GE 12CEYG51B(-)D User manual

INSTRUCTIONS

GEK—

34169

DIRECTIO1AL

DISTANCE

RELAY

1YPE

CEY

Insert

Booklet—

GEK-26423

MODEL

12CEYG51B(-)D

INTRODUCTION

This

instruction

book

along

with

the

LCEYG51A(-)D

relay

Instruction

Book,

form

the

instructions

for

the

12CEYGS1B(-)D

ay.

DESCRIPTiON

The 12CEYG51A(-)D

relay

except

for

the

removal

the

target/seal-in

unit

and

its

circuitry.

Rfu,’

figure

for

the

12CEYG51B(-)D

internal

connecLion

dgram.

Since

the

relay contacts

are

longer

protecect

unit,

the

contacts

must

never

inte’rut

curren

carv

trip

current

for

than

milliseconds.

These

instructions

not

purport

cover

all

details

variations

equipmtnt

nor

to provide

for

every

possible

contingency

met

connection

with

installation,

operation

maintenance.

Should

further

information

desired

should

particular

proble.s

arise

which

are

not

covered

sufficiently

for

the

purchaser’s

purposes,

the

matter

should

referred

the

General

Electric

Company.

POWER

SYSTEMS

MANAGEMENT

DEPARTMENT

GENERALS

ELECTRIC

PUIIADLLPNIA.

PA.

GEK-34169

cV>

Bb>

vi2

M1TOP

UNIT

M2=MIDDLE

UNIT

SHORT

FINGER

M3=BOTTOM

UNIT

FIG.

(0246A3351-O)

Internal

Connection

Diagram

For

The

CEYG51B(-)D

Relay

GENEtAL

ELECTRIC

COMPANY,

PHILADELPHIA,

GEK-26423D

INSTRUCTIONS

GROUND

DISTANCE

RELAY

TYPE

CEYG51A

Protection

and

Control

205

Great

Valley

Parkway

Malvern,

19355-1337

GEK-26423

CONT

PAGE

iNTRODUCTION

APPLICATION

RATINGS

Contacts

OPERATING

PRINCIPLES

CHARACTERISTICS

Pickup

Operating

Time

Burden

CALCULATION

SETTINGS

CONSTRUCTION

RECEIVING,

HANDLING

AND

STORAGE

ACCEPTANCE

TESTS

Visual

Inspection

Mechanical

Inspection

Electrical

Tests

INSTALLATION

PROCEDURE

Relay

Settings

Mechanical

Checks

Electrical

Checks

PORTABLE

TEST

EQUIPMENT

SERVICING

Restraint

Circuit

Angle

Adjustment

Directional

Characteristic

Maximum

Torque

Angle

Pickup

Clutch

Adjustment

RENEWAL

PARTS

APPENDIX

MINIMUM

PERMISSIBLE

REACH

SETTING

FOR

THE

CEYG51A

Zero

Sequence

Current

Compensation

With

Zero

Sequence

Current

Compensation

APPENDIX

MAXIMUM

PERMISSIBLE

REACH

SETTING

FOR

THE

CEYGS1A

Zero

Sequence

Current

Compensation

APPENDIX

III

MAXIMUM

PERMISSIBLE

REACH

SETTING

FOR

THE

CEYG51A

With

Zero

Sequence

Current

Compensation

GEK-2

6423

GROUND

DISTANCE

RELAY

CEYG51A

RELAY

INTRODUCTION

The

CEYGSIA

three

phase,

high

speed,

single

zone,

inho

type,

directional

distance

ground

relay.

consists

three

single-phase

units

one

L2—D

case

with

facilities

for

testing

one

unit

time.

One

target

and

seal-in

unit

provides

indication

operation for

all

three

distance

units.

The

transient

over

reach

characteristic

the

CEYG51A

relay

has

not

been

limited

the

point

where

suitable

for

use

first-zone

relay.

The

relay

was

specifically

designed

for

use

overreaching

device

directional

comparison

and

transferred

tripping

schemes.

Figure

shows

the

internal

connections.

APPLICAT

ION

The

CEYGS1A

ground

mho

relay is

applied

the

primary

ground

relay

directional

comparison

and

per

missive

overreaching

transferred

tripping

schemes,

employing

separate

primary

and

separate

backup

protec

tion.

