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Sunday, December 30, 2012
Tuesday, December 25, 2012
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Wednesday, December 19, 2012
Tuesday, December 18, 2012
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Friday, December 14, 2012
Wednesday, December 12, 2012
CHAPTER 5 QUESTIONS AND ANSWERS
5.1 QUESTIONS
1. What types of power transformers are
likely to be met with onshore and offshore?
2. Why are large oil-filled transformers often
fitted with a conservator?
3. What is the purpose of a Buchholz
relay?
4. How are large transformers cooled?
5. To which windings is a tapping switch
or tap changer connected? Why?
6. What is the advantage of silicone oil
over mineral oil?
7. Why is ‘Askarel’ used in many offshore
transformers?
8. What are the disadvantages of Askarel?
9. How
is the liquid level checked, and the integrity of the sealing monitored, in a
sealed transformer?
10. Why are LV cable boxes in transformers usually much
larger than HV boxes?
11. What
nameplate voltage ratio would you expect to see on a transformer used to
convert from a nominal 11 000V to a nominal 415V system?
12. What do you understand by a transformer’s
impedance Z? Give a typical value.
13. An
Askarel-filled sealed transformer is naturally cooled. What code letters would be used to describe
the cooling system?
14. What do you understand by a transformer
phase connection ‘Dy11’?
15. What precautions would you take before
operating an off-load tapping switch?
16. Describe
briefly the principle of an on-load tap changer. What types of mechanism are employed to
operate it?
17. What site tests would you expect to do on
an installed transformer?
18. What
is an auto-transformer? Where would it
be used? What are its properties as
compared with a double-wound transformer of the same rating and voltage ratio?
19. What
precautions would you take when connecting an auto-transformer into an earthed
system?
20. What material is used for cable conductors
on most installations?
21. What insulating materials are used for
power cables?
22. Why is steel wire not used for armouring
single-core cables?
23. What does the abbreviation HCL mean in a
cable description?
24. Name the precautions to be taken when
making a crimped cable termination.
25. Why are stress cones used when
terminating a high-voltage cable?
26. If
a 3-phase circuit is run with single-core cables between a non-hazardous and a
hazardous area, at which end must the armouring be bonded to earth?
27. Why are certain vital services designed
for operation on d.c.?
28. How are d.c. supplies to such services assured?
29. When should a battery be
boost-charged? Why? How is this done?
30. Why must ventilation always be on when a
battery is being charged?
31. What
do you understand by ‘central’ and ‘dedicated’ d.c. supplies? Give an example of both.
32. Why
are battery-supported a.c. supplies needed in certain cases? How are they achieved?
33. Why
is a battery, when being boost-charged, first given a constant-current charge,
then a constant-voltage charge?
34. What are the disadvantages of direct a.c.
measurements on high-voltage systems?
35. There
are two types of instrument transformers - ‘measurement’ and ‘protective’. What is their main difference?
36. Why
must a current transformer secondary never be fused? What are the dangers, and what precaution
must be taken when removing an instrument from a live CT circuit?
37. A CT with rated burden of 15VA is feeding a total
burden of 5VA through a 200 ft run of pilot leads with resistance of 0.15 ohms
per core per 100 ft. It is preferred to
use a CT with a 5A secondary; can this be done?
If not, what remedy would you propose?
38. What
class of accuracy would you expect to find generally used for measurement and
protective CTs and VTs in most installations?
What class is used with differential protection CTs?
5.2 ANSWERS
(Figures in brackets
after each answer refer to the relevant chapter and paragraph in the text.)
1. Oil-filled, sealed or
with conservator (not offshore).
Askarel-filled, sealed.
Dry type, encapsulated. (1.2)
2.
To allow expansion of the
oil with rise of temperature, while maintaining static oil pressure in the
tank. (1.2.2)
3. A Buchholz relay is
inserted in the pipe between the tank and conservator to:
(a)
trap gas bubbles and give a
‘gassing’ alarm
(b) to sense any surge of oil due to an
internal winding fault and to trip the circuit-breaker. (1.2.2)
4. Liquid-filled transformers (oil or
Askarel) have their windings cooled by thermo-syphon action whereby winding
heat is transferred to the liquid. The
liquid is usually cooled in tubes or radiators by natural convection, sometimes
assisted by forced ventilation. (1.2.2,
1.2.3)
Dry-type encapsulated transformers
are cooled by natural air circulation through the encapsulation. This may be assisted by forced fan
ventilation at the higher loadings. (1.2.4)
5. Tapping switch or tap changer operates
on the HV winding, which has lower currents to switch. (1.9)
6. Silicone oil is
non-flammable as compared with mineral oil. (1.2.2)
7. Askarel is used in offshore transformers because it too is
non-flammable and has
good heat-transfer properties (1.2.3)
good heat-transfer properties (1.2.3)
8. Askarel is toxic and risky to
handle. If spilt, it must all be
carefully recovered and disposed of ashore.
