GE CEY53A User manual

INSTRUCTIONS
GEK
-
7351
A
MHO
DISTANCE
RELAY
FOR
SHUNT
REACTOR
PROTECTION
TYPE
CEY
53
A
GENERAL
w
ELECTRIC
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Courtesy of NationalSwitchgear.com

GEK
-
7351
CONTENTS
PAGE
DESCRIPTION
APPLICATION
CALCULATION
OF
SETTINGS
RATINGS
5
5
5
6
CONTACTS
CONSTRUCTION
OPERATING
PRINCIPLES
MHO
UNIT
CHARACTERISTICS
IMPEDANCE
CHARACTERISTICS
DIRECTIONAL
ACTION
UNDERREACH
MEMORY
ACTION
TRANSIENT
OVERREACH
OPERATING
TIME
VERNIER
ADJUSTMENT
FOR
LOW
TAP
SETTINGS
6
7
.
7
7
8
8
8
8
9
9
9
9
BURDENS
9
9
CURRENT
CIRCUITS
POTENTIAL
CIRCUITS
MECHANICAL
ADJUSTMENTS
SERVICING
TESTING
WITH
THE
X
+
R
EQUIPMENT
PORTABLE
TEST
EQUIPMENT
ELECTRICAL
TESTS
DRAWOUT
RELAYS
GENERAL
POWER
REQUIREMENTS
GENERAL
RECEIVING
,
HANDLING
AND
STORAGE
PERIODIC
CHECKS
AND
ROUTINE
MAINTENANCE
CONTACT
CLEANING
RENEWAL
PARTS
INSTALLATION
PROCEDURE
LOCATION
MOUNTING
VISUAL
INSPECTION
MECHANICAL
INSPECTION
10
10
10
12
12
12
12
12
13
13
13
13
13
13
13
14
14
3
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GEK
-
7351
Photos
Not
Available
At
This
Time
Photos
Not
Available
At
This
Time
4
Courtesy of NationalSwitchgear.com

GEK
-
7351
MHO
DISTANCE
RELAY
FOR
SHUNT
REACTOR
PROTECTION
TYPE
CEY
53
A
DESCRIPTION
The
type
CEY
53
A
relay
is
a
single
phase
zone
one
mho
distance
relay
specifically
designed
for
shunt
reactor
protection
.
It
provides
instantaneous
protection
against
turn
-
to
-
turn
and
single
phase
-
to
-
ground
faults
.
The
relay
is
mounted
in
a
double
unit
single
ended
size
Ml
drawout
case
and
is
provided
with
a
target
seal
-
in
unit
.
Three
relays
are
required
,
one
per
phase
,
for
each
shunt
reactor
installation
.
APPLICATION
The
type
CEY
53
A
relay
is
a
zone
one
mho
distance
relay
specifically
designed
for
shunt
reactor
protection
.
The
external
connections
are
shown
in
Figure
3
.
This
application
shows
the
reactors
connected
as
an
integral
part
of
the
transmission
line
with
the
relays
supplied
with
line
side
potential
.
When
a
transmission
line
having
integral
shunt
reactors
is
first
deenergized
,
there
will
be
a
trapped
voltage
remaining
on
the
line
which
will
be
oscillating
at
some
matural
frequency
as
determined
by
the
total
reactance
and
the
line
distributed
shunt
capacitance
.
The
oscillation
frequency
varies
from
about
40
to
70
Hz
for
minimum
to
maximum
reactor
compensation
respectively
.
Since
the
relay
would
normally
receive
its
potential
from
line
side
coupling
capacitor
potential
devices
,
it
would
be
subjected
to
these
voltage
oscillations
.
If
the
relay
were
to
develop
operating
torque
and
close
its
contacts
under
these
conditions
,
it
would
most
likely
prevent
the
successful
high
speed
reclosing
of
the
line
.