The

ground

rnho

units

the

CEYG51A

relay

are

specifically

designed

detect

single

phase

ground

faults.

this

end

they

are

supplied

with

quadrature

voltage

polarization.

Thus,

the

polarizing

voltage

will

quite

high

and

the

relay

will

have

high

operating

torque

level

even

very

line

ground

faults.

For

this

reason, these

units

are

not

provided

with

memory

action.

These

ground

mho

units

will also

respond to

three

phase

faults.

this

objectionable,

the

relay

can

made

unresponsive

any

faults

not

involving

ground

simply

adding

non-directional

zero

sequence

fault

detector.

The

ground

mho

units

are

provided with

separate

current

circuits

for

zero

sequence

current

compensa

tion.

tapped

auxiliary

current

transformer

used

obtain

the

proper

ratio

compensation.

When

zero

sequence

current

compensation

used,

the

ground

niho

unit

has

essentially

the

same

reach

single

phase

ground

faults

three

phase

faults.

zero

sequence compensation

NOT

used,

the

ground

mho

unit

roach

considerably

foreshortened

single

phase

ground

faults.

See

Appendix

for

the

minimum

permissible

reach

settings

under

both

conditions.

directional

comparison schemes,

two

CEYG51A

relays

connected

back—to-back

are

required

each

terminal.

These

relays

operate

conjunction

with

carrier

channel to

provide

high

speed

protection

against

all

single

phase

ground

faults

the

protected

line section.

One

relay

acts

to stop

carrier

and

trip

for

internal

faults

while the

other

initiates

carrier

blocking

external

faults.

zero

sequence

current

compensation

used

the

carrier

stopping

and

tripping

units,

should

also

used

the

carrier

starting

units.

This

will

facilitate

the

unit

settings

and

insure

that

both

units

that

must

coordinate

will

operating

the

same

torque

level.

any

event,

the

carrier

starting

unit

should

set

sensitively

possible.

This

will

tend

increase

security

since

the

presence

carrier

signal

will

block

tripping.

permissive overreaching

transferred

tripping

schemes,

one

CEYG5IA

relay

required

each

ter

minal.

acts

combined

transferred

trip

initiating

and

permissive

relay for

ground

faults

the

protected

line

section.

The

choice

whether

not

use

sequence

current

compensation

depends

upon

the

protected

line

length

and

system

conditions.

When

zero

sequence

current

compensation

NOT

used,

the

ground

mho

unit

reach

required

may

about

times

the

positive

sequence

impedance

the

line

order

provide

the

proper coverage.

This

then

tends

make

the

ground

niho

unit

sensitive

operation

load

con

ditions

power

swings.

The

use

zero

sequence

current

compensation

reduces

the

necessary

ground

mho

unit

reach

setting

approximately

1.2S

times the

positive

sequence

impedance

the

line

and,

thus,

minimizes

its

response

to load

power

swings.

This

true

provided

there is

little

mutual

pedance

present

from

parallel

line.

These

h?structlons

not

purport

cover

all

details

variations

equipment

nor

provide

for

evero

pass:nle

contingency

met

connection

with

installation,

operation

or maintenance.

Should

fartn-r

;nformation

desired

shouM

particular

problerrm

arise

which

are

not

covcrci

suffic;enLlq for

tni

purchaser’s

r’Jrposes,

the

matter

should

referred

the General

Electric

Company.

the

extenL

reaured

the

;roducL-s

described

herein

meet

applicable

7’IS1,

IEEE

and

.VEM.4

standards;

not

sicn

assurance

7iven

respect

local

codes

and

ordnan:esj,ecaue

ti?C5

car

greatly.

GLK-26423

Whether

not

zero

sequence

current

compensation

used,

the

ground

mho

units

may

subject

ccrrect

operation

ground

faults

immediately

behind

the

relay

terminals.

This

will

dependent

upon

the

line

impedance

and

system

conditions.

may

necessary

unit

the

mho

unit

reach

setting

order

to avoid

this false tripping.

Appendix

gives

the

liniiatations

the

mho

unit

reach

setting

when

zero

sequence

current

compensation

NOT

used

Appendix

III

gives

the

limitations

the

inho

unit

reach

setting

when

zero

sequence

current

compensation

used.