If allowed to fall into the sea, it would be destructive of marine life. (1.2.3)
9. By sight-glass on the side of the
tank. A pressure/vacuum gauge in the
space above the liquid will indicate if the sealing is faulty. (1.2.3)
10. Currents on the LV side are much greater than on the HV side
and may require many cables per phase. The LV cable boxes not only carry larger-section
conductors but may have to terminate many cables. (1.8)
11.
Approximately 11 000/435V
(no-load ratio), or 11 000 ±2½ ±5%/435V if tappings are shown. (1.3)
12.
Z is the impedance offered
to a current passing through a transformer.
It is usually expressed as a percentage, being that percentage of the
nominal applied voltage which, when applied to the primary windings with the
secondary windings short circuited, will give full-load rated current in the
secondary. (1.4)
13. LNAN. (1.6)
14. ‘Dy’
signifies a delta-connected high-voltage winding and a star-connected
low-voltage winding. If A, B, C are the
high-voltage terminals and a, b, c the corresponding low-voltage terminals,
then, taking the vector representing phase ‘A’ voltage as 12 o’clock, the
corresponding vector representing phase ‘a’ voltage is at 11 o’clock - that is,
the LV system leads 30o on the HV. (1.7)
15. Make sure that the
transformer is off load and isolated on both the HV and LV sides. (1.9.1)
16. An on-load tap changer changes the
tappings without breaking the current by using a ‘make-before-break’
method. The current in those turns which
are temporarily short-circuited during the transition is limited by introducing
resistance. To avoid the risk of the
changeover becoming stuck during transition, a ‘stored energy’ mechanism is used
which only starts the tap change when there is enough energy stored to complete
it without further outside power. The
storage of energy may be by spring or flywheel. (1.9.3)
17. (a)
Check for leaks, damage, signs of
overheating, earthing.
(b) Insulation resistance testing of HV and LV windings, to earth
and, if possible, between phases.
(c)
Checking liquid level and
effectiveness of sealing (if applicable).
(d) Simulate
operation of overtemperature or overpressure devices (also of Buchholz relay,
if fitted). (1.11.2)
18. In
an auto-transformer the secondary and primary sides share part of a common
winding in which the secondary and primary current oppose one another. This common part may therefore be of smaller
section and usually gives less heating.
It may be economically used where the voltage ratio is small - say 3:1
or less.
Compared
with its equivalent double-wound type, it is smaller and gives rise to less
heat. Its impedance is usually lower. It does not provide complete electrical
isolation between the two sides. (1.10)
19. Where one side is earthed, the earthed
line must be the one which is connected to the common primary/secondary
terminal in order that the earth may be applied to the other side also. If this is not done, the voltage of one LV line will be the same as
that of the HV side. (1.10)
20. Copper.
(2.1)
21. Polyvinyl chloride (PVC) or Ethylene
Propylene Rubber (EPR). (2.2.3)
22. Because of eddy-current heating. (2.2.5)
23. Hydrochloric Level.
(2.5)
24. Use the correct lug or ferrule and
correct crimping die. (2.6.2)
25. To control the electric stress where the
core screen ends. (2.6.2)
26. In the hazardous area. (2.6.3)
27. Because they must continue in operation
after failure of main a.c. power. This
means a supply from a battery, which in general requires operation of those
services by d.c. (3.1)
28. Power
is taken from an a.c. switchboard and is passed through a transformer-rectifier
(‘charger’) unit to provide the d.c.
required. A battery floats on the d.c. side ready to take
over the supply of d.c.
without interruption if the a.c. supply or the rectifier fails. (3.2)
29. After discharge, a battery would take a
fairly long time to recharge from the rectifier at the system’s
constant-voltage rate. This time is
shortened by ‘boosting’ - that is, by increasing the charge rate. Boosting should be done after an appreciable
discharge; also at 6- or 12-month intervals to maintain the condition of the
battery. (3.3)
30. At
top of charge a battery emits hydrogen and oxygen in an explosive mixture. Ventilation ensures that this gas mixture is
dissipated. (3.9)
31. Where several d.c. services, usually of a similar type,
are grouped to be supplied from a single D.C. Supply System, that system is
termed a ‘central’ one. Where a d.c. supply is provided
for a single equipment, that is a ‘dedicated’ system. Examples of central systems are: main
switchgear closing and tripping; fire and gas detection; communications
supplies. Examples of dedicated systems
are: gas-turbine or diesel engine starting; navigational aids; emergency radio. (3.6)
32.
