protocol

The IED supports station communication

with IEC 61850-8 and IED60870-5-103

protocols.

By means of IEC61850, GOOSE peer- to

peer communication make it possible that

bay IEDs can exchange information to

each other directly, and a simple

master-less system can be set up for bay

and system interlocking and other

interactive function.

Time synchronization port


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AllIEDs feature a permanently integrated

electrical time synchronization port. It can

be used to feed timing telegrams in IRIG-B

or pulse format into the IEDs via time

synchronization receivers. The IED can

adapt the second or minute pulse in the

pulse mode automatically.

Meanwhile, SNTP network time

synchronization can be applied.

The Figure 16 illustrates the optional time

synchronization modes.

SNTP IRIG-B Pulse

Ethernet port IRIG-B port Binary input

Figure 16 Time synchronizing modes


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Binary signal transfer

The binary signals can be exchanged

through remote communication channels

between the two IEDs on the two end of

the transmission line or cable respectively.

This functionality is mainly used for the line

Tele-protection communication schemes,

e.g., POTT or PUTT schemes, blocking

scheme and inter trip and so on.

Remote communicationchannel

The IEDs are able to communicate with

each other in two types:

Directly fiber-optical cable connection

mode at distances up to 100 km (see

Figure 17 and Figure 18)

Through the communication converter

with G.703 or G.703E1 interface

through the public digital

communication network (see Figure 19

and Figure 20)

Because there are up to two selectable

fiber-optical remote communication ports,the IED can work in the redundant

communication channel mode, with

advantage of no time-delay channel switch

in case of the primary channel broken

(Figure 18, Figure 20 and Figure 21).

Figure 17 Single channel, communication through dedicated fiber optical cable


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Figure 18 Double channels, communication through dedicated fiber optical cable

Communication converter

The link between the IED and a

multiplexed communication network is

made by dedicated communication

converters (CSC186). They have a

fiber-optic interface with 1310 nm and 2 FC

connectors to the protection IED. The

converter can be set to support an

electrical G703-64 kbit/s or G703-E1

2Mbit/s interface, according the

requirement of the multiplexed

communication network.

Figure 19 Single Channel, communication through digital communication network


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Figure 20 Double channels, communication through digital communication network

Figure 21 Double channels, one channel through digital communication network, one channel

through dedicated fiber optical cables


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Software tools

CSmart protection manager is a

user-friendly software tool for engineering,

parameter setting, disturbance handling

and monitoring. It provides versatile

functionalities required throughout the life

cycle of protection IEDs. Its features are as

follows:

Device administration in projects with

freely configurable hierarchies for any

substation and electrical power station

topology

Modification, import and export of

parameter sets sorted by protection

functions,withsetting logicality check

Precise fault analysis by Fisewave

software: visualization of fault records

in curves over time, circle diagrams,

vector diagrams, bar charts and data

sheet

Intelligent plausibility checks rule out

incorrect input

Graphical visualization of

characteristics and zone diagrams with

direct manipulation of the curves

Password-protected access for

different jobs such as parameter setting,

commissioning and controlling

(authorized staff only)

Testing and diagnostic functions

decisive support in the commissioning

phase


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Hardware

Human-machine Interface(HMI)

The human-machine interface is simple

and easy to understand the whole front

plate is divided into zones, each of them

with a well-defined functionality:

Figure 22 IED front plate

1 Liquid crystal display (LCD)

2 LEDs

3 Shortcut function keys

4 Arrow keys

5 Reset key

6 Quit key

7 Set key

8 RS232 communication port


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Analogue Input Module (AIM)

The analogue input module is used to

galvanically separate and transform the

secondary currents and voltages

generated by the measuring transformers.

CPU Module (CPU)

The CPU module handles all protection

functions and logic. There are two CPU

modules in the IED, CPU1 and CPU2, with

the same software and hardware. They

work in parallel and interlock each other to

prevent maloperation due to the internal

faults of one CPU modules.

