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An Efficient System for Bulk Power Transmission Balachandar.V (09EER013), Dinesh Kumar.G (09EER027)
III BE ±ELECTRICAL & ELECTRONICS ENGINEERING
Kongu engineering college, Perundurai, Erode - 638 052, India.
Abstract: Beginning with a brief historical
perspective on the development of high voltage direct
current (hvdc) transmission systems, this paperpresents an overview of the status of HVDC systems
in the world today. it then reviews the underlyingtechnology of HVDC systems, and discusses the
HVDC systems from a design, construction, operation
and maintenance points of view. the paper thendiscusses the recent developments in HVDC
technologies. the paper also presents an economic and
financial comparison of HVDC system with those of an ac system; and provides a brief review of reference
installations of HVDC systems. the paper concludeswith a brief set of guidelines for choosing HVDC
systems in today¶s electricity system development.
INTRODUCTION:
A high-voltage, direct current (HVDC)
electric power transmission system uses direct
current for the bulk transmission of electrical
power, in contrast with the more common
alternating current systems. For long-distance
transmission, HVDC systems may be less
expensive and suffer lower electrical losses. For underwater power cables, HVDC avoids the heavy
currents required by the cable capacitance. For
shorter distances, the higher cost of DC conversion
equipment compared to an AC system may still be
warranted, due to other benefits of direct current
links. HVDC allows power transmission between
unsynchronized AC distribution systems, and can
increase system stability by preventing cascading
failures from propagating from one part of a wider
power transmission grid to another.
THE HVDC TECHNOLOGY:
The fundamental process that occurs in an HVDCsystem is the conversion of electrical current from
AC to DC (rectifier) at the transmitting end and
from DC to AC (inverter) at the receiving end.
There are three ways of achieving conversion
NATURAL COMMUTATED CONVERTERS
(NCC):
Natural commutated converters are most
used in the HVDC systems as of today. The
component that enables this conversion process is
the thyristor, which is a controllable semiconductor
that can carry very high currents (4000 A) and is
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able to block very high voltages (up to 10 kV). By
means of connecting the thyristors in series it is
possible to build up a thyristor valve, which is able
to operate at very high voltages (several hundred of
kV).The thyristor valve is operated at net frequency
(50 Hz or 60 Hz) and by means of a control angle itis possible to change the DC voltage level of the
bridge. This ability is the way by which thetransmitted power is controlled rapidly and
efficiently.
CAPACITOR COMMUTATED CONVERTERS
(CCC):
An improvement in the thyristor-based
Commutation, the CCC concept is characterised by
the use of commutation capacitors inserted in series
between the converter transformers and the
thyristors valves. The commutation capacitors
improve the commutation failure performance of
the converters when connected to weak networks.
FORCED COMMUTATED CONVERTERS(FCC):
This type of converters introduces a
spectrum of advantages, e.g. feed of passive
networks (without generation), independent control
of active and reactive power, power quality. The
valves of these converters are built up with
semiconductors with the ability not only to turn-on but also to turn-off. They are known as VSC
(Voltage Source Converters). Two types of
semiconductors are normally used in the voltage
source converters: the GTO (Gate Turn-Off
Thyristor) or the IGBT (Insulated Gate Bipolar
Transistor). Both of them have been in frequent use
in industrial applications since early eighties. The
VSC commutates with high frequency (not with the
net frequency). The operation of the converter
is achieved by Pulse Width Modulation (PWM).
With PWM it is possible to create any phase
Angle and/or amplitude (up to a certain limit) bychanging the PWM pattern, which can be one
almost instantaneously. Thus, PWM offers the
possibility to control both active and reactive
power independently. This makes the PWM
Voltage Source Converter a close to ideal
component in the transmission network. From a
transmission network viewpoint, it acts as a motor
or generator without mass that can control active
and reactive power almost instantaneously.