Certain important services
such as process instrumentation require unbroken a.c. supplies. This is
achieved by providing a battery-supported d.c. system followed by an inverter to
convert the assured d.c.
power into a.c. (3.11)
33. If
the boost-charging voltage were first applied to a discharged battery, the
charge current would be so high that the battery might be damaged and the
rectifier overloaded. Current-limiting
circuits therefore ensure that the charge current cannot exceed a safe value -
this is the ‘constant-current’ mode.
After the battery emf has risen to the point where the charge current
will not exceed the safe value, the charge automatically becomes constant-voltage,
and the charge current tapers off (Fig 3.6). (3.8)
34. Instruments
and relays connected directly to the main system must be insulated to withstand
the full mains voltage. In HV systems
(6.6kV or 11kV) this is not practical.
Also current-operated instruments and relays must be able to carry the
full fault current of the main system - again not practical. Such devices are therefore operated through
instrument transformers (VTs and CTs). (4.2,
4.3)
35. Measurement instrument transformers must
maintain their specified accuracy over the normal working range of currents and
a little above; accuracy in the fault range is not important. Protective instrument transformers must have
their specified accuracy in the range of fault currents; accuracy in the normal
working range is not important. (4.4)
36. A high-resistance burden on a CT gives
rise to very high secondary voltages which could be a danger to personnel and
could cause insulation breakdown in the CT itself. An open-circuit is an extreme case of this. A blown fuse would cause an open-circuit;
therefore CT secondaries must never be fused.
When removing an instrument from a
live CT circuit, the CT secondary must first be short-circuited - preferably at
the CT secondary terminals - to prevent its becoming open-circuited when the
instrument is disconnected. (4.7)
37. Instrument burden = 5VA
Pilot leads burden = 15VA
Total = 20VA. This cannot be fed from a 15VA CT.
Either
substitute a 20VA CT, or else redesign the instrument system to work on 1A
instead of 5A. (4.8)
38. Measurement
CTs: Class
0.5
Protective
CTs: Class
5P
Measurement
VTs: Class
0.5
Protective
VTs: Class
3P
Differential
CTs: Class
X (4.4)
CHAPTER 4 A.C. MEASUREMENTS
4.1 GENERAL
In a.c. power systems
it is necessary continually to monitor the voltage, currents, power and similar
quantities in the various parts of the system.
This is done by the use of instruments - that is by indicating
voltmeters, ammeters, wattmeters etc.
The same measured quantities are also used to protect the system by
means of relays, which are devices to detect when any of the quantities is
going outside the predetermined limit.
They initiate whatever automatic action is necessary to restore the
situation or disconnect faulty or overloaded apparatus.
Almost all electrical
instruments and relays depend for their action on measurements of voltage or
current or combinations of the two.
Measurements of frequency are obtained from analysing a voltage
measurement.
The manner in which
the various types of a.c. measuring instruments work is described in Chapter 8
of the manual ‘Fundamentals of Electricity 3’.
These include moving-iron, dynamometer and eddy-current types and also
transducer-operated instruments. In the
following paragraphs it will be assumed that the appropriate type of instrument
is used.
FIGURE 4.1
DIRECT MEASUREMENT
4.2 DIRECT MEASUREMENT
Voltage and current
samples are taken either directly or indirectly from the conductors of the
circuit to be monitored. In the simplest
case (direct measurement) the voltage is taken by tapping the main conductors. The tappings must always be protected by
fuses which, for a voltage-operated instrument or relay, are quite lightly
rated, though still able to deal with the full fault capacity of the
system. In the 3-phase case a selector
switch may be used to measure voltages between any desired phases, as shown in
Figure 4.1 (a).