The

system

conditions

which

require

the

limi

tdtion

the

uho

unit

reach,

described

Appendices

Nand

111,

are

rather

unusual.

They

occur

when

the

zero

sequence

current

contribution

over

the

line

Fault

behind

the

relay

larger

than

the

positive

sequence

current

contribution.

the

reach

the

unfaulted

phase

units

the

non-trip

direction

application

limitation,

zero

soquence

directional

overcurrent

relay

(CFPG16A)

may

used

supervise

the

CEYG51

operation.

This

will

permit

tripping

only

when

the

fault

the

forward

direction.

The

external

connections

are

shown

Figure

Since the

CEYG51A

extended

range

relay

with

three

basic

minimum

reach

settings,

the

best overall

pcrforiance

will

obtained

the

highest

basic

minimum

reach

tap

setting

that

will

accommodate

the

sired

setting

used.

RATINGS

The

Type

CEYG51A

relays

covered

these

instructions

are

available

with

potential

circuits

rated

for

operation

wye—wye

connected

potential

transformers

which

supply

secondary

voltage

120

volts

phase-

to-phase.

Current

coil

ratings

and

ohmic

ranges

are

tabulated

below:

BASIC

MIN.

RANGE

CONTIN.

ONE

SEC.

OHMIC

REACH

OHMIC

REACH

CURRENT

RATING

CUR.

RATING

(-N

OHMS)

(p-N

OHMS)

AMPERES

1/2/3

225

•

0.5/1.0/1.5

0.5

—

[

225

The

ohmic

reach

the

angle

maximum

torque

degrees

lag,

and

can

adjusted

percent

steps

means

tapped

autotransformner.

will

noted

that

three

basic

minimum

reach

settings

are

listed

for

the

mho

units.

Selection

the

desired

basic

minimum

reach

made

means

links

terminal

boards

located

rear

the

relay.

The

positions

of the

two

sets

links,

(for

each

unit),

each

identified

A-B

determine the

minimum

ohmic

reach

setting

follows:

MINIMUM

OHMIC

REACH

SETTING

(OHM

PHASE-TO-NEUTRAL)

CONTACTS

The

main

circuit-closing

contacts

the

re1a

will close

and

carry

amperes

momentarily

for

tripping

duty

control

voltages

250V

less.

The

circuit

breaker

trip

coil

should,

however,

always

opened

by an

auxiliary

switch or

other

suitable

means.

the

tripping

current

exceeds

amperes,

tripping

relay

should

used.

The

current

carrying

rating

the

main

contacts

determined

the

tap

setting

the

seal—in

coil

shown

Table

TABLE

TARGET

AND

SEAL-IN

UNIT

2.0

0.6 0.2

Amp

Tap

Amp

Tap

Amp

Tap

0-C

Resistance

0.13

Ohms

0.6

Ohms

Carry

Continuously

3.5

Amps

1.0

Amps

0.35

Amps

Carry

Amps

for

Secs.

0.5

Secs.

Carry

Amps

for

0.2 Secs.

GEK-26423

The

normally

closed

contacts

between

terminals

and

will

close,

carry

continuously,

interrupt

0.3

amperes

non-inductive

circuits

250V

DC.

OPERATING

PRINCIPLES

The

inho

type

units

the

C[YG51A

relay

are

the

four—pole

induction-cylinder

construction

(see

Fig.

with

schematic

connections

shown

Fig.

The two

side

poles,

which

are

energized

the

phase-to-phase

vol

tage

quadrature

with

the

phase-

to—neutral

vol

tage

the

protected

phase,

produce

the

polarizing

flux.

The

flux

the

front pole,

which

energized

percentage

the

phase-to-neutral

vultaçje

Lire

protected

phase,

interacts

with

the

polarizinq

flux

produce

restraint

torque.

The

flux

the

rear

pole,

which

energized

the

line

current

the

protected

phase,

interacts

with

the

polar

rig

flux

produce

operating

torque.