The
relay
design
is
such
that
its
ohmic
reach
is
appreciably
shortened
at
frequencies
lower
than
rated
frequency
.
The
curve
of
Figure
4
shows
the
mho
unit
response
over
a
range
of
38
to
70
Hz
.
As
the
frequency
is
decreased
the
mho
unit
maximum
torque
angle
becomes
less
lagging
and
also
the
diameter
of
the
mho
circle
decreases
.
These
variations
are
shown
in
the
curves
of
Figure
5
.
The
curve
of
Figure
4
is
a
composite
showing
the
effect
of
both
of
the
variations
shown
in
the
curves
of
Figure
5
with
an
85
degree
angle
line
as
reference
.
Shunt
reactors
designed
to
be
connected
to
transmission
lines
will
generally
begin
to
saturate
at
just
over
rated
voltage
.
The
apparent
reduction
of
reactance
at
elevated
voltages
must
be
considered
in
setting
the
relay
so
as
to
avoid
misoperation
of
the
reactor
protection
on
the
line
overvoltage
conditions
expected
.
When
the
transmission
line
section
and
its
connected
reactor
are
energized
at
the
zero
point
in
the
voltage
wave
,
the
reactor
inrush
current
produced
will
have
maximum
offset
and
will
saturate
the
reactor
to
some
degree
.
Thus
the
apparent
reactance
will
be
reduced
.
The
relay
setting
must
not
be
so
sensitive
as
to
respond
to
this
reduced
apparent
reactance
otherwise
line
retripping
would
result
.
The
sensitivity
of
the
protection
for
the
reactor
will
depend
upon
the
relay
setting
and
the
reactor
design
.
The
relay
sensitivity
will
first
be
limited
by
the
considerations
previously
discussed
so
that
it
will
not
trip
incorrectly
on
energizing
or
overvoltage
,
etc
.
The
resulting
setting
will
determine
the
degree
of
protection
remaining
.
However
,
as
one
example
of
turn
-
to
-
turn
protection
,
calculations
of
a
particular
reactor
design
indicated
that
a
short
circuit
involving
only
5
percent
of
the
total
turns
would
reduce
the
apparent
impedance
of
the
reactor
to
approximately
25
percent
of
its
rated
value
.
Thus
,
fairly
good
protection
coverage
is
provided
.
When
the
reactor
is
part
of
the
transmission
line
,
clearing
of
any
reactor
faults
requires
the
tripping
of
a
remote
line
breaker
.
The
external
connections
of
Figure
1
show
a
21
/
X
external
auxiliary
device
operated
by
the
CEY
53
A
trip
circuit
to
provide
transfer
trip
keying
to
accomplish
this
function
.
CALCULATION
OF
SETTINGS
For
the
purpose
of
illustrating
relay
settings
assume
a
shunt
reactor
of
100
MVAR
per
phase
on
a
500
KV
system
.
The
reactor
rated
reactance
is
therefore
:
These
instructions
do
not
purport
to
cover
all
details
or
variations
in
equipment
nor
to
provide
for
every
possible
contingency
to
be
met
in
connection
with
installation
,
operation
or
maintenance
.
further
:
i
n
forma
tion
be
desired
or
should
particular
problems
arise
which
are
not
covered
sufficiently
for
the
purchaser
'
s
purposes
,
the
matter
should
be
referred
to
the
General
Electric
Company
.
Should
Tc
the
extent
required
the
products
described
herein
meet
applicable
ANSI
,
IEEE
and
NEMA
standards
;
but
no
such
assurance
is
given
with
respect
to
local
codes
and
ordinances
because
they
vary
greatly
.
5
Courtesy of NationalSwitchgear.com

GEK
-
7351
X
=
(
ELN
)
2
=
(
289
)
2
X
106
=
100
X
106
835
ohms
primary
VAR
CT
Ratio
PY
Ratio
Xsec
=
Xpri
Assume
CT
Ratio
=
600
/
5
PT
Ratio
-
289
,
000
/
120
(
1
ine
-
to
-
neutral
)
Xsec
=
41.6
ohms
(
1
per
unit
)
Assume maximum
short
time
overvoltage
are
1.3
per
unit
.