Direct measurement of
current in a single-phase circuit is obtained by placing the instrument’s
current-operated coil in series with a main conductor, shown in Figure 4.1
(b). In the 3-phase case it is not
possible to select phases for current measurement unless current transformers
are used. It would otherwise be
necessary to break each phase to connect the ammeter, and this would not be
acceptable. Selection with the use of
current transformers is shown under ‘Indirect Measurement’ in Figure 4.2. Alternatively three separate ammeters may be
used.
The currents in the
separate phases can, however, be measured independently by use of a clip-on
type ammeter (also known by the trade name ‘Tong Test’). Different ammeter instruments can be plugged
into the tongs to give current ranges from 10A to 1 000A. On some types the range is altered by a
switch on the tester.
Direct measurement has
serious disadvantages. In high-voltage
systems the instrument or relay would have to be insulated up to the full
system voltage, which for a normal sized switchboard instrument is not
practical. Current-operated instruments
would not only have to be insulated up to the full system voltage, they would
also have to carry the full normal current of the circuit and to withstand the
extreme fault currents. This, too, is
not practical except for the lightest circuits.
4.3 INDIRECT MEASUREMENT
To overcome these
objections indirect measurement is employed.
Transformers are used not only to scale down the quantities actually
measured, but also to isolate the instrument or relay from the main system
voltage. Such transformers, which are
designed specifically for this purpose, are known as instrument transformers.
Instrument transformers
are of two types - ‘voltage transformers’ (VT) and ‘current transformers’
(CT). They are shown diagrammatically in
Figure 4.2 for both single-phase and 3-phase systems. For 3-phase there may be
either three separate single-phase VTs (with their ratios adjusted for the star
connection) as shown in the inset to the figure, or else a 3-phase unit, which
is more usual. Current transformers are always provided as separate
single-phase units.
The secondary voltages
and currents may be chosen as desired, but in practice the VT secondary voltage
is usually 110V line-to-line, and the CT secondary current 5A or 1A (see para.
4.7 for special caution when dealing with CT secondaries).
To select the phases
between which voltages are measured, a 3-position selector switch is used, as
in Figure 4.1, but connected to the VT secondaries. Further positions may be provided to measure
voltages between each phase and neutral.
To select the phases
in which currents are measured, a special selector switch is used which inserts
the ammeter into the CT secondary of the desired phase and at the same time
allows the secondary currents of the other two phases to pass. To avoid open-circuiting the CT secondaries,
all contacts are of the make-before-break type.
This is shown in Figure 4.2(b), bottom right.
FIGURE 4.2
INDIRECT MEASUREMENT WITH
INSTRUMENT TRANSFORMERS
A VT feeds, through
secondary fuses (except in the earthed line), all voltage-operated instruments
and relays in parallel, single- or 3-phase as required. Current-operated instruments and relays are
connected in series with the CT secondary whose phase is being used. Fuses must never be used in a CT secondary
circuit, for the reason stated in para. 4.7.
Instrument transformer
secondaries must always be earthed. With
star-connected VT secondaries it is normal practice to earth one phase (usually
the yellow) and not the star-point. CT
secondaries are normally commoned at some point, and it is usual to earth this
common line, as shown in Figure 4.2(b).
4.4 INSTRUMENT ACCURACY
Since the purpose of
instruments and relays is to monitor the actual conditions in the main power
line, it is necessary that VTs and CTs reproduce those conditions, to a
stepped-down scale, as accurately as possible.
That is to say their voltage ratio or current ratio must be correct and
constant over their whole range of operation; they must not introduce undue
phase shift while doing so (important for wattmeters); and they must reproduce
unbalance conditions exactly.
The extent to which
these conditions are met determines the accuracy class of the instrument
transformer. A distinction is drawn
between ‘measuring’ and ‘protective’ types.
For measurements, the accuracy within, and a little above, the normal
working range is important, but accuracy in the overcurrent and fault ranges of
current does not matter. On the other
hand, a protective CT must deliver accurate currents in the fault range,
whereas accuracy in the working range is unimportant. This gives rise to two
different design concepts.