The

torque

the

balance

point for

the

phase

starting

unit

can,

therefore,

expressed

the

following

equation:

Torque

KI’aEbc

cos

((

-30)

—

TE’aEbC’

sin

(1)

where:

design

constant

Phase-A-to-neutral voltage

the

relay

location

Ebc

Phase

voltage

(Eb

the

relay

Phase

current,

the

relay location

Angle

which

leads

Ebc’

(900

for

balanced

3-phase

condition)

Restraint

tap

setting

Angle

which

‘a’

leads

CHARACTERISTICS

The

operating

characteristics

the

mho

units

the

CEYG51A

relay

may

represented

the

R-X

impedance

diagram

shown

Fig.

should

noted

that

these

steady-state

characteristics

are

for

rather specific

fault

conditions

described

below:

The

mho

unit

has

circular

characteristic

which

passes

through

the

origin

the

R-X

diagram.

The

diameter passing

through

the

origin

defines

the

angle

maximum

torque

the

unit,

which

occurs

when

line

current

for

example)

leads

the

quadrature

polarizing

voltage

(Ebc

for

example)

30°. Since

there

essentially

phase

shift

the

line—to-neutral

voltage

for

single-phase-to-ground

fault,

this

maximum

torque

angle

(i.e.

maximum

reach

angle)

occurs

when

the

line current

lags the

phase—to—neutral

voltage

600,

which

the

condition

represented

Fig.

The

diameter

the

impedance

circle

would

nonially

considered

the

ohmic

reach

the

unit,

which

would

the

basic

minimum

reach

with

the

tap

leads

100

percent.

However,

the

mho

unit

not

compensated

not

accurate

distance

measuring

until

except

3—phase

faults,

for

the

special

case

single-phase—to-ground

faults

where

the

zero-sequence

impedance

the

fault

equal to

the

positive

sequence

impedance

the

fault.

Instructions

are

given

Appendices

and

III

for

selecting

reach

setting.

The

ohmic

redch

the

inho

unit

can

extended

reducing the

percentage

the

faut

voltage

applied

the

restraint

circuit,

that

setting

the

tap

leads

lower

percentaoe

position

the tap

block.

(Zi)

100

Ohmic

Reuch

Tap

Setting

()

(5)

GEK—26423

The

ohmic

reach

obtained

from

equation

(5)

assumes

that line

angle

and

maximum

torque

angle are

equal

(60°).

The

reduced

reach

line

angles

other

than

60°

can

obtained

multiplying

the

reach

obtained

from

equation

(5)

cos

(60-0),

where

the

hne

angle.

PICKUP

The

operating

torque

will close

the

contacts

when

the

fault

urrent

certain direction

and

sufficient

magnitude

overcome

the

restraint

torque.

The

operating

torque

3-phase

faults

maxi

mum

for

fault

currents

which

lag

the

unity

power

factor

position

degrees

and

reliable

down

one

percent voltage

with

currents

tabulated

below:

MINIMUM OHMIC

REACH

SETTING

CURRENT

RANGE FOR

RELIABLE

OPERATION

(0-N

OHMS)

0.5

18-60

1.5

single-phase-to-ground

faults

the

quadrature

polarizing potential

will

remain

quite

high

with

the

result

that

the

relay

will

operate

considerably

less

current

than

tabulated.

For

example,

with

one

percent

restraint

voltage

and

120

volts

polarizing

the

unit

will

operate

with

less

than

ampere

operating

current

for

the

3-ohm

minimum

reach

setting.

OPERATING TIME

For

typical

operating

time

characteristics

see

Figure

13A

and

13B.

BURDEN

The

burden

imposed

the

potential

transformers

the type

CEYG51A

relay

with

the

restraint

tap

set

100

percent

given

below:

Basic

Rated

Polarizing

Circuit

Restraint Circuit

Ohms

Freq

Watts

Vars

Volts

Watts

Vars

120

10.1

8.88

13.5

2.7

4,0

4.8

0.5

120

10.1

8.88

13.5

0.9

1.6

1.8

120

8.41 7.38

11.2

1.7

3.0

3.4

the

restraint

tap

reduced,

the

burden

the

restraint

circuit

given

the

following

equation:

Watts

*()2

VARS(.j-)

where

Watts

Restraint

circuit

watts

from

table

above.

VARS

Restraint

circuit

Vars

from

table

above.

Tap

percent.

GEK-26423

The

burdens

imposed

the

current

transformers

the

current

circuits

are

given

below:

Basic

Rated

3-4, 5-6,

7-8

Circuit

9-10

Circuit

Ohms

Freq.

