CSC-103Line Protection IED

Product Guide

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Feature

2

Protection and monitoring IED with

extensive functional library, user

configuration possibility and expandable

hardware design to meet with user’s

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 startup

element

Overcurrent 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

Line differential protection (87L):

Phase-segregated measurement

with high sensitivity

Charging current compensation

High reliability against external fault

with CT saturation detection

Automatic conversion of CT ratios

Time synchronization of sampling

Redundant communication

channels without channel switching

delay

Full scheme phase-to-phase and

phase-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 power

swing

All useful types of tele-protection

scheme (85)

Permissive Underreach Transfer

Trip (PUTT) scheme

Permissive Overreach Transfer Trip

(POTT) scheme

Blocking scheme

Inter-tripping scheme

Particular logic for tele-protection

scheme

Feature

3

Current reversal

Weak-infeed end

Evolving fault logic

Sequence tripping logic

A complete protection functions library,

include:

Line differential protection (87L)

Distance protection with

quadrilateral characteristic

(21,21N)

Power swing function (68)

Tele-protection scheme based on

distance protection (85-21,21N)

Tele-protection scheme based on

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

(50SOTF)

Overload protection (50OL)

Overvoltage protection (59)

Undervoltage protection (27)

Circuit breaker failure protection

(50BF)

Poles discordance protection

(50PD)

Dead zone protection (50DZ)

STUB protection (50STUB)

Synchro-check and energizing

check (25)

Auto-reclosing 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 remote

communication ports for protection

function, like differential protection,

distance and EF tele-protection,

used up to 100kM single–mode

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

selected to communicate with substation

automation system by IEC60870-5-103

Feature

4

protocol

Time synchronization via network

(SNTP), pulse and IRIG-B mode

Configurable LEDs (Light Emitting

Diodes) and output relays satisfied users’

requirement

Versatile human-machine interface

Multifunctional software tool for setting,

monitoring, fault recording analysis,

configuration, etc.

Function

5

Protection functions

Description ANSI Code

IEC 61850

Logical Node

Name

IEC 60617

graphical symbol

Differential protection

Line differential protection 87L PDIF

Distance protection

Distance protection 21, 21N PDIS Z<

Power-swing function 68 RPSB Zpsb

Tele-protection

Communication scheme for distance

protection 85–21,21N PSCH

Communication scheme for earth fault

protection 85–67N PSCH

Current protection

Overcurrent protection 50,51,67 PTOC

3IINV>

3I >>

3I >>>

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

I0INV>

I0>>

I0>>>

Emergency/backup overcurrent protection 50,51 PTOC 3IINV>

3I >

Emergency/backup earth fault protection 50N,51N PTEF I0INV>

I0 >

Switch-onto-fault protection 50SOTF PSOF 3I >SOTF

I0>SOTF

Overload protection 50OL PTOC 3I >OL

Voltage protection

Overvoltage protection 59 PTOV 3U>

3U>>

Undervoltage protection 27 PTUV 3U<

3U<<

Breaker protection and control function

Circuit breaker failure protection 50BF RBRF 3I> BF

Function

6

I0>BF

I2>BF

Dead zone protection 50DZ

3I> DZ

I0>DZ

I2>DZ

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-reclosing 79 RREC O→I

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

Function

7

Station communication

Description

Front communication port

Isolated RS232 port for maintaining

Rear communication port

0-2 isolated electrical RS485 communication ports, support IEC 60870-5-103 protocol

0-3 Ethernet electrical/optical communication ports, support IEC 61850 protocol or IEC 60870-5-103

protocol

Time synchronization port, support GPS pulse or IRIG-B code

Remote communication

Description

Communication port

Contact(s) interface for power line carrier for tele-protection

0– 2 fiber optical communication port(s) for line differential protection or tele-protection

Connection mode

Direction fiber cable connection

Digital communication network through converter

IED software tools

Functions

Reading measuring value, IED report

Setting

IED testing

Disturbance recording analysis

IED configuration

Printing

Function

8

Protection

9

Startup elements

The startup elements basically work as

sensitive detector to all types of fault. 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 are four

kinds of startup elements listed below,

which are used to enhance the sensitivity,

and to guarantee the security in case of

IED’s internal hardware faults.

Sudden-change current startup 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 startup element

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, overcurrent startup element is

used to improve the fault detection

sensitivity. As an auxiliary startup element,

it operates with short time delay.

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 scheme with weak-echo

logic.

Phase selector

The IED applies different phase selectors

to determine the faulty phase to make

tripping or Auto-reclosing initiation

correctly. There are three kinds of phase

selectors based on different principle for

different fault stages.

Sudden-change current phase selector

It operates as soon as the sudden- change

current startup element starts up. It makes

a phase selection for fast tripping by

Protection

10

comparison amongst changes of

phase-phase currents, iAB, iBC and

iCA.

Symmetrical component phase selector

During the whole period of fault, the phase

selector checks the angle between

negative sequence current and zero

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 directional element

The IED uses the memory voltage and

fault current to determine the direction of

the fault. Therefore transient voltage of

short circuit conditions doesn’t influence

the direction detection. Additionally, it

improves the direction detection sensitivity

for symmetrical or asymmetrical close-in

faults with extremely low voltage. But it

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 component directional 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 of power

system, regardless of the quantity of load

current and/or fault resistance throughout

the fault. The characteristic of the zero

sequence directional element is illustrated

in Figure 1

Figure 1 Characteristic of zero sequence

directional element where:

Ф0_Char: The settable characteristic angle

Negative sequence component directional element

Protection

11

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 2.

Forward

Φ2_Char

Bisector

Figure 2 Characteristic of negative sequence

directional element

where:

Ф2_Char: The settable characteristic angle

Impedance directional elements

The characteristic of the impedance

directional element (shown in Figure 3) is

same with that of distance protection.

Figure 3 Direction detection characteristic of

impedance directional element

where:

RSET: The resistance setting of relevant 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

Line differential protection (87L)

The line differential protection consists of

three protection functions, phase

segregated differential protection function,

sudden change current differential

protection function and zero sequence

current differential protection function.

These three functions are associated to

achieve high sensitivity and reliability with

capacitive charge current compensation

and reliable phase selection during various

system disturbances. The precise time

synchronization of sampling ensures the

Protection

12

differential protection of both end IEDs to

operate reliably.