THE COMPONENTS OF AN HVDCTRANSMISSION SYSTEM:
To assist the designers of transmission
systems, the components that comprise the HVDC
system, and the options available in these
components, are presented and discussed. The three
main elements of an HVDC system are:
A. THE CONVERTER STATION:
The converter stations at each end arereplica¶s of each other and therefore consists
of all the needed equipment for going from AC to
DC or vice versa. The main component of a
converter station are:
1. THYRISTOR VALVES:
The thyristor valves can be build-up in different
ways depending on the application andmanufacturer. However, the most common way of
arranging the thyristor valves is in a twelve-pulse
group with three quadruple valves. Each single
thyristor valve consists of a certain amount of series connected thyristors with their auxiliary
circuits. All communication between the control
equipment at earth potential and each thyristor at
high potential, is done with fibre optics.
2. VSC VALVES:
The VSC converter consists of two level
or multilevel converter, phase-reactors and AC
filters. Each single valve in the converter bridge is
built up with a certain number of seriesconnectedIGBTs together with their auxiliary electronics.VSC valves, control equipment and cooling
equipment would be in enclosures (such as
standard shipping containers) which make
transport and installation very easy. All modern
HVDC valves are water-cooled and air insulated.
3. TRANSFORMERS:
The converter transformers adapt the AC
voltage level to the DC voltage level and they
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contribute to the commutation reactance. Usually
they are of the single phase three winding type, but
depending on the transportation requirements and
the rated power, they can be arranged in other
ways.
B. FILTERS:
1. AC Filters and Capacitor Banks:On the AC side of a 12-pulse HVDC
converter, current harmonics of the order of 11, 13,
23, 25 and higher are generated. Filters are installed
in order to limit the amount of harmonics to the
level required by the network.. In the conversion
process the converter consumes reactive power
which is compensated in part by the filter banks
and the rest by capacitor banks.
In the case of the CCC the reactive power is
compensated by the series capacitors installed in
series between the converter valves and the
converter transformer. The elimination of switched
reactive power compensation equipment simplify
the AC switchyard and minimise the number of circuit-breakers needed, which will reduce the area
required for an HVDC station built with CCC.
With VSC converters there is no need to
compensate any reactive power consumed by the
converter itself and the current harmonics on the
AC side are related directly to the PWM
frequency. Therefore the amount of filters in thistype of converters is reduced dramatically
compared with natural commutated converters.
DC filters: HVDC converters create harmonics in
all operational modes. Such harmonics can
create disturbances in telecommunication systems.
Therefore, specially designed DC filters are
used in order to reduce the disturbances. Usually no
filters are needed for pure cable transmissions
as well as for the Back-to-Back HVDC stations.
However, it is necessary to install DC filters if an
OH line is used in part or all the transmission
system The filters needed to take care of theharmonics generated on the DC end, are usually
considerably smaller and less expensive than the
filters on the AC side. The modern DC filters are
the Active
2. DC filters:
In these filters the passive part is reduced
to a minimum and modern power electronics is
used to measure, invert and re-inject the harmonics,
thus rendering the filtering very effective.
C. TRANSMISSION MEDIUM:
For bulk power transmission over land, the
most frequent transmission medium used is the
overhead line. This overhead line is normally
bipolar, i.e. two conductors with different polarity.
HVDC cables are normally used for submarine
transmission. The most common types of cables are
the solid and the oil -filled ones. The solid type is in
many cases the most economic one. Its insulation
consists of paper tapes impregnated with a high
viscosity oil. No length limitation exists for this
type and designs are today available for depths of
about 1000 m. The self ±contained oil-filled cable
is completely filled with a low viscosity oil andalways works under pressure. The maximum length
for this cable type seems to be around 60 km.The development of new power cable technologies
has accelerated in recent years and today a new
HVDC cable is available for HVDC underground
or submarine power transmissions. This new
HVDC cable is made of extruded polyethylene, and
is used in VSC based HVDC systems.
Design, Construction, Operation and Maintenance
considerations:
In general, the basic parameters such as
power to be transmitted, distance of transmission,
voltage levels, temporary and continuous overload,
status of the network on the receiving end,environmental requirements etc. are required to
initiate a design of an HVDC system. For tendering
purposes a conceptual design is done following a
technical specification or in close collaboration
between the manufacturer and the customer. The
final design and specifications are in fact the
result of the tendering and negotiations with themanufactures/suppliers. It is recommended that a
turnkey approach be chosen to contract execution,
which is the practice even in developed countries.