From
the
reactor
saturation
curve
determine
the
current
level
at
this
voltage
.
Assume
1.53
per
unit
current
1.30
X
at
1.3
pu
voltage
= =
0
,
85
pu
-
35.4
ohms
1753
The
reactor
apparent
impedance
under
extreme
inrush
conditions
when
energizing
as
discussed
under
APPLICATION
will
have
to
be
calculated
or
determined
by
test
.
When
this
value
is
known
,
compare
it with
the
apparent
reactance
determined
under
overvoltage
conditions
as
shown
above
.
Using
the
smaller
of
the
two reactances
,
reduce
this value
by
a
suitable
margin
of
perhaps
10
to
15
percent
to
determine
the
required
relay
reach
setting
.
Assume
the
relay
to
be
set
for
0.55
pu
or
22.9
ohms
secondary
.
For
best
performance
select the
highest
possible
relay
basic
minimum
tap
TB
available
that
can
be used
for
the
required
setting
.
For
this
case
,
connect
the
two
relay
current
coils
in
series
as
is
shown
in
the
external
connections
of
Figure
3
.
The
relay
basic
minimum
taps
will
now
be twice
the
nameplate
value
.
For
example
if
the
nameplate
taps
are
0.75
/
1.5
/
3
,
connecting
the
two current
coils
in
series
will
change
these
tap
values
to
1.5
/
3
/
6
.
In
this
case
select
the
6
ohm
tap
.
The
percent
restraint
tap
T
is
determined
by
the
following
rel
ation
j
_
100
TB
cos
(
9
-
0
)
Z
where
9
=
reactor
angle
,
assume
90
degrees
0
=
maximum
torque
angle
of
relay
,
75
degrees
.
Z
=
desired
reach
at
angle
9
=
100
(
6
)
cos
15
°
T
=
25
percent
22.9
RATINGS
The
type
CEY
53
A
relay
covered
by
these
instructions
is
available
for
120
volts
,
5
amperes
,
60
cycle
rating
.
The
1
second
rating
of
the
current
circuits
is
225
amperes
per
circuit
.
The
basic
minimum
reach
and
adjustment
ranges
of
the
mho units
are
given
in
the
table below
.
MHo
Unit
Basic
Min
.
*
Reach
0
N
ohms
Angie
of
Max
.
Tor
.
Range
0
-
N
ohms
75
°
Lag
750
Lag
0.75
/
1.5
/
3.0
1.5
/
3.0
/
6.0
Standard
Long
Reach
0.75
/
30
1.5
/
6
s
*
The
above
basic minimum
reach
taps
are
for
only
one
current
coil
connected
in
the
current
circuit
or
for
'
both
current
coils connected
in
parallel
.
If
the
two
current
coils
are
connected
in
series
these
basic
minimum
taps
are
multiplied
by
two
.
CONTACTS
The
contacts
of
the
CEY
53
relay
will
close
and
carry
momentarily
30
amperes
D
.
C
.
However the
circuit
breaker
,
trip
circuit
must
be
opened
by
an
auxiliary
switch
contact
or
other suitable
means
since
the
relay
contacts
have
no
interrupting
rating
.
6
Courtesy of NationalSwitchgear.com

GEK
-
7351
Target
and
Seal
-
in
Unit
The
ratings
of
the
target
seal
-
in
unit
is
shown
below
.
2
Amp
Tap
0.2
Amp
1
ap
3
amps
0.3
amps
7
ohms
Carry
tripping
duty
Carry
continuously
D
.