Moreover, the redundant A/D sampling

channels are equipped. By comparing the

data from redundant sampling channels,

any sampling data errors and the channel

hardware faults can be detected

immediately and the proper alarm and

blocking is initiated in time.

Communication Module (COM)

The communication module performs

communication between the internal

protection system and external equipments

such as HMI, engineering workstation,

substation automation system, RTU, etc.,

to transmit remote metering, remote

signaling, SOE, event reports and record

data.

Up to 3 channels isolated electrical or

optical Ethernet ports and up to 2 channels

RS485 serial communication ports can be

provided in communication module to meet

the communication demands of different

substation automation system and RTU at

the same time.

The time synchronization port is equipped,

which can work in pulse mode or IRIG-B

mode. SNTP mode can be applied through

communication port.

In addition, a series printer port is also

reserved.

Binary Input Module (BIM)

The binary input module is used to connectthe input signals and alarm signals such as

the auxiliary contacts of the circuit breaker

(CB), etc.

Binary Output Module (BOM)

The binary output modules mainly provide

tripping output contacts, initiating output

contacts and signaling output contacts. All

the tripping output relays have contacts

with a high switching capacity and are

blocked by protection startup elements.

Each output relay can be configured to

satisfy the demands of users.

Power Supply Module (PSM)

The power supply module is used to

provide the correct internal voltages and

full isolation between the terminal and the

battery system.


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Layout and dimension

Figure 23 4U, 19 case with rear cover

Table 2 Dimension of the IED case

Legend A B C D E

Dimension 177 482.6 265 320 437.2

Unit: mm

Figure 24 Cut-out on the panel

Table 3 Dimension of the cutout for IED mounting

Legend A B C D E

Dimension 450 465 101.6 178 6.5

Unit: mm


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Typical connection

A. For one breaker of single or double busbar arrangement

Figure 25 Typical connection diagram for one breaker of single or double busbar arrangement


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B. For one and half breaker arrangement

* **

IA

IB

IC

UB

UA

UC

U4

IN

UN

Protection IED

a01

a02

a03

a04

b01

b02

b03

b04

a10

a09

b09

b10

a07

b07

A

B

C

AB

C

* **

Figure 26 Typical connection diagram for one and half breaker arrangement


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C. For parallel lines

IA

IB

IC

UB

UA

UC

U4

IN

UN

Protection IED

A

B

C

* * *

a01

a02

a03

a04

b01

b02

b03

b04

a10

a09

b09

b10

a07

b07

***

INM

a05

b05

Figure 27 Typical connection diagram for parallel lines


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Rear terminals

The rear view of the protection IED

Figure 28 Rear view of the protection IED


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Terminals of Analogue Input Module (AIM)

The Analogue Input Module E

Figure 29 Terminals arrangement of AIM E

Table 4 Description of terminals of AIM E

TerminalAnalogue

InputRemark

a01 IA Star point

b01 IA

a02 IB Star point

b02 IB

a03 IC Star point

b03 IC

a04 IN

b04 IN Star point

a05 INM

b05 INM Star point

a06 Null

b06 Null

a07 U4 Star point

b07 U4

a08 Null

b08 Null

a09 UB Star point

b09 UC Star point

a10 UA Star point

b10 UN

a11 Null

b11 Null


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Terminals of Binary Output Module (BOM)

Binary Output Module A

The module provides 16 output relays for tripping or initiating, with total 16 contacts.

a02

R

1

a04

a06

a08

a10

a12

a14

a16

a18

a20

a22

a24

a26

a28

a30

a32

ac

c02

c04

c06

c08

c10

c12

c14

c16

c18

c20

c22

c24

c26

c28

c30

c32

R

3

R

5

R

7

R

9

R

11

R

13

R

15

R

16

R

2

R

4

R

6

R

8

R

10

R

12

R

14

Figure 30 Terminals arrangement of BOM A


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Table 5 Definition of terminals of BOM A