The classes of
accuracy are laid down by British Standards (BS 3941 for VTs and BS 3938 for
CTs). For each type different ranges of
accuracy are specified for measurement and for protective transformers
according to the purpose for which they are to be used. The ranges are as
follows:
VTs
(BS 3941)
|
CTs
(BS 3938)
|
||||
Class
|
Voltage Ratio Error
|
Phase Displ
|
Class
|
Current Ratio Error
|
Phase Displ
|
Measurement
0.1
0.2
0.5
1
3
|
±0.1%
±0.2%
±0.5%
±1.0%
±3.0%
|
±5’ (angle)
±10’
±20’
±40’
not spec
|
0.1
0.2
0.5
1
3
5
|
±0.25 – 0.1%
±0.5 – 0.2%
±1.0 – 0.5%
±2.0 – 1.0%
±3%
±5%
|
±10’ – 5’
±20’ – 10’
±60’ – 30’
±120’ – 60’
not spec
not spec
|
Protective
3P
6P
|
±3%
±6%
|
±120’
±240’
|
5P
10P
|
±1%
±3%
|
±60’
±60’
|
Special |
X
|
as specified
|
(Note: These
classifications replace the former A-B-C series, which is, however, still found
on equipment installed before the change.)
Most indicating
instruments on onshore and offshore switchboards are fed from VTs and CTs of
Class 0.5, and most protective relays
from VTs Class 3P and CTs Class 5P.
There are, however, exceptions (for example differential relays are fed
from Class X CTs), and it is necessary to refer to drawings for particular
cases.
If it is ever
necessary to check or recalibrate a switchboard instrument or relay, it must
always be done with instrument transformers of a class higher than those with
which it normally runs.
4.5 VOLTAGE TRANSFORMER DESIGN
A voltage transformer
is made basically like an ordinary open-type power transformer, with separate
HV and LV
windings. It is, of course, much smaller, having ratings in the range 15 to
200VA per phase. The loading on a VT (or CT) is termed ‘burden’, not ‘load’; an
instrument transformer burden is always measured in volt-amperes, never in
watts. At voltages up to those found in Shell installations, VTs are always
dry-type, often embedded in synthetic resin. They are usually located inside
the switchboards. On shore equipments, especially when associated with
high-voltage oil circuit-breakers, VTs are often in oil-filled tanks (see
Figure 2.1 of Part A of this manual).
The high-voltage VT
primary fuses are of the HRC type. They have a low current rating but are
capable of breaking the full busbar fault current of the HV system. They are
located in the VT compartment and with some types are embodied in the VT
itself.
Access to the
high-voltage VT and its fuses is through the VT compartment door. This cannot
be opened until the VT has been isolated. The manner of isolation varies with
different manufacturers.
4.6 CURRENT TRANSFORMER DESIGN
A current transformer
can take one of two forms. One type is wound like an ordinary transformer, with
primary and secondary windings round a common core. As a CT steps current down,
it steps voltage up. The primary winding, though connected in the system’s
high-voltage system, is in fact the LV (high current) winding as far as the
transformer is concerned, and the secondary is the HV (low current) winding.
Wound-primary CTs are used where the primary current is low and where it is
necessary to have several primary turns to achieve enough ampere-turns in the
CT. The examples shown in Figure 4.3(a) and (b) are typical; burdens are in the
range 5 to 30VA per phase. Wound-primary CTs must be able to withstand the full
voltage and fault current of the main system on their primary windings.
FIGURE 4.3
TYPICAL CURRENT TRANSFORMERS
An alternative form of
CT is known as the ‘bar’ or ‘ring’ type.
It has no primary ‘winding’ as such but uses the main conductor itself
as a ‘one-turn’ primary. The flux
surrounding the conductor, due to the current it is carrying, links the closed
iron core of the CT and induces voltage in the secondary winding, which is
wound as a toroid around the circular core.
The secondary circuit is closed through its burden, and the current
which flows in it is an exact scaled-down replica of the primary current in the
conductor.
Bar-type CTs are
generally used whenever the current ratio (e.g. 1 500/1A) is large
enough. They are also convenient in that
several can easily be stacked over a single existing conductor. It is very important that they be placed the
right way up, otherwise the secondary terminal voltages and current flow will be
reversed. By convention the secondary
terminal S1 always has the same polarity as primary terminal P1, or as that of
the end of the bar emerging from the face marked P1. This type of CT is shown in Figure
4.3(c). Its construction is not limited
by the fault current of the main system.
Another important
difference between a CT and other types of transformer lies in its
magnetisation. The magnetising current,
and therefore the flux, of a power transformer or a VT is constant and depends
only on the applied voltage. However a
CT when it has no burden is effectively short-circuited, and no voltage is
present, whatever the primary current; therefore there is no core flux. If the burden is increased, so also is the
voltage for a given current, as explained in para. 4.7, and this causes the magnetisation
to increase. Thus with a current
transformer the magnetisation is variable not only with the current, but it
also is increased depending on the burden connected.