C
.
resistance
Impedance
(
60
cycles
)
30
amps
3
amps
0.13
52
ohms
0.53
ohms
CONSTRUCTION
The
Type
CEY
53
relays
are
assembled
in
the
medium
size
single
ended
(
Ml
)
drawout
case
having
studs
at
one
end
in
the
rear
for
external
connections
.
The electrical
connections
between the
relay
and
case
studs
are
through
stationary
molded inner and
outer
blocks
between
which
nests
a
removable
connecting
plug
.
The
outer
blocks
have
the
terminals
for
the
internal connections
.
Every
circuit
in
the
drawout
case
has
an
auxiliary
brush
,
as
shown
in
fig
.
6
,
to
provide adequate
overlap
when the
connecting plug
is
withdrawn
or
inserted
.
Some
circuits
are
equipped
with
shorting
bars
(
see
internal
connections
in
Fig
.
7
,
and
on
those
circuits
,
it
is
especially
important
that the
auxiliary
brush
make
contact
as
indicated
in
Fig
.
6
with
adequate
pressure
to
prevent
the
opening
of
important
interlocking
circuits
.
The
relay
mechanism
is
mounted
in
a
steel
framework
called
the
cradle and
is
a
complete
unit
with
all
leads terminated
at
the inner
blocks
.
This
cradle
is
held
firmly
in
the
case
with
a
latch
at
both
top
and
bottom
and
by
a
guide
pin
at
the
back
of
the
case
.
The
connecting plug
,
besides
making
the
electrical
connections
between
the
respective
blocks
of
the
cradle and
case
,
also locks the latch
in
place
.
The
cover
,
which
is
drawn
to
the
case
by
thumbscrews
,
holds
the
connecting
plugs
in
place
.
The
target
reset
mechanism is
a
part
of
the
cover
assembly
.
The
relay
case
is suitable
for
either
semi
flush
or
surface
mounting
on
all
panels
up
to
2
inches thick
and
appropriate
hardware
is
available
.
However
,
panel
thickness
must
be
indicated
on
the
relay
order
to
insure
that
proper
hardware
will
be
included
.
Outline
and
panel
drilling
is
shown
in
Fig
.
8
.
A
separate
testing
plug
can
be
inserted
in
place
of
the
connecting
plug
to
test
the
relay
in
place
on
the
panel
either
from
its
own
source
of
current
and
voltage
,
or
from
other
sources
.
Or
the
relay
can
be
drawn
out
and
replaced
by
another
which
has
been
tested
in
the
laboratory
.
Fig
.
i
shows
the
relay
removed
from
its drawout
case
with
all
major
components
identified
.
Symbols
used
to
identify
circuit
components
are
the
same as
those which
appear
on
the
internal
connections
diagram
in
figure
7
,
All
adjustments
can
be made
from
the
£
ront
of
the
relay
without
removing
the
relay
from
its
case
.
OPERATING
PRINCIPLES
he
mho unit
of
the
CEY
53
A
relay
is
of
the
four
pole
induction
cylinder
construction
in
which
torque
produced
uy
the
interaction
between
a
polarizing
flux
and
fluxes
proportional
to
the
restraining
or
operating
quantities
.
The
method
of
obtaining
the
mho
characteristics
for
the
unit is described
below
.
MHO
UNIT
:
^
The
schematic
connections
of
the
Mho
unit
are
illustrated
in
fig
.
9
.
The
two
side
poles
,
energized
by
phase
-
to
-
neutral
voltage
,
produce
the
polarizing
flux
.
The
flux
from
the
front
and
rear
poles
,
energized
by
the
difference
between
the
secondary
voltage
of
the
transactor
TR
and
a
percentage
of
the
same
phase
-
to
-
neutral
voltage
,
interacts
with
the
polarizing
flux
to
produce
torque
.