Phase-segregated current differential protection

The protection provides two-slope percent

differential characteristic, as shown in

Figure 4.

Figure 4 Characteristic of phase-segregated

current differential protection

where:

IDiff : Differential currents, calculated

separately in each phase

IRes : Restraining currents calculated

separately in each phase

K1 = 0.6

K2 = 0.8

I_1Diff= 1 I_Set

I_2Diff= 3 I_Set

I_1Res= 3 I_Set

I_2Res= 5 I_Set

I_Set= I_LDiff High, the different current high setting

The differential current IDiff and the

restraining current IRes are calculated in

the IED using the measured current

flowing through both ends of the protected

feeder (end M and end N), according to

following formula:

| |

| |

where:

IMC and INC: The capacitive charging current in each phase of the protected line, which are calculated from the measured voltage in each end of the line

The characteristics can be described with

following formula:

_ 1 , 3 _ 2 _ , _

Sudden-change current differential protection

The sudden-change current differential

protection calculates the fault current only,

the sudden change variable part of whole

current. Without influence of load current,

the protection function has high sensitivity,

especially, to fault through arc resistance

on heavy load line. However, for the

sudden change current, the variable will

fade out quickly in short time. Thus the

whole current differential protection

presented above is still needed to cover

entire fault detection and clearance period.

The differential characteristic is shown in

Figure 5.

Protection

13

Figure 5 Characteristic of sudden-change

current differential protection

where:

∆IDiff : Sudden-change of differential currents

∆IRes : Sudden-change of restraining currents

K1 = 0.6

K2 = 0.8

∆I_1Diff= 1 I_Set

∆I_2Diff= 3 I_Set

∆I_1Res= 3 I_Set

∆I_2Res= 5 I_Set

I_Set: I_LDiff High, the different current high setting

∆IDiff and ∆IRes are calculated by using

the calculated change in current flowing

through both ends of the protected feeder

(end M and end N) in each phase

according to the following formula.

∆ |∆ ∆ |

∆ |∆ ∆ |

∆IM : Variable of current flowing toward the protected feeder from end M

∆IN : Variable of current flowing toward the protected feeder from end N

The characteristics can be described with

following formula:

∆ _∆ ∆ , ∆ _

∆ ∆ _ , ∆ _

Zero-sequence current differential protection

As a complement to phase segregated

differential protection, the zero sequence

current differential protection is used to

enhance the sensitivity on the earth fault

through high arc resistance. It always

clears the fault after a delay time. The

protection provides one slope percent

differential characteristic, as shown in

Figure 6.

I_0Diff

Operating area

K

Figure 6 Characteristic of zero-sequence current

differential protection

where:

I0Diff: Zero sequence differential currents

I0Res : Zero sequence restraining currents

K=0.75

I_0Diff: I_LDiffZeroSeq, the zero sequence differential current setting

Protection

14

The differential current I0Diff and the

restraining current I0Res are calculated in

the IED using the measured current

flowing through both sides of the protected

feeder (End M and N) according to

following formula.

∆ |

|

∆ |

|

where:

IMx and INx: the measured currents of phase x flowing toward the protected object in ends M and N, respectively

IMxC and INxC: the capacitive charging currents calculated for phase x in ends M and N, respectively

x: represents Phase A, B or C

The characteristics can be described with

following formula:

∆ _

Capacitive current compensation

In the IED, both ends voltages are

employed to compensate capacitive

current accurately to enhance the

sensitivity of current differential protection

using the well-known half compensation

method.

CT saturation discrimination

Based on current waveform principle, the

protection can discriminate the CT

saturation condition. Once under this

condition, the protection will use a new

differential and restraint characteristic

shown in Figure 7 to guarantee the security

of the protection.

Figure 7 Characteristic of phase segregated

differential protection at CT saturation

where:

ILDiffCT= Max (I_LDiff, 0.5Ir)

Ir: The CT secondary rated current

K=0.9

Tele-transmission binary signals

In the IED, two binary signals can be

transmitted to the remote end of the line in

the binary bits of each data frame, which

are tele-transmission command 1 and

tele-transmission command 2. When the

remote IED receives the signals, relevant

operation will be performed.

Direct transfer trip

In the IED, one binary input is provided for

remote trip to ensure the remote IED fast

tripping when fault occurs between CT and

circuit breaker, or in case of a breaker

failure. It is used to transmit the trip

command of dead zone protection or

circuit breaker failure protection to trip the

opposite end circuit breaker.

Protection

15

Time synchronization of Sampling

The differential protection of both end IEDs

can be set as master or slave mode. If one

IED is set as master, the IED at the other

end should be set as slave. To ensure

sampling synchronization between both

IEDs, the salve IED sends a frame of

synchronization request to master IED.

After the master IED receives the frame, it

returns a frame of data including its local

time. Then the slave IED can calculate

both the communication delay time and the

sampling time difference with the master

IED. Thus, the slave IED adjusts its

sampling time and the IEDs of both ends

come to complete sampling

synchronization.

Redundant remote communication channels

The differential protection is able to receive

data from the redundant remote

communication channels in parallel. When

one of the channels is broken, there is no

time delay for primary channel switching.

Switch onto fault protection function

Under either auto reclosing or manual

closing process, the protection function is

able to discriminate these conditions to

give an instantaneous tripping once closing

on permanent faulty line.

Distance protection (21, 21N)

The transmission line 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 8.

Additionally, one extension zone is

employed to co-operate with Auto-

-reclosing 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 8 Distance protection zones

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 9.

Protection

16

Figure 9 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 fault. Subscript 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

X_ZnPE: Reactance reach setting for phase

to earth fault

Φ_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

Φ_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

Φ_ZRight: The right boundary angle of

characteristic in the first quadrant is used

to deal with load encroachment problems

Φ_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 operating characteristic

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 10) 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 10 Extended polygonal distance

protection zone characteristic

Protection

17

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 11.

Figure 11 Characteristic distance protection

reverse zone

Switch-onto- fault protection 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.

Power swing (68)

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 ms after 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 unblocking logic

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.

Protection

18

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.