Terminal Definition Related relay

a02 Trip contact 1-0 Output relay 1

c02 Trip contact 1-1 Output relay 1
































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Binary Output Module C

The module provides 16 output relays for signal, with total 19 contacts.

a02

a04

a06

a08

a10

a12

a14

a16

a18

a20

a22

a24

a26

a28

a30

a32

ac

c02

c04

c06

c08

c10

c12

c14

c16

c18

c20

c22

c24

c26

c28

c30

c32

R

4

R

5

R

1

R

2

R

3

R

6

R

7

R

16

R

9

R

10

R

11

R

12

R

13

R

14

R

15

R

8

Figure 31 Terminals arrangement of BOM C


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Table 6 Definition of terminals of BOM C

Terminal Definition Related relay

a02 Signal 1-0, Common terminal of signal contact group 1

c02 Signal 2-0, Common terminal of signal contact group 2

a04 Signal contact 1-1 Output relay 1

c04 Signal contact 2-1 Output relay 1





a10 Signal 3-0, Common terminal of signal contact group 3

c10 Signal 4-0, Common terminal of signal contact group 4
























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Terminals of Binary Input Module (BIM )

Binary Input Module A

Figure 32: Terminals arrangement of BIM A

Table 7 Definition of terminals of BIM A

Terminal Definition Remark

a02 BI1 BI group 1

c02 BI2 BI group 2

a04 BI3 BI group 1

c04 BI4 BI group 2

a06 BI5 BI group 1

c06 BI6 BI group 2

a08 BI7 BI group 1

c08 BI8 BI group 2

a10 BI9 BI group 1

c10 BI10 BI group 2

a12 BI11 BI group 1

c12 BI12 BI group 2

a14 BI13 BI group 1

c14 BI14 BI group 2

a16 BI15 BI group 1

c16 BI16 BI group 2

a18 BI17 BI group 1

c18 BI18 BI group 2

a20 BI19 BI group 1

c20 BI20 BI group 2

a22 BI21 BI group 1

c22 BI22 BI group 2

a24 BI23 BI group 1

c24 BI24 BI group 2

a26 BI25 BI group 1

c26 BI26 BI group 2

a28 BI27 BI group 1

c28 BI28 BI group 2

a30 BI29 BI group 1

c30 BI30 BI group 2

a32 DC - Input

Common terminal

of BI group 1

c32 DC - InputCommon terminal

of BI group 2


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Terminals of Communication Module (COM)

Figure 33 Terminals arrangement of COM

Table 8 Definition of terminals of COM

Terminal Definition

01 Null

02 Null

03 Null

04 Null

05 Optional RS485 port - 2B

06 Optional RS485 port - 2A

07 Optional RS485 port - 1B

08 Optional RS485 port - 1A

09 Time synchronization

10 Time synchronization GND

11 Null

12 Null

13 Null

14 Null

15 Null

16 Null

Ethernet

Port A

Optional optical fiber or RJ45

port for station automation

system

Ethernet

Port B



system

Ethernet

Port C



system


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Communication ports of CPU module (CPU)

RX

TX

RX

TX

Ch A

Ch B

Figure 34 Communication ports arrangement of

CPU module

Table 9 Definition of communication ports of

CPU module

Ports Definition

Ch A RX Remote communication channel

A optical fiber data receiving

port

Ch A TX Remote communication channel

A optical fiber data transmitting

port

Ch B RX Remote communication channel

B optical fiber data receiving

port

Ch B TX Remote communication channel

B optical fiber data transmitting

port

Note:These ports are optional.