In the limit, if the
burden is increased beyond the rating of the CT, the core will saturate, and
the current ratio of the CT will no longer hold; it will become
inaccurate. Moreover the iron losses
will rise sharply and may cause severe overheating of the CT and possibly
damage to it.
4.7 SPECIAL DANGERS WITH CURRENT TRANSFORMERS
When a CT secondary
circuit is closed, a current flows through it which is an exact proportion of
the primary current, regardless of the resistance of the burden. In Figure 4.4(a) the secondary of the CT
(assumed to have a ratio of 1 000/5A and to have 1 000A flowing in the primary)
is carrying exactly 5A, and, since the secondary terminals S1 and S2 are
short-circuited, there is no voltage between them.
If now the
short-circuit be replaced by a resistance of, say, 0.5 ohm (as in Figure
4.4(b)), the same 5A will flow through, causing a volt-drop of 2.5V and a
burden of 5 x 2.5 = 12.5VA. If the
resistance were increased to 5 ohms (as in Figure 4.4(c)), the terminal voltage
with 5A flowing would rise to 25V and the burden to 125VA. The greater the resistance, the greater would
be the voltage and burden until, as it approached infinity (the open-circuit
condition), so also in theory would the voltage (and burden) become
infinite. This cannot of course happen
in practice because the CT would saturate or the terminals flash over due to
the very high secondary voltage between them.
But it does show the danger of open-circuiting the secondary of a
running CT. Lethal voltages can be produced
at the point of opening. This is why CT secondaries are never fused.
The danger from an
open-circuited CT is twofold. It can
produce lethal voltages and so is a very real danger to personnel. The high voltage across the secondary winding
could also cause insulation failure in that winding, leading at best to
inaccuracy and at worst to burn out or fire.
Before ever an
instrument or relay is removed from the secondary loop of a running CT (if such
a thing had to be done), the wires feeding that instrument must first be
securely short-circuited at a suitable terminal box or, better, at the CT
itself. Similarly, if a running CT is
ever to be taken out of circuit, it must first be firmly shorted. CTs with 1A secondaries are more dangerous
than those with 5A, as the induced voltages are higher.
FIGURE 4.4
VOLTAGE AND BURDEN OF A CURRENT
TRANSFORMER
To prevent this danger
many CT secondaries are permanently short-circuited by a ‘metrosil’, which is a
non-linear element with a high resistance at low voltages but which breaks down
to almost a short-circuit at the higher and dangerous voltages. It does, however, somewhat reduce the
accuracy of the CT and is not always acceptable for this reason.
There is also a range
of CTs designed to saturate if their burden becomes excessive, so that even on
open-circuit their secondary voltage will not exceed about 100V. It is not safe,
however, to assume that such CTs are fitted in any particular case.
WHENEVER POSSIBLE THE
MAIN CIRCUIT SHOULD BE MADE DEAD BEFORE INTERFERING WITH CT SECONDARIES OR
THEIR INSTRUMENTS OR RELAYS.
4.8 CALCULATION OF AN INSTRUMENT TRANSFORMER BURDEN
Instrument
transformers are rated according to the burden that they can carry and still
remain within their specified accuracy.
The burdens are always given in VA units (i.e. power factor is ignored),
and all burdens are simply added together.
Manufacturers of instruments and relays similarly state the burdens of
these devices in VA. Thus, if a CT
operates an ammeter (2VA), a current relay (3VA) and, say, the current coil of
a kWh meter (4VA), the total burden on the CT of these three devices will be
9VA.
The burden imposed by
long secondary pilot leads, however, cannot be ignored. If, for example, the total resistance of a CT
secondary run were 0.5 ohms (go and return) and the CT had a 5A secondary, the
total volt-drop across the pilots would be 0.5 x 5 = 2.5V. With 5A current flowing in them, the burden
of the pilot leads would be 2.5V x 5A = 12.5 VA, and this would need to be
added to that of the instruments (9VA above) to give a total burden on the CT
of 12.5 + 9 = 21.5VA. It must therefore
have a rating sufficient to meet this total burden. In general, pilot leads impose far less VA
burden on a 1A current transformer than on a 5A.