Tele-protection scheme for distance protection (85-21)

To achieve non-delayed and selective

tripping 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

Sequence tripping 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 communication scheme

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 scheme for earth 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 for distance

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

Protection

19

Sequence tripping 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 segregated communication scheme

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.

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 the

overcurrent 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 direction element

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

Protection

20

between the fault current and the reference

voltage, Figure 12 illustrates the direction

detection characteristic for phase A

element.

Forward

ΦPh_Char

Bisector

Figure 12 Direction detection characteristic of

overcurrent protection directional element

where:

ФPh_Char: The settable characteristic angle

The assignment of the applied measuring

values used in direction determination has

been shown in Table 1 for different types of

faults.

Table 1 Assignment of applied current and

reference voltage for directional element

Phase Current Voltage

A aI bcU

B bI caU

C cI abU

For three-phase short-circuit fault, without

any healthy phase, memory voltage 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:

Two definite time stages

One inverse time stage

11 kinds of the IEC and ANSI inverse

time characteristic curves as well as

optional user defined characteristic

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 as

directional/non-directional

Settable directional element

characteristic angle, to satisfy the

different network conditions and

applications

Each stage can be set individually for

inrush restraint

Settable maximum inrush current

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

Protection

21

Zero-sequence current is measured

from earth phase CT

Directional element

The earth fault protection adopts zero

sequence directional element which

compares the zero sequence system

quantities:

3I0, current is measured from earth

phase CT

3U0, the voltage is used as reference

voltage. It is calculated from the sum of

the three phase voltages

Figure 13 Direction detection characteristic of

zero sequence directional element

where:

Ф0_Char: The settable characteristic angle

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 sequence

voltage due to some fault condition e.g. the

unfavorable zero-sequence voltage. The

negative sequence directional element

characteristic is shown in Figure 14.

Figure 14 Direction detection characteristic of

negative sequence directional element

where:

Ф2_Char: The settable characteristic angle

Furthermore, under the VT failure situation,

it can be set to block directional earth fault

protection.

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 doesn’t

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 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.

Protection

22

Emergency/backup overcurrent protection (50, 51)

In the case of VT fail condition, all distance

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 user’s

requirement.

The protection provides following features:

One definite time stage

One inverse time stage

11 kinds of IEC and ANSI inverse

characteristics curve as well as

optional user defined characteristic

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 functions related 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 user’s

requirement.

The protection provides following features:

One definite time stage

One inverse time stage

11 kinds of IEC and ANSI inverse

characteristics curve as well as

optional user defined characteristic

Inrush restraint can be selected

individually for each stage

Settable maximum inrush current

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 (50SOTF)

The protection gives a trip when the circuit

breaker is closed manually onto a short

circuited line.

The protection provide following features:

One definite time overcurrent stage

One definite time earth fault protection

stage

Inrush restraint can be selected

Cross blocking for inrush detection

Settable maximum inrush current

Manual closing binary input detection

Protection

23

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 voltage

conditions. 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:

Two definite time stages

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.

The protection provides following features:

Two definite time stages

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.

The protection can be single- or three-

-phase started to allow use with single or

three-phase tripping applications.

Once a circuit breaker operating failure

occurs 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 signal is

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.

Protection

24

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 (50DZ)

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 15.

Figure 15 Tripping logic, 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 16.

Figure 16 Tripping logic, applying line side CT

Protection

25

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 dis-

-connector. 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 17.

Figure 17 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 system

normal 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 the both side voltages of the circuit breaker for 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 if

energizing check failure

Override

Protection

26

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-reclosing (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, the protection will re-trip the

breaker. Main features of the

Auto-reclosing are as follows:

Up to 4 shots (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

Secondary system supervision

Current transformer secondary circuit supervision

Open or short circuited CT cores can

cause unwanted operation of some

protection functions such as differential,

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.

Furthermore, when the zero-sequence

current is always lager than the setting

value of “3I0_CT Fail” for 12s while one

phase current is less than a low current

threshold, or the calculated differential

current of both sides is always lager than a

threshold for 12s while one phase current

is less than the low current threshold, an

alarm will be reported. Blocking current

differential protection or not can be set in

this condition. If blocking is selected, it can

be decided further to blocking three

phases or only blocking the faulty phase.

Voltage transformer secondary circuit 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

Protection

27

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

Monitoring

28

Phase-sequence of voltage and current 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 voltage supervision

If the third harmonic voltage is excessive,

the alarm without blocking protection will

be given with delay time for checking of the

secondary circuit of voltage transformer.

Auxiliary contacts of circuit breaker 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 alarm

or 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 function giving the distance

from the IED measuring location to the

fault position in km. The IED reports fault

location after the IED tripping.

Communication

29

Station communication

Overview

The IED is able to connect to one or

more substation level systems or

equipments simultaneously, through the

communication ports with communica-

-tion protocols supported. (Shown in

Figure 18)

Front communication port

There is a serial RS232 port on the front

plate of all the IEDs. Through this port,

the IED can be connected 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 communication ports

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 18 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

Communication

30

All IEDs 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 synchro-

-nization can be applied.

The

Figure 19 illustrates the optional time

synchronization modes.

SNTP IRIG-B Pulse

Ethernet port IRIG-B port Binary input

Figure 19 Time synchronizing modes

Remote communication

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 schemes, e.g., POTT or

PUTT schemes, blocking scheme and inter

trip and so on.

Remote communication channel

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 20 and Figure 21)

Through the communication converter

with G.703 or G.703E1 interface

through the public digital communica-

-tion network (see Figure 22 and Figure

23)

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 21, Figure 23 and Figure 24).

Communication

31

Figure 20 Single channel, communication through dedicated fiber optical cable

Figure 21 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 require-

-ment of the multiplexed communication

network.

Figure 22 Single Channel, communication through digital communication network

Communication

32

Figure 23 Double channels, communication through digital communication network

Figure 24 Double channels, one channel through digital communication network, one channel

through dedicated fiber optical cables

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Hardware

34

Front plate

The whole front plate is divided into

zones, each of them with a well-defined

functionality:

Figure 25 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

Rear plate

Figure 26 Rear plate of the protection IED

Hardware

35

Modules

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 different hardware.

They work in parallel and interlock each

other to prevent maloperation due to the

internal faults of one CPU modules.