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Terminals of Power Supply Module (PSM)

Figure 35 Terminals arrangement of PSM

Table 10 Definition of terminals of PSM

Terminal Definition

a02 AUX.DC 24V+ output 1

c02 AUX.DC 24V+ output 2

a04 AUX.DC 24V+ output 3

c04 AUX.DC 24V+ output 4

a06 Isolated terminal, not wired

c06 Isolated terminal, not wired

a08 AUX.DC 24V- output 1

c08 AUX.DC 24V- output 2





a14 Alarm contact A1, for AUX.DC

power input failure

c14 Alarm contact A0, for AUX.DC

power input failure

a16 Alarm contact B1, for AUX.DCpower input failure

c16 Alarm contact B0, for AUX.DC

power input failure



a20 AUX. power input 1, DC +

c20 AUX. power input 2, DC +

a22 AUX. power input 3, DC +

c22 AUX. power input 4, DC +



a26 AUX. power input 1, DC -

c26 AUX. power input 2, DC -

a28 AUX. power input 3, DC -

c28 AUX. power input 4, DC -



a32 Terminal for earthing

c32 Terminal for earthing


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Technical data

Basic data

Frequency

Item Data

System rated frequency 50 Hz or 60Hz

Internal current transformer

Item Data

Rated current Ir 1 or 5 A

Nominal current range (0.2 40)x Ir

Power consumption (per phase)

at Ir= 1 A 0.5 VA

at Ir= 5 A 1 VA

Thermal overload capability

at Ir= 1 A 100 x Ir for 1 s

30 x Ir for 10 s

3 x Ircontinuous

at Ir= 5 A 40 x Ir for 1 s

30 x Ir for 10 s

3 x Ircontinuous

Internal voltage transformer

Item Data

Rated voltage Vr(ph-ph) 100 V /110 V

Nominal range (ph-e) 0.4 V to 120 V

Power consumption

at Vr= 110 V 0.5 VA per phase

Thermal overload capability in voltage path

(phase-neutral voltage)

2Vr, for 10s

1.5Vr, continuous


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Auxiliary voltage

Item Data

Rated auxiliary voltage Vaux 100~125V DC

195~250V DC

Permissible tolerance %20 Uaux

Power consumption

Normal operation 30 W

Tripping condition 50 W

Binary inputs

Item Data

Input voltage range 24 V DC

110/125 V DC

220/250 V DC

Response time/dropout time Software provides de-bounce time

Power consumption, energized 2mA

Binary outputs

Item Data

Max. system voltage 250V DC/AC

Current carrying capacity 5 A continuous

30 A for 0.5s making current

2000 switching cycles

Making capacity at inductive load with L/R>10 ms 1100 W(DC)

1250 VA(AC)

Breaking capacity 250 mA, 100 W resistive, for AC, cos > 0.4

50W, for DC at L/R < 40 ms


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Type tests

Insulation test

Item Data

Standards IEC 60255-5:2000

GB/T 15145-2001

DL/T 478-2001

Voltage test (100 % test)