FIGURE 4.5
CALCULATION OF CT BURDEN
In Figure 4.5 a 20VA
CT with full-load secondary current of 5A supplies two ammeters, a current
relay, a wattmeter and a kWh meter with VA burdens as shown. The pilot leads have a resistance of 0.1 ohm per
core. Is the 20VA rating of the CT
sufficient?
Total instrument burden = 2 + 2 + 3 + 2 + 4 = 13VA.
Total pilot load resistance = 2 x 0.1 = 0.2 ohm.
With 5A secondary current, volt-drop in leads is 5 x 0.2 = 1V.
Burden imposed by both leads = 5A x 1V = 5VA.
\Total burden on CT = 13 + 5
= 18VA.
As the CT is rated
20VA, it has sufficient margin.
The reader should work
out for himself what would be the total burden if the CT had a 1A secondary.
4.9 LOCATION OF CTs AND VTs
Current and voltage
transformers can be located anywhere desired where the primary conductors are
available, but in HV switchgear they are usually incorporated in special
chambers in the switchgear unit itself.
Figures 3.1 and 3.3 in Part A of this manual show views of typical HV
circuit-breaker units, where the VT and CT chambers can be clearly seen. The VT can be drawn forward to isolate it
from the busbars. Other manufacturers’
arrangements differ in detail, especially in the front or back access to the VT
chamber.
4.10 INSTRUMENTS
A.C. instruments
include voltmeters, ammeters, wattmeters, varmeters, power factor meters,
frequency meters and synchroscopes.
Voltmeters, ammeters and frequency meters are almost all of the
moving-iron or transducer-operated type, with an accuracy of 2% full-scale
deflection. Wattmeters and varmeters are
of the dynamometer type, and power factor meters and synchroscopes have two
sets of fixed coils and a moving-iron armature.
All voltage-operated coils (except those for 415V or 440V or less which
may be direct-fed) are fed through VTs, and all current-operated coils through
CTs at all voltages.
4.11 EXAMPLE - INSTRUMENTATION FOR A GENERATOR
Figure 4.6 shows a
typical set of instrumentation for an offshore high-voltage generator. One complete set of indicating instruments is
normally located on the electrical control panel in the Electrical Control
Room; a second set is mounted on the generator local control panel. A megawatt meter for each generator may also
be mounted on the main control panel in the Platform Control Room if this is
separate from the Electrical Control Room.
The generator circuit-breaker panel usually carries one ammeter and a
voltmeter.
FIGURE 4.6
TYPICAL INSTRUMENTATION FOR A
MAIN GENERATOR
Since wattmeter,
varmeter, power factor meter and frequency meter movements tend to be
expensive, an alternative which is being increasingly used is the
transducer-operated instrument. Here the
VT and CT signals are fed into static electronic a.c./d.c. transducers, and a d.c. voltage signal is
produced from each which faithfully represents the a.c. watts, vars, power
factor or frequency. These are led to
simple d.c.
voltmeter-type moving-coil instruments, but which are
scaled in watts, vars, power factor or hertz.
Many such instruments can be connected in parallel. Figure 4.7 shows
typical connections. They can also be
seen in Figure 4.6 where the transducers for wattmeters, power factor meters
and frequency meters are indicated by the blocks with diagonal line.
FIGURE 4.7
TRANSDUCER OPERATED INSTRUMENTS
Where two or more such
instruments are used from the same transducer, they are connected in
parallel. Some instruments have their
transducer in the instrument case; others have the transducer in a separate
box, especially if it operates more than one instrument.
Kilowatt-hour or
megawatt-hour meters are fed through VTs and CTs whose connections are the same
as for a wattmeter. As kWh meters are
often used onshore as a basis for financial charging, they sometimes operate
through VTs and CTs of a higher standard of accuracy.
4.12 TARIFF METERING
In onshore
installations, where the supply is taken from the National Grid, the Supply
Authority tariff takes account of maximum demand and power factor as well as
actual energy consumption in kilowatt-hours.
At the main substation therefore, where the supplies are taken, the
Supply Authority installs sealed meters to record kilowatt-hours, kilovarhours
and maximum demand. In larger
installations the maximum demand is measured in kVA; in smaller it is in kW. It is averaged over each successive period of
30 minutes and then it resets.
A fuller description
of how tariff metering is carried out will be found in the manual ‘Onshore
Electrical Systems’, and methods of power factor control are described in the
manual ‘Electrical System Control’.
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