The CPU1 provides compatible data ports

with 64kbps and 2Mbps used for

differential protection, which can be

configured 1or 2 data ports according to

requirement. There are two versions for

CPU1 with single channel or double

channel. The double channel CPU1 is

compatible completely with single channel

CPU1.

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 connect

the 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.

Hardware

36

Dimension

Figure 27 4U, 19” case with rear cover

Table 2 Dimension of the IED case

Legend A B C D E

Dimension (mm) 177 482.6 265 320 437.2

Figure 28 Cut-out on the panel

Table 3 Dimension of the cutout for IED mounting

Legend A B C D E

Dimension (mm) 450 465 103.6 178 6.5

Connection

37

A. Typical rear terminal diagram

X1

CSC-103a01

IAb01a02

IBb02a03

ICb03a04

I0b04a05

I4b05

a10U4

b10

a09

UB

b09

UCUA

a11b11a12b12 UN

NullNull

X5a02

BI02 c02BI03 a04BI04 c04BI05 a06BI06 c06BI07 a08BI08 c08BI09 a10

BI01

BI10 c10BI11 a12BI12 c12BI13 a14BI14 c14BI15 a16BI16 c16BI17 a18BI18 c18BI19 a20BI20 c20BI21 a22BI22 c22BI23 a24BI24 c24BI25 a26BI26 c26BI27 a28BI28 c28BI29 a30BI30 c30

a32c32

BI-COM1(-)BI-COM2(-)

X4123456789

10111213141516

Ethernet Port 1 - RJ45

Ethernet Port 2 - RJ45

NullNullNullRS485 - 2BRS485 - 2ARS485 - 1BRS485 - 1AGPS

Null

GPS - GNDNullNullNullNullNullNull

X6a02c02a04c04a06c06a08c08a10c10a12c12a14c14a16c16a18c18a20c20a22c22a24c24a26c26a28c28a30c30a32c32

2)

Ethernet Port 1 - ST

Ethernet Port 2 - ST

Note:1) The optical fiber port is optional for redundant communi--cation channels requirement.2) Alternative Ethernet ports for station communication are 2 ST optical fiber ports, shown as following,

a06b06a07b07a08b08

NullNull

NullNull

NullNull

RX connector of optical fiber port 1

X2

Output relay 01

Output relay 02

Output relay 03

Output relay 04

Output relay 05

Output relay 06

Output relay 07

Output relay 08

Output relay 09

Output relay 10

Output relay 11

Output relay 12

Output relay 13

Output relay 14

Output relay 15

Output relay 16

1)

TX connector of optical fiber port 1

RX connector of optical fiber port 2

TX connector of optical fiber port 2

Connection

38

Connection

39

Connection

40

B. Typical analogue inputs connection for one breaker of single or double busbar arrangement

Connection

41

C. Typical analogue inputs connection for one and half breaker arrangement

Technical data

42

Frequency

Item Standard Data

Rated system frequency IEC 60255-1 50 Hz or 60Hz

Internal current transformer

Item Standard Data

Rated current Ir IEC 60255-1 1 or 5 A

Nominal current range 0.05 Ir to 30 Ir

Nominal current range of sensitive

CT

0.005 to 1 A

Power consumption (per phase) ≤ 0.1 VA at Ir = 1 A;

≤ 0.5 VA at Ir = 5 A

≤ 0.5 VA for sensitive CT

Thermal overload capability IEC 60255-1

IEC 60255-27

100 Ir for 1 s

4 Ir continuous

Internal voltage transformer

Item Standard Data

Rated voltage Vr (ph-ph) IEC 60255-1 100 V /110 V

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

Power consumption at Vr = 110 V IEC 60255-27

DL/T 478-2001

≤ 0.1 VA per phase

Thermal overload capability

(phase-neutral voltage)

IEC 60255-27

DL/T 478-2001

2 Vr, for 10s

1.5 Vr, continuous

Auxiliary voltage

Item Standard Data

Rated auxiliary voltage Uaux IEC60255-1 110 to 250V

Permissible tolerance IEC60255-1 ±%20 Uaux

Power consumption at quiescent

state

IEC60255-1 ≤ 50 W per power supply module

Power consumption at maximum

load

IEC60255-1 ≤ 60 W per power supply module

Technical data

43

Inrush Current IEC60255-1 T ≤ 10 ms/I≤ 25 A per power supply

module,

Binary inputs

Item Standard Data

Input voltage range IEC60255-1 110/125 V

220/250 V

Threshold1: guarantee

operation

IEC60255-1 154V, for 220/250V

77V, for 110V/125V

Threshold2: uncertain operation IEC60255-1 132V, for 220/250V ;

66V, for 110V/125V

Response time/reset time IEC60255-1 Software provides de-bounce

time

Power consumption, energized IEC60255-1 Max. 0.5 W/input, 110V

Max. 1 W/input, 220V

Binary outputs

Item Standard Data

Max. system voltage IEC60255-1 250V /~

Current carrying capacity IEC60255-1 5 A continuous,

30A，200ms ON, 15s OFF

Making capacity IEC60255-1 1100 W( ) at inductive load with

L/R>40 ms

1000 VA(AC)

Breaking capacity IEC60255-1 220V , 0.15A, at L/R≤40 ms

110V , 0.30A, at L/R≤40 ms

Mechanical endurance, Unloaded IEC60255-1 50,000,000 cycles (3 Hz switching

frequency)

Mechanical endurance, making IEC60255-1 ≥1000 cycles

Mechanical endurance, breaking IEC60255-1 ≥1000 cycles

Specification state verification IEC60255-1

IEC60255-23

IEC61810-1

UL/CSA、TŰV

Technical data

44

Contact circuit resistance

measurement

IEC60255-1

IEC60255-23

IEC61810-1

30mΩ

Open Contact insulation test (AC

Dielectric strength)