All circuits besides auxiliary voltage and

RS485/RS232 and time synchronization

2KV,50Hz,1min

IEC 60255-5:2000

GB/T 15145-2001

DL/T 478-2001

Auxiliary voltage 3.5 kV DC

IEC 60255-5:2000

GB/T 15145-2001

DL/T 478-2001

Communication ports and time synchronization

terminals

500V,50Hz,1min

IEC 60255-5:2000

GB/T 15145-2001

DL/T 478-2001

Impulse voltage test

all circuits, except communication ports and time

synchronization

5kV (Ui63V) /1kV (Ui100 M at 500 VDC

IEC 60255-5:2000

GB/T 15145-2001

DL/T 478-2001

Electromagnetic compatibility tests

Item Data

Standards GB/T 14598.9-2002

identify IEC 60255-22-3:2000, for radiatedelectromagnetic field disturbance test


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GB/T 14598.10-2007

identify IEC 60255-22-4:2002, for electrical fast

transient/burst immunity test

GB/T 14598.13-2008

Modify from IEC 60255-22-1:2007, for 1MHz

burst immunity test

GB/T 14598.14-1998

identify IEC 60255-22-2:1996, for electrostatic

discharge test

GB/T 14598.17-2005

Identify with IEC 60255-22-6:2002, for

Conducted electromagnetic field disturbance

tests

GB/T 14598.18-2007

Identify with IEC 60255-22-5:2002, for surge

immunity test

GB/T 14598.19-2007

Identify with IEC 60255-22-7:2003, for power

frequency immunity test

GB/T 14598.20-2007

Identify with IEC 60255-26:2004, for

electromagnetic compatibility requirements

High-frequency burst disturbance test 2.5 kV (peak value); 1 MHz

test duration 2 s

IEC 60255-22-1, class III

and VDE 0435 Part 303, class III

Electrostatic discharge 8 kV contact discharge

15 kV air gap discharge

both polarities; 150 pF; Ri = 330

IEC 60255-22-2; class IV

and EN 61000-4-2; class IV

Radio-frequency electromagnetic field disturbance

non-modulated

10V/m, 80 to 1000 MHz



amplitude-modulated

10 V/m, 80MHz to 2.7GHz

80%AM; 1 kHz



pulse-modulated

10 V/m, 900 MHz; repetition rate 200 Hz, on

duration 50 %

IEC 61000-4-3/ENV 50204, class IIIFast transient disturbance 4KV


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IEC 60255-22-4 and IEC 61000-4-4, class IV

High-energy surge voltages (Surge)

Auxiliary voltage

2KV


radio-frequency line-conducted disturbance,

amplitude-modulated

10 V; 150 kHz to 80 MHz

AM 80 %; 1 kHz


Power frequency magnetic field test 30 A/m; 50 Hz, continuous

300 A/m; 50 Hz, 3 s

0.5 mT, 50 Hz

IEC 61000-4-8, class IV

IEC 60255-6

Oscillatory surge withstand capability test 2.5kV, 1 MHz

ANSI/IEEE C37.90.1

Fast transient surge withstand capability test 4KV

5kHz

ANSI/IEEE C37.90.1

Radiated electromagnetic field disturbance 10 V/m; 25 to 1000 MHz

amplitude and pulse-modulated

ANSI/IEEE C37.90.2

Damped wave 2.5 kV (peak value, polarity alternating)

100 kHz, 1 MHz, 10 and 50 MHz, Ri = 200

IEC 60694 / IEC 61000-4-12

Radiated emission 30MHz to 1GHz ( IT device may up to 5 GHz)

CISPR11, class A

EN61000-6-4:2005

Conducted emission 0.15MHz to 80MHz

CISPR11, class A

EN61000-6-4:2005

Mechanical tests

Item Data

During operation

Standards IEC 60255-21-1:1988

IEC 60255-21-2

Vibration Sinusoidal

10 to 50 Hz; +/- 0.035 mm amplitude

50 to 150 Hz

IEC 60255-21-1, class 2


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IEC 60068-2-6

Shock Semi-sinusoidal

Acceleration 5 g, duration 11 ms; 6 shocks in both

directions of 3 axes

IEC 60255-21-2, class 1

IEC 60068-2-27

During transportation

Standards IEC 60255-21-2

Vibration Sinusoidal

5 to 8 Hz: 7.5 mm amplitude

8 to 150 Hz; 2 g acceleration

frequency sweep 1 octave/min

20 cycles in 3 perpendicular axes

IEC 60255-21-1, class 2

IEC 60068-2-6

Shock Semi-sinusoidal

Acceleration 15 g, duration 11 ms

6 shocks in both directions of 3 axes

IEC 60255-21-2, Class 1

IEC 60068-2-27

Continuous shock Semi-sinusoidal

Acceleration 10 g, duration 16 ms

2000 shocks in both directions

of 3 axes

IEC 60255-21-2, class 1

IEC 60068-2-29

Environmental tests

Item Data

Temperatures

Type-tested , test Bd, for 16 h -25 C to +70 C

IEC 60068-2-1

IEC 60068-2-2

Recommended permanent operating temperature -10 C to +55C

IEC 60255-6

(Legibility of display may be impaired above

+55 C /+131 F)