0.070 0.040 0.080

0.210 0.120

0.240

0.5

0.007

0.005 0.008

0.021

0.013

0.024

0.058 0.033

0.067

0.175

0.100

0.200

NOTE:

Above

data

For

the

mho

units

set

their

maximum

ohmic

reach

taps.

The

burden

for

the

lower

reach

tap

settings

will

less

than

the

tabulated

burdens.

CALCULATION

SETTINGS

applying

the

relay

particular

line

and

system, the

limitations

outlined

under

APPLICATION

fre

quently

not

materialize.

Therefore,

reconinended

that

the

initial

calculations

and

below

followed

determine

what

final

calculations

may

necessary

and

how

the

relay

may

applied.

Determine

zero

sequence

current

compensation

required.

This

will

depend

upon

evaluation

the

necessary

rnho

unit

tap

settings

and

the

relation

the

resulting

mho

characteristic

with

the

line

power

loadings

and

power

swings.

See

Appendix

equations

and

Determine

there

limitation

the

application

for

incorrect

operation

faults

behind

the

relay

terminal.

When

zero

sequence

current

compensation

iQi

used:

equal

less

than

further

evaluation

need

made.

See

Appendix

II,

equations

Ha,

lIb

and

lIc.

When

zero

sequence

current

compensation

used:

(3K

equal

less

than

further

evaluation

need

made.

See

Appendix

III,

equations

lila,

Ilib

and

IlIc.

neither

nor

above

applicable,

evaluate

the

equations

either

Appendix

III

determine

necessary

use

the zero

sequence

directional

overcurrent

supervising

lay,

Type

CFPH16A.

The

following

calculations

are

made

example

determining

the

actual

tap

settings

used.

Consider the

protected

line

between

breakers

and

the

portion

system

shown

Fig.

Assume

the

following

characteristics:

24.0

/790

primary

ohms

72.0

/750

primary

ohms

14.4

L°

primary

ohms

Ratio

600/5

Ratio

1200/1

Secondary

Ohms

Ratio

Primary

Ohms

Ratio

2.4

/79°

0.47

j2.36

secondary

ohms

7.2

/750

1.9

j5.95

secondary

ohms

Zom

1.4

/75°

0.36

jl.35

secondary

ohms

Checking

Appendix

first

establish

the

maximum

tap

setting

that

would

still

permit

the

CEYGSIA

breaker

detect

single

phase

ground

fault

(F2)

the

remote

bus,

Equation

should

used.

GEK-26423

Assume

for

this

fault

that

system

study

yields

the

following

quantities.

0.17

0.20

‘a’

13.7

secondary

amperes

based

600/5

CT’s

4.1

secondary

amperes

-0.88

secondary

amperesbased

the

protected

line

ratio

600/5.

Note

the

negative

sign

because

flows

the

opposite

direction

the

parallel

line

from

that

in which

flows

the

protected

line

8).

790

Substituting

these

values

and

the

values

impedance

assumed

above

into

equation

Appendix

obtain:

Cos

(60—79)

(7.2

-2.4)(0.17)

(1.4)(-0.88)

‘

(0.4

0.27)

13.7

0.204K

The

value of

could

obtained

for

all

three

basic

minimum

reach

settings.

However,

the

highest

one

should

used.

For

the

three

ohm

basic

reach

settings

300.

Thus,

for

this

basic

tap

setting

the

restraint

tap

should

larger

than:

0.204K

percent

Consider

now

ground

fault

immediately

behind

the

relay.

Appendix

indicatos

the approach

calculate

the

maximum

safe

reach

setting

eliminate

the

possibility

incorrect

operation

single

double

phase

ground

faults

this

location.

Assume

that

system

study

yields

the

following

system

constants:

0.27

0.11

0.875

secondary

ohms

1.05

/780

secondary

ohms

ZQ/Z

1.2

Using

the

ohm

basic

minimum

tap

settings

established

above

arid

evaluating

equations

ha,

JIb

and

TIc

Appendix

II,

the

minimum

permissible

values

tap

setting

are

tabulated

below.

QUANTITY

VALUE

0.875

/820

1.05

LL8_°

1.2

0.11

0.27

100

123

82°

(Equation

ha)

-10.5

Percent

(Equation

lib)

-18

Percent

(Equation

Tic)

-14.5 Percent

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