IEC60255-1

IEC60255-27

AC1000V 1min

Maximum temperature of parts and

materials

IEC60255-1 55

Front communication port

Item Data

Number 1

Connection Isolated, RS232; front panel,

9-pin subminiature connector, for software tools

Communication speed 9600 baud

Max. length of communication cable 15 m

RS485 communication port

Item Data

Number 0 to 2

Connection 2-wire connector

Rear port in communication module

Max. length of communication cable 1.0 km

Test voltage 500 V AC against earth

For IEC 60870-5-103 protocol

Communication speed Factory setting 9600 baud,

Min. 1200 baud, Max. 19200 baud

Ethernet communication port

Item Data

Electrical communication port

Number 0 to 3

Connection RJ45 connector

Rear port in communication module

Max. length of communication cable 100m

For IEC 61850 protocol

Technical data

45

Communication speed 100 Mbit/s

For IEC 60870-5-103 protocol

Communication speed 100 Mbit/s

Optical communication port ( optional )

Number 0 to 2

Connection SC connector

Rear port in communication module

Optical cable type Multi-mode

Max. length of communication cable 2.0km

IEC 61850 protocol

Communication speed 100 Mbit/s

IEC 60870-5-103 protocol

Communication speed 100 Mbit/s

Time synchronization

Item Data

Mode Pulse mode

IRIG-B signal format IRIG-B000

Connection 2-wire connector

Rear port in communication module

Voltage levels differential input

Fiber optic communication ports for remote communication

Item Data

Number 1 to 2

Fiber optic cable type Single-mode

Optic wavelength 1310nm, when the transmission distance <60km;

1550nm, when the transmission distance >60km

Optic received sensitivity -38dBm

Emitter electric level >-8dBm; (the transmission distance <40km)

>-4dBm; (the transmission distance 40～60km)

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

Fiber optic connector type FC, when the transmission distance <60km)

SC, when the transmission distance >60km

Data transmission rate 64 kbit/s, G703;

2,048 kbit/s, G703-E1

Max. transmission distance 100kM

Technical data

46

Environmental influence

Item Data

Recommended permanent operating temperature -10 °C to +55°C

(Legibility of display may be impaired above

+55 °C /+131 °F)

Storage and transport temperature limit -25°C to +70°C

Permissible humidity 95 % of relative humidity

IED design

Item Data

Case size 4U×19inch

Weight ≤ 10kg

Technical Data

47

Product safety-related Tests

Item Standard Data

Over voltage category IEC60255-27 Category III

Pollution degree IEC60255-27 Degree 2

Insulation IEC60255-27 Basic insulation

Degree of protection (IP) IEC60255-27

IEC 60529

Front plate: IP40

Rear, side, top and bottom: IP 30

Power frequency high voltage

withstand test

IEC 60255-5

EN 60255-5

ANSI C37.90

GB/T 15145-2001

DL/T 478-2001

2KV, 50Hz

2.8kV

between the following circuits:

auxiliary power supply

CT / VT inputs

binary inputs

binary outputs

case earth

500V, 50Hz

between the following circuits:

Communication ports to case

earth

time synchronization terminals

to case earth

Impulse voltage test IEC60255-5

IEC 60255-27

EN 60255-5

ANSI C37.90

GB/T 15145-2001

DL/T 478-2001

5kV (1.2/50μs, 0.5J)

If Ui≥63V

1kV if Ui<63V

Tested between the following

circuits:

auxiliary power supply

CT / VT inputs

binary inputs

binary outputs

case earth

Note: Ui: Rated voltage

Insulation resistance IEC60255-5

IEC 60255-27

EN 60255-5

ANSI C37.90

GB/T 15145-2001

≥ 100 MΩ at 500 V

Technical Data

48

DL/T 478-2001

Protective bonding resistance IEC60255-27 ≤ 0.1Ω

Fire withstand/flammability IEC60255-27 Class V2

Electromagnetic immunity tests

Item Standard Data

1 MHz burst immunity test IEC60255-22-1

IEC60255-26

IEC61000-4-18

EN 60255-22-1

ANSI/IEEE C37.90.1

Class III

2.5 kV CM ; 1 kV DM

Tested on the following circuits:

auxiliary power supply

CT / VT inputs

binary inputs

binary outputs

1 kV CM ; 0 kV DM

Tested on the following circuits:

communication ports

Electrostatic discharge IEC 60255-22-2

IEC 61000-4-2

EN 60255-22-2

Level 4

8 kV contact discharge;

15 kV air gap discharge;

both polarities; 150 pF; Ri = 330 Ω

Radiated electromagnetic field

disturbance test

IEC 60255-22-3

EN 60255-22-3

Frequency sweep:

80 MHz – 1 GHz; 1.4 GHz – 2.7 GHz

spot frequencies:

80 MHz; 160 MHz; 380 MHz; 450

MHz; 900 MHz; 1850 MHz; 2150

MHz

10 V/m

AM, 80%, 1 kHz

Radiated electromagnetic field

disturbance test

IEC 60255-22-3

EN 60255-22-3

Pulse-modulated

10 V/m, 900 MHz; repetition rate

200 Hz, on duration 50 %

Electric fast transient/burst immunity

test

IEC 60255-22-4,

IEC 61000-4-4

EN 60255-22-4

ANSI/IEEE C37.90.1

Class A, 4KV

Tested on the following circuits:

auxiliary power supply

CT / VT inputs

binary inputs

binary outputs

Technical Data

49

Class A, 1KV

Tested on the following circuits:

communication ports

Surge immunity test IEC 60255-22-5

IEC 61000-4-5

4.0kV L-E

2.0kV L-L

Tested on the following circuits:

auxiliary power supply

CT / VT inputs

binary inputs

binary outputs

500V L-E

Tested on the following circuits:

communication ports

Conduct immunity test IEC 60255-22-6

IEC 61000-4-6

Frequency sweep: 150 kHz – 80

MHz

spot frequencies: 27 MHz and 68

MHz

10 V

AM, 80%, 1 kHz

Power frequency immunity test IEC60255-22-7 Class A

300 V CM

150 V DM

Power frequency magnetic field test IEC 61000-4-8 Level 4

30 A/m cont. / 300 A/m 1 s to 3 s

100 kHz burst immunity test IEC61000-4-18 2.5 kV CM ; 1 kV DM

Tested on the following circuits:

auxiliary power supply

CT / VT inputs

binary inputs

binary outputs

1 kV CM ; 0 kV DM

Tested on the following circuits:

communication ports

DC voltage interruption test

Item Standard Data

DC voltage dips IEC 60255-11 100% reduction 20 ms

Technical Data

50

60% reduction 200 ms

30% reduction 500 ms

DC voltage interruptions IEC 60255-11 100% reduction 5 s

DC voltage ripple IEC 60255-11 15%, twice rated frequency

DC voltage gradual shut–down

/start-up

IEC 60255-11 60 s shut down ramp

5 min power off

60 s start-up ramp

DC voltage reverse polarity IEC 60255-11 1 min

Electromagnetic emission test

Item Standard Data

Radiated emission IEC60255-25

EN60255-25

CISPR22

30MHz to 1GHz ( IT device may up

to 5 GHz)