The
torque
equation
can
be
written
as
follows
:
KE
(
IZT
-
TE
)
cos
f
Torque
(
i
)
where
:
phase
-
to
-
neutral
voltage
(
E
]
)
line
current
(
I
]
-
I
2
)
E
I
7
Courtesy of NationalSwitchgear.com

GEK
-
7351
Zj
=
transfer
impedance
of
transactor
Tp
K
=
the inherent
design
contact
T
=
Out
-
transformer
tap
setting
B
=
Angle
between
E
and
(
IZj
-
E
)
.
That
this
equation
(
1
)
defines
a
mho
characteristic
can
be
shown
graphically
by
means
of
fig
.
10
.
The
vector
IZj
at
an
angle
0
determines
the
basic
minimum reach
of
the unit
for
a
particular
tap
setting
of
the
transactor
TR
primary
.
Assuming
finite
value
of
E
and
(
IZj
-
TE
)
,
the
balance
point
,
torque
=
0
,
will
occur
where
cos
B
=
0
,
that
is
where
the
angle
B
is
90
°
.
The
locus
of
the terminus
of
vector
TE
(
point
A
in
fig
.
10
)
which
will
cause
the
angle
B
to
always
be
90
°
is
a
circle
passing through
the
origin
and
with
the
vector
IZj
as a
diameter
.
Considering
further
the
diagram
in
fig
.
10
,
we
note
that the
angle
B
is less
than
90
°
for
an
internal
fault
(
point
C
)
and the
net
torque
will
be
in
the
closing
direction
(
cos
B
is
positive
)
;
and
that
the
angle
B
is
greater
than
90
°
for
an
external
fault
(
point
D
)
and
the
net
torque
will
be
in
the
opening
direction
(
cos
B
is
negative
)
.
CHARACTERISTICS
IMPEDANCE
CHARACTERISTICS
The
impedance
characteristics
of
the
mho
unit is shown
in
Fig
.
11
for
the
0.75
ohm
basic
minimum
reach
setting
at
a
maximum
torque
angle
of
75
°
.
This
circular
impedance
characteristic
can
be
enlarged
that is
the
unit
reach
can
be
increased
up
to
10
/
1
by
reducing
the
percentage
of
the
terminal
voltage
supplied
to
the
taps
on
the
auto
transformer
.
The
circle
will
always
pass
through
the
origin
and have
a
diameter
along
the
75
degree
impedance
line
equal
to
the ohmic
reach
of
the unit
as
expressed
by
the
following
equation
.
(
Input
Tap
)
Z
min
Unit
Tap
Setting
(
%
)
Ohmic
Reach
where
:
Input
Tap
=
100
%
Zmin
=
Basic
min
.
0
to
N
ohmic reach
of
the unit
(
tap
setting
)
Unit
Tap
=
Restraint
tap
lead
setting
on
transformer
taps
.
Setting
DIRECTIONAL
ACTION
The mho unit
is
adjusted
to
have
correct
directional
action under
steady
state
conditions
.
For
faults
in
the
non
-
tripping
direction
,
the
contacts
will
remain
open
between
0
and
60
amperes
.
For
faults
in
the
tripping
direction
,
the
unit
will
close its
contact
for
voltages
and
current
given
in
the
following
table
:
BASIC
MIN
.
REACH
TAP
0
-
N
VOLTAGE
STUDS
3
-
4
CURRENT RANGE
STUDS
5
AND
8
JUMPER
6
AND
7
0.75
ohms
1.5
ohms
3.0
ohms
6.0
ohms
2.0
volts
2.0
volts
2.0
volts
2.0
volts
6
-
6 0
Amps
3
-
6 0
Amps
1.5
-
6 0
Amps
.
7 5
-
6 0
Amps
The
unit is
tested
at
the
factory
in
the
1.5
ohm
tap
for
correct
directional
action
,
of
+
10
%
can
be
expected
in
the other
taps
listed
above
.
A
variation
UNDERREACH
(
FIG
.
12
)
At
reduced
voltage
the ohmic
value
at
which the unit
will
operate
may
be
somewhat
lower
than the
calculated
value
.