In terms of construction, it can take from three
years for thyristor-based large HVDC systems, to
just one year for VSC based HVDC systems to go
from contract date to commissioning. HVDC links
can be operated remotely, in view of the
semiconductor and microprocessor based control
systems included. There are some existing
installations in operation completely unmanned.
Moreover, modern HVDC systems are designed tooperate unmanned. This feature is particularly
important in situations or countries where skilled
people are few, and these few people can operate
several HVDC links from one central location.
Maintenance of HVDC systems is comparable to
those of high voltage AC systems. The high voltage
equipment in converter stations is comparable to
the corresponding equipment in AC substations,
and maintenance can be executed in the same way.
Maintenance will focus on: AC and DC filters,
smoothing reactors, wall bushings, valve-coolingequipment, thyristor valves. In all the above,
adequate training and support is provided by the
supplier during the installation, commissioning and
initial operation period. Normal routine
maintenance is recommended to be one week per
year. The newer systems can even go for two years
before requiring maintenance. In fact in a bipolar
system, one pole at a time is stopped during the
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time required for the maintenance, and the other
pole can normally continue to operate and
depending on the in-built overload capacity it can
take a part of the load of the pole under
maintenance. In addition, preventive maintenance
shall be pursued so that the plants and equipmentwill achieve optimally balanced availability with
regard to the costs of maintenance, operatingdisturbances and planned outages. As a guideline
value, the aim shall be to achieve an availability of
98 % according to Cigrè protocol 14-97. While
HVDC systems may only need a few skilled staff
for operation and maintenance, several factors
influence the number of staff needed at a station.
These factors are: local routines and regulations,
working conditions, union requirements, safety
regulations, and other local rules can separately or
together affect the total number of personnel
required for the type of installed equipment.
COST STRUCTURE:
The cost of an HVDC transmission system
depends on many factors, such as power capacity to
be transmitted, type of transmission medium,
environmental conditions and other safety,
regulatory requirements etc. Even when these areavailable, the options available for optimal design
(different commutation techniques, variety of
filters, transformers etc.) render it is difficult to
give a cost figure for an HVDC system.
Nevertheless, a typical cost structure for the
converter stations could be as follows:
As a guidance, an example showing the price
variation for an AC transmission compared with an
HVDC transmission for 2000 MW is presented
below.
The choice of DC transmission voltage level has a
direct impact on the total installation cost. At the
design stage an optimisation is done finding out the
optimum DC voltage from investment and losses
point of
View. The costs of losses are also very important -in the evaluation of losses the energy cost and the
time horizon for utilisation of the transmission have
to be taken into account. Finally the depreciation
period and desired rate of return (or discount rate)
should be considered. Therefore, to estimate the
costs of an HVDC system, it is recommended that
life cycle cost analysis is undertaken. Two different
comparisons are needed to highlight the cost
comparison between high voltage AC and HVDC
systems
1. Between thyristor based HVDC systems
and a high voltage AC transmission
System
2. Between a VSC based HVDC system; anAC system and a local generation source.
THYRISTOR BASED HVDC SYSTEM VERSUS
HIGH VOLTAGE AC SYSTEM:
The investment costs for HVDC converter
stations are higher than for high voltage AC
substations. On the other hand, the costs of transmission medium (overhead lines and cables),
land acquisition/right-of-way costs are lower in the
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HVDC case. Moreover, the operation and
maintenance costs are lower in the HVDC case.
Initial loss levels are higher in the HVDC system,
but they do not vary with distance. In contrast, loss
levels increase with distance in a high voltage AC
system. The following picture shows the cost breakdown (shown with and without considering
losses).
The breakeven distance depends on
several factors, as transmission medium (cable or
OH line), different local aspects (permits, cost of
local labour etc.). When comparing high voltage
AC with HVDC transmission, it is important to
compare a bipolar HVDC transmission to a double-
circuit high voltage AC transmission, especially
when availability and reliability is considered.
VSC based HVDC system versus an AC system or
a local generation source: VSC based HVDC
systems cater to the small power applications (up to200MW) and relatively shorter distances (hundred
of km) segment of the power transmission
spectrum. The graph below shows that, the VSC
based HVDC system is the better alternative
economically when compared to either an high
voltage AC system or a generationsource local to
the load centre (e.g., diesel generator).