Conducted emission IEC60255-25

EN60255-25

CISPR22

0.15MHz to 30MHz

Mechanical tests

Item Standard Data

Sinusoidal Vibration response

test

IEC60255-21-1

EN 60255-21-1

Class 1

10 Hz to 60 Hz: 0.075 mm

60 Hz to 150 Hz: 1 g

1 sweep cycle in each axis

Relay energized

Sinusoidal Vibration endurance

test

IEC60255-21-1

EN 60255-21-1

Class 1

10 Hz to 150 Hz: 1 g

20 sweep cycle in each axis

Relay non-energized

Shock response test IEC60255-21-2

EN 60255-21-2

Class 1

5 g, 11 ms duration

3 shocks in both directions of 3 axes

Relay energized

Shock withstand test IEC60255-21-2

EN 60255-21-2

Class 1

15 g, 11 ms duration

3 shocks in both directions of 3 axes

Technical Data

51

Relay non-energized

Bump test IEC60255-21-2 Class 1

10 g, 16 ms duration

1000 shocks in both directions of 3

axes

Relay non-energized

Seismic test IEC60255-21-3 Class 1

X-axis 1 Hz to 8/9 Hz: 7.5 mm

X-axis 8/9 Hz to 35 Hz :2 g

Y-axis 1 Hz to 8/9 Hz: 3.75 mm

Y-axis 8/9 Hz to 35 Hz :1 g

1 sweep cycle in each axis,

Relay energized

Climatic tests

Item Standard Data

Cold test - Operation IEC60255-27

IEC60068-2-1

-10°C, 16 hours, rated load

Cold test – Storage IEC60255-27 IEC60068-2-1 -25°C, 16 hours

Dry heat test – Operation [IEC60255-27

IEC60068-2-2

+55°C, 16 hours, rated load

Dry heat test – Storage IEC60255-27

IEC60068-2-2

+70°C, 16 hours

Change of temperature IEC60255-27

IEC60068-2-14

Test Nb, figure 2, 5 cycles

-10°C / +55°C

Damp heat static test IEC60255-27

IEC60068-2-78

+40°C, 93% r.h. 10 days, rated load

Damp heat cyclic test IEC60255-27

IEC60068-2-30

+55°C, 93% r.h. 6 cycles, rated load

CE Certificate

Item Data

EMC Directive EN 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).

Technical Data

52

Functions

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

Line differential protection (ANSI 87L)

Setting range

Differential current pickup 0.1Ir～2Ir

Time

Operating time ≤ 20 ms, when fault current is 2 times setting value

Tolerance

Differential current pickup ≤±3% of setting value or ±0.02Ir

Distance protection (ANSI 21, 21N)

Item Rang or Value Tolerance

Number of settable zone 5 zones ， with additional

extended zone

Distance characteristic Polygonal

Resistance setting range 0.01Ω～120Ω, step 0.01Ω, when

Ir=5A;

0.05Ω～600Ω, step 0.01Ω, when

Ir=1A;

≤± 5.0% static accuracy

Conditions:

Voltage range: 0.01 Ur to 1.2 Ur

Current range: 0.12 Ir to 20 Ir

Reactance setting range 0.01Ω～120Ω, step 0.01Ω, when

Ir=5A;

0.05Ω～600Ω, step 0.01Ω, when

Ir=1A;

Time delay of distance zones 0.00 to 60.00s, step 0.01s ≤±1% or +20 ms, at 70%

operating setting and setting

time > 60ms

Operation time 22ms typically at 70% setting of

zone 1

Dynamic overreaching for zone 1 ≤±5%, at 0.5<SIR<30

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

Item Rang or Value Tolerance

Operating time 25ms typically in permission

Technical Data

53

mode for 21/21N, at 70% setting

Overcurrent protection (ANSI 50, 51, 67)

Item Rang or Value Tolerance

Definite time characteristics

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Time delay 0.00 to 60.00s, step 0.01s ≤ ±1% setting or +40ms, at 200% operating setting

Inverse time characteristics

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

IEC standard Normal inverse;

Very inverse;

Extremely inverse;

Long inverse

≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20, in accordance

with IEC60255-151

ANSI Inverse;

Short inverse;

Long inverse;

Moderately inverse;

Very inverse;

Extremely inverse;

Definite inverse

≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20, in

accordance with ANSI/IEEE

C37.112,

user-defined characteristic T=

_

B k ≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20, in accordance

with IEC60255-151

Time factor of inverse time, A 0.005 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

Minimum operating time 20ms

Maximum operating time 100s

Reset mode instantaneous

Directional element

Operating area range 170°　 ≤ ±3°, at phase to phase voltage >1V Characteristic angle 0° to 90°, step 1°

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

Item Rang or value Tolerance

Definite time characteristic

Technical Data

54

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Time delay 0.00 to 60.00s, step 0.01s ≤ ±1% setting or +40ms, at 200% operating setting

Inverse time characteristics

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

IEC standard Normal inverse;

Very inverse;

Extremely inverse;

Long inverse

IEC60255-151

≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20

ANSI Inverse;

Short inverse;

Long inverse;

Moderately inverse;

Very inverse;

Extremely inverse;

Definite inverse

ANSI/IEEE C37.112,

≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20

user-defined characteristic T=

_

B k IEC60255-151

≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20

Time factor of inverse time, A 0.005 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

Minimum operating time 20ms

Maximum operating time 100s

Reset mode instantaneous

Directional element

Operating area range of zero

sequence directional element 160°　

≤ ±3°, at 3U0≥1V

Characteristic angle 0° to 90°, step 1°

Operating area range of negative

sequence directional element 160°　

≤ ±3°, at 3U2≥2V

Characteristic angle 50° to 90°, step 1°

Emergency/backup overcurrent protection (ANSI 50, 51)