Storage and transport temperature limit -25C~+70C


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Humidity

Permissible humidity 95 % of relative humidity

IED design

Item Data

Case size 4U19inch

Dimensions See outline and installation dimension

drawing

Weight 10kg

Protection level IP20 class I

EN 60529

IEC 60529

CE certificate

Item Data

EMC DirectiveEN 61000-6-2 and EN61000-6-4 (EMC Council

Directive 2004/108/EC)

Low voltage directive EN 60255-27 (Low-voltage directive 2006/95 EC)


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Station communication ports


Item Data

Number 1

Connection Isolated, RS232; front panel

9-pin subminiature connector, for CSmart

Communication speed 9600 baud

Max. length of communication cable 15 m

RS485 communication port

Item Data

Number 0~2

Connection 2-wire connector

Rear port in communication module

Max. length of communication cable 1.0 km


Communication speed Factory setting 9600 baud

Min. 1200 baud, Max. 19200 baud

Ethernet communication port

Item Data

Electrical communication port

Number 0 ~ 3

Connection RJ45 connector


Max. length of communication cable 100m

IEC 61850 protocol

Communication speed 100 Mbit/s



Optical communication port ( optional )

Number 0 ~ 3

Connection SC connector



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Optical cable type Multi-mode

Max. length of communication cable 2.0km

IEC 61850 protocol




Time synchronization

Item Data

Mode Pulse mode

IRIG-B signal format IRIG-B000

Connection 2-wire connector


Voltage levels differential input


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Fiber optic communication ports

Item Data

Number 1 ~ 2

Fiber optic cable type Single-mode

Optic wavelength 1310nm, when the transmission distance 60km

Optic received sensitivity -38dBm

Emitter electric level >-8dBm; (the transmission distance -4dBm; (the transmission distance 40~60km)

>-3dBm; (the transmission distance >60km)

Fiber optic connector type FC or SC, when the transmission distance 60km

Data transmission rate 64 kbit/s, G703

2,048 kbit/s, G703-E1

Max. transmission distance 100km


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Functions

NOTE:Ir: CT rated secondary current, 1A or 5A

In: nominal current of the reference side of transformer

Distance protection (ANSI 21, 21N)

Setting range

Number of settable zone 5 zones

Distance characteristic Polygonal

Resistance setting range 0.01120, step 0.01, when Ir=5A

0.05600, step 0.01, when Ir=1A

Reactance setting range 0.01120, step 0.01, when Ir=5A

0.05600, step 0.01, when Ir=1A

Delay time of distance zones 0.00 ~ 60.00s, step 0.01s

Time

Best Operation time 20ms for zone 1 of distance when fault occurs

within 0.7 time setting value

Operation time 30ms for zone 1 of distance when fault occurs

within 0.7 time setting value

Tolerance

Dynamic overreaching for zone 1 of distance

protection

5%

Tolerance of time 1% or +20 ms for other zones, when setting

time > 60ms

Measuring tolerance of fault locator (not including

errors caused by factors outside product)

+3% when fault current is greater than 0.01 Ir at

metal fault, error will become bigger when fault

occurs with greater path fault resistance

Power-swing logic (ANSI 68)

Setting range

Range of sudden-change current 0.05 A to 20 A , when Ir=1A

0.25 A to 100 A when Ir=5A

Current range of power swing detection 0.05 A to 20 A , when Ir=1A



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Tele-protection (ANSI 85 21, 21N, 67N)

Time

Best operation time

Operation time

25ms Permission mode for 21/21N

30ms for 21/21N

Overcurrent protection (ANSI 50, 51, 67)