This
pullback
or
reduction
unit
will
operate
for
all
points
to
the
right
of
the
curves
.
8
Courtesy of NationalSwitchgear.com

GEK
-
7351
These
curves
were
determined
by
tests
performed
with
no
voltage
applied
to
the
relay
before
the
fault
was
applied
.
That
is
the
steady
state
curve
.
While
the
dynamic
curves
were
obtained
with
full
rated
voltage
appplied
to
the
relay
before
the
fault
was
applied
.
MEMORY
ACTION
The
dynamic
curves
of
fig
.
12
show
the
effect
of
memory
action
in
the
unit
which
maintains
the
polarizing
flux
for
~
few
cycles
following
the
fault
.
This
memory
action
is
particularly
effective
at
low
voltage
levels
of
current
.
The
steady
state
curve
shows
that
the
unit
will
not
see
a
fault
at
zero
percent
of
the
relay
setting
regardless
of
the
tap
setting
.
Under
dynamic
conditions
when
memory
action
i s
effective
,
when
I
is
greater
than
2.53
amperes
.
TRANSIENT
OVERREACH
The
operation
of
the
mho
unit
under
transient
conditions
at
the
inception
of
a
fault
is
important
because
the
relay
is
normally
connected
so
that
the
MHO
contacts
will
trip
a
circuit
breaker
independently
of
any
other
contacts
.
The
impedance
characteristic
of
Fig
.
11
and
the
steady
-
state
curves
of
Fig
.
12
represent
steady
-
state
conditions
.
If
the
fault
current
contains
a
D
-
C
transient
,
the
unit
may
close
its
contacts
momentarily
even
though
the
impedance
being
measured
is
slightly
greater
than
the
calculated
steady
-
state
reach
.
This
overreaching
tendency
will
be
a
maximum
when
a
fault
occurs
at
the
one
instant
in
either
half
-
cycle
which
produces
the
maximum
D
-
C
offset
of
the
current
wave
.
The
maximum
transient
overreach
of
the
MHO
unit
will
not
exceed
5
percent
of
the
steady
-
state
reach
for
line
angles
up
to
85
degrees
.
OPERATING
TIME
The
operating
time
of
the
MHO
unit
is
determined
by
a
number
of
factors
such
as
the
basic
minimum
reach
setting
of
the
unit
,
fault
current
magnitude
,
ratio
of
fault
impedance
to
relay
reach
,
and
magnitude
of
relay
voltage
prior
to
the
fault
.
The
curves
in
Fig
,
13
are
for
the
condition
of
rated
volts
prior
to
the
fault
.
Time
curves
are
given
for
four
ratios
of
fault
impedance
to
relay
reach
setting
.
In
all
cases
,
the
M
10
taps
were
in
the
100
percent
position
and
the
angle
of
maximum
torque
was
set
at
75
°
TA
-
VERNIER
ADJUSTMENT
FOR
LOW
TAP
SETTINGS
The
input
leads
to
the
tapped
auto
-
transformer
are
normally
set
at
100
percent
,
but
for
applications
on
lines
with
a
high
secondary
line
impedance
,
where
the
tap
leads
would
be
set
at
a
low
percentage
,
the
input
connections
can
be
varied
by
a
vernier
method
to
obtain
a
closer
setting
.
For
example
,
if
the
desired
first
-
zone
reach
is
4.5
ohms
and
the
basic
minimum
reach
setting
of
the
unit
is
3
ohms
,
with
the
input
setting
on
100
percent
,
the
tap
leads
would
be
:
=
100
(
3
)
Tap
Setting
66.7
percent
4.5
This
desired
-
reach
setting
can
be
made
within
0.45
percent
accuracy
by
means
of
the
67
percent
However
,
if
the
desired
firsr
zone
reach
were
28.5
ohms
,
the
output
tap
setting
would
be
:
tap
.