Item Rang or Value Tolerance

Definite time characteristics

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Technical Data

55

Time delay 0.00 to 60.00s, step 0.01s ≤ ±1% setting or +40ms, at 200% operating setting

Inverse time characteristics

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

IEC standard Normal inverse;

Very inverse;

Extremely inverse;

Long inverse

≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20, in accordance

with IEC60255-151

ANSI Inverse;

Short inverse;

Long inverse;

Moderately inverse;

Very inverse;

Extremely inverse;

Definite inverse

≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20, in

accordance with ANSI/IEEE

C37.112,

user-defined characteristic T=

_

B k ≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20, in accordance

with IEC60255-151

Time factor of inverse time, A 0.005 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

Minimum operating time 20ms

Maximum operating time 100s

Reset mode instantaneous

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

Item Rang or value Tolerance

Definite time characteristic

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Time delay 0.00 to 60.00s, step 0.01s ≤ ±1% setting or +40ms, at 200% operating setting

Inverse time characteristics

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

IEC standard Normal inverse;

Very inverse;

Extremely inverse;

Long inverse

≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20, in accordance with

IEC60255-151

ANSI Inverse; ≤ ±5% setting + 40ms, at 2

Technical Data

56

Short inverse;

Long inverse;

Moderately inverse;

Very inverse;

Extremely inverse;

Definite inverse

<I/ISETTING < 20, in accordance

with ANSI/IEEE C37.112,

user-defined characteristic T=

_

B k ≤ ±5% setting + 40ms, at 2

<I/ISETTING < 20, in accordance with

IEC60255-151

Time factor of inverse time, A 0.005 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

Minimum operating time 20ms

Maximum operating time 100s

Reset mode instantaneous

Inrush restraint function

Item Range or value Tolerance

Upper function limit

Max current for inrush restraint

0.25 Ir to 20.00 Ir ≤ ±3% setting value or ±0.02Ir

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 ≤ ±1% setting or +40ms

Switch-onto-fault protection (ANSI 50SOTF)

Item Rang or Value Tolerance

Phase current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Zero-sequence current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Time delay of phase overcurrent 0.00s to 60.00s, step 0.01s ≤ ±1% setting or +40ms, at

200% operating setting

Time delay of zero sequence

current

0.00s to 60.00s, step 0.01s ≤ ±1% setting or +40ms, at

200% operating setting

Technical Data

57

Breaker failure protection (ANSI 50 BF)

Item Rang or Value Tolerance

phase current

Negative sequence current

zero sequence current

0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Time delay of stage 1 0.00s to 32.00 s, step 0.01s ≤ ±1% setting or +25 ms, at

200% operating setting Time delay of stage 2 0.00s to 32.00 s, step 0.01s

Reset time of stage 1 < 20ms

Dead zone protection (ANSI 50DZ)

Item Rang or Value Tolerance

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Time delay 0.00s to 32.00s, step 0.01s ≤ ±1% setting or +40 ms, at

200% operating setting

Pole discordance protection (ANSI 50PD)

Item Rang or Value Tolerance

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Time delay 0.00s to 60.00s, step 0.01s ≤ ±1% setting or +40 ms, at

200% operating setting

STUB protection (ANSI 50STUB)

Item Rang or Value Tolerance

Current 0.08 Ir to 20.00 Ir ≤ ±3% setting or ±0.02Ir

Time delay 0.00s to 60.00s, step 0.01s ≤ ±1% setting or +40 ms, at

200% operating setting

Undervoltage protection (ANSI 27)

Item Rang or Value Tolerance

Voltage connection Phase-to-phase voltages or

phase-to-earth voltages

≤ ±3 % setting or ±1 V

Phase to earth voltage 5 to 75 V , step 1 V ≤ ±3 % setting or ±1 V

Phase to phase voltage 10 to 150 V, step 1 V ≤ ±3 % setting or ±1 V

Technical Data

58

Reset ratio 1.01 to 2.00, step 0.01 ≤ ±3 % setting

Time delay 0.00 to 120.00 s, step 0.01 s ≤ ±1 % setting or +50 ms, at 80%

operating setting

Current criteria 0.08 to 2.00 Ir ≤ ±3% setting or ±0.02Ir

Reset time ≤ 50 ms

Overvoltage protection (ANSI 59)

Item Rang or Value Tolerance

Voltage connection Phase-to-phase voltages or

phase-to-earth voltages

≤ ±3 % setting or ±1 V

Phase to earth voltage 40 to 100 V, step 1 V ≤ ±3 % setting or ±1 V

Phase to phase voltage 80 to 200 V, step 1 V ≤ ±3 % setting or ±1 V

Reset ratio 0.90 to 0.99, step 0.01 ≤ ±3 % setting

Time delay 0.00 to 60.00 s, step 0.01s ≤ ±1 % setting or +50 ms, at

120% operating setting

Reset time <40ms

Synchro-check and voltage check (ANSI 25)

Item Rang or Value Tolerance

Operating mode Synchronization check:

Synch-check

Energizing check, and synch-check if energizing check failure

Override

Energizing check:

Dead V4 and dead V3Ph

Dead V4 and live V3Ph

Live V4 and dead V3Ph

Voltage threshold of dead line or

bus

10 to 50 V (phase to earth), step

1 V

≤ ± 3 % setting or 1 V

Voltage threshold of live line or

bus

30 to 65 V (phase to earth), step

1 V

≤ ± 3 % setting or 1 V

∆V-measurement Voltage

difference

1 to 40 V (phase-to-earth), steps

1 V

≤ ± 1V

∆f-measurement (f2>f1; f2<f1) 0.02 to 2.00 Hz, step, 0.01 Hz, ≤ ± 20 mHz

∆α-measurement (α2>α1; 1 ° to 80 °, step, 1 ° ≤ ± 3°

Technical Data

59

α2<α1)

Minimum measuring time 0.05 to 60.00 s, step,0.01 s, ≤ ± 1.5 % setting value or +60

ms

Maximum synch-check

extension time

0.05 to 60.00 s, step,0.01 s, ≤ ± 1 % setting value or +50 ms

Auto-Reclosing (ANSI 79)