Setting range

Current pickup 0.05 A to 20.00 A, when Ir=1A

0.25 A to 100.00 A, when Ir=5A

Definite time delay 0.00 to 60.00s, step 0.01s

Directional element

Operating area range 85 of characteristic bisector

Characteristic angle 0 to 90, step 1

Directional element voltage threshold 5V

Inverse time characteristics

IEC standard Normal inverse

Very inverse

Extremely inverse

Long inverse

ANSI InverseShort inverse

Long inverse

Moderately inverse

Very inverse

Extremely inverse

Definite inverse

user-defined characteristic

A

i

I_SETP

1

B

k

Time factor of inverse time, A 0.001 to 200.0s, step 0.001s

Delay of inverse time, B 0.000 to 60.00s, step 0.01s

Index of inverse time, P 0.005 to 10.00, step 0.005

set time Multiplier for step n: k 0.05 to 999.0, step 0.01

Time of definite time stage

Operating time 40ms, at 1.2 times of set value

Time of inverse time stage

Minimum operating time 20ms

Maximum operating time 100s

Tolerance of definite time stage


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Current pickup 3% of set value or 0.02Ir

Angle 3

Time delay 1% set value or 40ms

Tolerance of inverse time stage


Angle 3

Time delays 5% set value + 40ms

Earth fault protection (ANSI 50N, 51N, 67N)

Setting range


0.25 A to 100.00 A, when Ir=5A


Directional element

Operating area range 80 from characteristic bisector

Characteristic angle 0 to 90, step 1

Voltage threshold of zero-sequence directional

element3U0= 1 V

Voltage threshold of Negative-sequence directional

element3U2 =2 V

Current threshold of zero-sequence directional

element3I0= 0.08In

Current threshold of Negative-sequence directional

element3I2= 0.08In



Very inverse

Extremely inverse

Long inverse

ANSI Inverse

Short inverse

Long inverse

Moderately inverse

Very inverse

Extremely inverse

Definite inverse

user-defined characteristic A iI_SETP 1 B k




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Angle 3




Angle 3


Emergency/backup overcurrent protection (ANSI 50, 51)

Setting range


0.25 A to 100.00 A, when Ir=5A




Very inverse

Extremely inverse

Long inverse

ANSI Inverse

Short inverse

Long inverse

Moderately inverse

Very inverse

Extremely inverse

Definite inverse

user-defined characteristic A iI_SETP 1 B k






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Maximum operating time 100sTolerance of definite time stage






Emergency/backup earth fault protection (ANSI 50N, 51N)

Setting range


0.25 A to 100.00 A, when Ir=5A




Very inverse

Extremely inverse

Long inverse

ANSI Inverse

Short inverse

Long inverse

Moderately inverse

Very inverse

Extremely inverse

Definite inverse

user-defined characteristic

A

iI_SETP 1 B kTime factor of inverse time, A 0.001 to 200.0s, step 0.001s










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Current pickup 3% of set value or 0.02IrTime delays 5% set value + 40ms


Setting range

Upper function limit (setting range)

Max current for inrush restraint

0.25 A to 20 A , when Ir=1A

1.25 A to 100 A, when Ir=5A

Ratio of 2nd

harmonic current to fundamental

component current

0.10 to 0.45, step 0.01

Cross-block (IL1, IL2, IL3) (settable time) 0.00s to 60.00 s, step 0.01s

Switch-onto-fault protection (ANSI 50HS)

Setting range

Range of phase overcurrent 0.05 A to 20 A , when Ir=1A


Range of zero-sequence current 0.05 A to 20 A , when Ir=1A


Delay time of phase overcurrent 0.00s to 60.00s, step 0.01s

Delay time of zero-sequence current 0.00s to 60.00s, step 0.01s


Current pickup 3% setting or 0.02Ir

Time delays 1% setting or +40ms

Breaker failure protection (ANSI 50 BF)

Setting range

Pickup of

phase current

Negative sequence current

zero sequence current

0.05 A to 20 A , when Ir=1A


Delay time of stage 1 0.00s to 32.00 s, step 0.01s

Delay time of stage 2 0.10s to 32.00 s, step 0.01s

Tolerances

Pickup 3% of set value or 0.02Ir


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D

csc-101 line protection ied protection guide

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