100
(
3
)
=
10.5
percent
2875
The
nearest
output
tap
would
be
11
percent
which
is
4.2
percent
off
the
desired
value
.
To
correct
this
,
the
input
leads
can
be
shifted
to
95
percent
,
in
which
case
,
the
output
would
be
:
95
(
3
)
=
10
percent
28.5
BURDENS
CURRENT
CIRCUITS
The
maximum
current
burden
imposed
on
each
current
transformer
at
5
amperes
and
60
cycles
is
listed
below
:
AMPS
CYCLES
R
P
.
F
.
X
w
.
V
A
5
60
.
089
.
019
.
98
2.22
2.5
9
Courtesy of NationalSwitchgear.com

GEK
-
7351
This
data is
for
the
3
ohm basic
reach
tap
settings
,
setting
will
be
lower
.
The burden
for
the
1.5
and
the
0.75
ohm
tap
POTENTIAL
CIRCUITS
The
maximum
potential
burden
imposed
on
each
potential
transformer
at
120
volts and
60
cycles
is
listed below
.
IK
CIRCUIT
P
7
F
7
WATTS
R
X
Polarizing
1300
-
J
680
0.89 8.7
9.8
Restraint
4.5
3200
JO
1.0
4.5
The
potential
burden
of
the
mho
unit
is
maximum when
the restraint
tap
is
set
at
100
%
.
The
restraint
circuit burden and hence the
total
burden will
decrease when
the restraint
tap
setting
is
less
than
100
%
.
The
potential
burden
at
tap
settings
less
than
100
%
,
can
be calculated
from
the
following
formula
.
Tap
Setting
VA
=
(
a
+
Jb
)
+
(
c
+
jd
)
The
terms
(
a
+
Jb
)
(
c
+
Jd
)
represent
the
burdens
of
the mho unit
potential
circuit
expressed
in
watts
and
vars
with
their
taps
on
100
%
,
The values
for
these
terms
are
as
shown
below
.
100
TERM
CIRCUIT
TERM
(
WATTS
+
J
VARS
)
(
WATTS
±
J
VARS
)
(
4.5
+
JO
)
(
8.7
+
J
4.5
)
(
a
+
Jb
)
(
c
+
Jd
)
RESTRAINT
POLARIZING
MECHANICAL
ADJ
.
Check
Points
Mh
Unit
Rotating
Shaft
End
Play
Contact
Gap
Contact
Wipe
(
N
.
O
.
Contacts
)
.
010
-
.
015
inch
.
030
-
.
035
inch
.
003
-
.
005
inch
SERVICING
The
phase
shifter
phase
angle
meter
method
of
testing
the
CEY
53
A
relay
.
Connect
the
relay
per
Figure
14
except
(
C
)
to
stud
3
(
D
)
to
stud
8
and
jumper
studs
6
and
7
.
Directional
Tests
A
.
1
.
Put
the
reach
taps
int
he
1.5
ohm
position
.
2
.
Set
current
for
5
amperes
and
the
voltage
for
120
volts
.
3
.
Set
the
phase
angle
at
285
degrees
(
75
degrees lag
)
.
4
.
Reduce
the
voltage
to
0
.
Vary
the
current
from
0
to
60
amperes
,
the
unit
should
develop
slight
opening
torque
.
Adjust
the
core
if
this
test
fails
,
refer
to
figure
15
.
The
core
can
be
rotated
360
degrees
without
having
to
loosen
any
part
of
the
assembly
.
This
adjustment
is
done
by
using
a
special
core
adjusting
wrench
(
Cat
.
No
.
0178
A
9455
Pt
.
1
)
which
fits
only
octagon
nut
D
in
figure
15
.
5
.
Set
the
voltage
to
2.0
volts
and
current to
3
amperes
and
adjust
the
control
spring
until the
unit
just
closes
.
Then
increase the
current
to
60
amperes
and
the
contact
should
remain
closed
.
10
Courtesy of NationalSwitchgear.com