Item Rang or Value Tolerance

Number of reclosing shots Up to 4

Shot 1 to 4 is individually

selectable

AR initiating functions Internal protection functions

External binary input

Dead time, separated setting for

shots 1 to 4

0.05 s to 60.00 s, step 0.01 s ≤ ± 1 % setting value or +50 ms

Reclaim time 0.50 s to 60.00s, step 0.01 s

Blocking duration time (AR reset

time)

0.05 s to 60.00s, step 0.01 s

Circuit breaker ready supervision

time

0.50 s to 60.00 s, step 0.01 s

Dead time extension for

synch-check (Max. SYNT EXT)

0.05 s to 60.00 s, step 0.01 s

VT secondary circuit supervision (97FF)

Item Range or value Tolerances

Minimum current 0.08Ir to 0.20Ir, step 0.01A ≤ ±3% setting or ±0.02Ir

Minimum zero or negative

sequence current

0.08Ir to 0.20Ir, step 0.01A ≤ ±5% setting or ±0.02Ir

Maximum phase to earth voltage 7.0V to 20.0V, step 0.01V ≤ ±3% setting or ±1 V

Maximum phase to phase

voltage

10.0V to 30.0V, step 0.01V ≤ ±3% setting or ±1 V

Normal phase to earth voltage 40.0V to 65.0V, step 0.01V ≤ ±3% setting or ±1 V

Ordering

60

Pre-configure schemes

Table 4 Function and hardware of pre-configure scheme for transmission network

Pre-configure version M01 M02 M03 M04

Application Full,2 ends 2 ends 2 ends 2 ends

Breaker arrangement A or B or C A or B or C A or C B

Voltage level(kV) ≥ 230 ≥ 230 ≥ 230 ≥ 230

Line differential protection (87L) 1 1 1 1

Distance protection, 1 or 3 Pole Tripping

Mode (21, 21N) 1 1

Power-swing logic (68) 1 1

Communication scheme for distance

protection (85–21,21N) 1

Communication scheme for directional earth

fault protection (85–67N) 1

Overcurrent protection (50, 51, 67) 1 1 1 1

Earth-fault protection (50N, 51N, 67N) 1 1 1 1

Emergency/backup overcurrent protection

(50, 51) 1 1 1 1

Emergency/backup overcurrent protection

(50N, 51N) 1 1 1 1

Switch-onto-fault protection (50HS) 1 1 1 1

Overload protection (50OL) 1 1 1 1

Overvoltage protection (59) 1 1 1 1

Under voltage protection (27) 1 1 1 1

STUB protection (50STUB) 1 1 1

Breaker failure protection (50BF) 1 1 1

Dead zone protection (50SH-Z) 1 1 1

Poles discordance protection (50PD) 1 1 1

Synchro-check and energizing check (25) 1 1 1

Auto-reclosing, 1 or 3 Pole closing Mode (79) 1 1 1

Single and/or three pole tripping (94) 1 1 1 1

Ordering

61

CT secondary circuit supervision 1 1 1 1

VT secondary circuit supervision (97FF) 1 1 1 1

Fault locator 1 1

Analogue input module (5I + 4U) 1 1 1 1

CPU modules 2 2 2 2

Communication module(with Ethernet

interfaces, RS485 interfaces and time

synchronizing interface)

1 1 1 1

Binary input module (30 BI) 1 1 1 1

Binary output modules (16 relays for tripping

and initiation) 2 2 2 2

Binary output modules (16 relays for signal) 2 2 2 2

Power supply module 1 1 1 1

Programmable LEDs 18 18 18 18

Case, 4U,19” 1 1 1 1

NOTE:

n : Quantity of standard function or standard hardware, n= 1, 2, ….;

(n) : Quantity of optional function or optional hardware, n= 1, 2, ….;

A: Single busbar arrangement

B: breaker arrangement

C: Double busbar arrangement

Ordering

62

Table 5 Function and hardware of pre-configure scheme for sub-transmission network

Pre-configure version N01 N02 N03

Application 2 ends 2 ends 2 ends

Breaker arrangement A or B or C A or B or C B

Voltage level(kV) ≤ 132 ≤ 132 ≤ 132

Line differential protection (87L) 1 1 1

Distance protection, 3 Pole Tripping Mode (21, 21N) 1

Power-swing logic (68) 1

Communication scheme for distance protection (85–

21,21N) 1

Communication scheme for directional earth fault

protection (85–67N) 1

Overcurrent protection (50, 51, 67) 1 1 1

Earth-fault protection (50N, 51N, 67N) 1 1 1

Emergency/backup overcurrent protection (50, 51) 1 1 1

Emergency/backup overcurrent protection (50N,

51N) 1 1 1

Switch-onto-fault protection (50HS) 1 1 1

Overload protection (50OL) 1 1 1

Overvoltage protection (59) 1 1 1

Under voltage protection (27) 1 1 1

STUB protection (50STUB) 1 1

Breaker failure protection (50BF) 1 1

Dead zone protection (50SH-Z) 1 1

Poles discordance protection (50PD) 1 1

Synchro-check and energizing check (25) 1 1

Auto-reclosing, 3 Pole closing Mode (79) 1 1

Three pole tripping (94) 1 1 1

CT secondary circuit supervision 1 1 1

VT secondary circuit supervision (97FF) 1 1 1

Fault locator 1

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Analogue input module (5I + 4U) 1 1 1

CPU modules 1 1 1

Communication module(with Ethernet interfaces,

RS485 interfaces and time synchronizing interface) 1 1 1

Binary input module (30 BI) 1 1 1

Binary output modules (16 relays for tripping and

initiation) 2 2 2

Binary output modules (16 relays for signal) 2 2 2

Power supply module 1 1 1

Programmable LEDs 18 18 18

Case, 4U,19” 1 1 1

NOTE:

n : Quantity of standard function or standard hardware, n= 1, 2, ….;

(n) : Quantity of optional function or optional hardware, n= 1, 2, ….;

A: Single busbar arrangement

B: breaker arrangement

C: Double busbar arrangement

Ordering

64

Ordering code

Ordering

65

Ordering

66

Ordering

67

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