However, the break-even distance and
power transfer level criteria and the comparative
cost information should be taken in the proper
perspective, because of the following reasons:
01. in the present (and future) industry environment
of liberalised competitive markets and heightened
efforts to conserve the environment. In such an
environment, the alternative for a transmission
system is an in-situ gas-fired combined cycle
power plant, not necessarily an option between an
AC transmission and a HVDC one.
02. Second, the system prices for both AC and
HVDC have varied widely even for a given level
of power transfer. For example, several different
levels of project costs have been incurred for a HVDC system with a power transfer capacity of
600 MW. What this shows therefore is that,
in addition to the criteria mentioned above (power
levels, distance, transmission medium,
environmental conditions etc.), the market
conditions at the time of the project is a critical
Factor, perhaps more so than the numerical
comparisons between the costs of an AC or DC
System.
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03. Third, technological developments have tended
to push HVDC system costs downward, while the
environmental considerations have resulted in
pushing up the high voltage AC system costs.
Therefore, for the purposes early stage feasibility
analysis of transmission system type, it is perhaps better to consider HVDC and high voltage AC
systems as equal cost alternatives.
ADVANTAGES OF HVDC OVER AC
TRANSMISSION:
The advantage of HVDC is the ability to transmit
large amounts of power over long distances with
lower capital costs and with lower losses than AC.
Depending on voltage level and construction
details, losses are quoted as about 3% per
1,000 km.[15] High-voltage direct current
transmission allows efficient use of energy sources
remote from load centers.
In a number of applications HVDC is more
effective than AC transmission. Examples include:
y Undersea cables, where high capacitance
causes additional AC losses. (e.g., 250 km
Baltic Cable between Sweden and
Germany,[16]
the 600 km NorNed cable
between Norway and the Netherlands, and290 km Basslink between the Australian
mainland and Tasmania[17])
y Endpoint-to-endpoint long-haul bulk power transmission without intermediate
'taps', for example, in remote areas
y Increasing the capacity of an existing
power grid in situations where additional
wires are difficult or expensive to install
y Power transmission and stabilization
between unsynchronised AC distribution
systems
y Connecting a remote generating plant to
the distribution grid, for example Nelson
River Bipoley Stabilizing a predominantly AC power-
grid, without increasing prospective short
circuit current
y Reducing line cost. HVDC needs fewer
conductors as there is no need to support
multiple phases. Also, thinner conductors
can be used since HVDC does not suffer
from the skin effect
y Facilitate power transmission between
different countries that use AC at differing
voltages and/or frequencies
y Synchronize AC produced by renewable
energy sources
Long undersea / underground high voltage cables
have a high electrical capacitance, since theconductors are surrounded by a relatively thin layer
of insulation and a metal sheath while the extensive
length of the cable multiplies the area between the
conductors. The geometry is that of a long co-axial
capacitor. Where alternating current is used for
cable transmission, this capacitance appears in
parallel with load. Additional current must flow in
the cable to charge the cable capacitance, which
generates additional losses in the conductors of the
cable. Additionally, there is a dielectric loss
component in the material of the cable insulation,
which consumes power.
However, when direct current is used, the cable
capacitance is charged only when the cable is first
energized or when the voltage is changed; there is
no steady-state additional current required. For a
long AC undersea cable, the entire current-carrying
capacity of the conductor could be used to supply
the charging current alone. The cable capacitance
issue limits the length and power carrying capacity
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of AC cables. DC cables have no such limitation,
and are essentially bound by only Ohm's Law.
Although some DC leakage current continues to
flow through the dielectric insulators, this is very
small compared to the cable rating and much less
than with AC transmission cables.
HVDC can carry more power per conductor because, for a given power rating, the constant
voltage in a DC line is the same as the peak voltage
in an AC line. The power delivered in an ACsystem is defined by the root mean square (RMS)
of an AC voltage, but RMS is only about 71% of
the peak voltage. The peak voltage of AC
determines the actual insulation thickness and
conductor spacing. Because DC operates at a
constant maximum voltage, this allows existing
transmission line corridors with equally sized
conductors and insulation to carry more power into
an area of high power consumption than AC, which
can lower costs.
Because HVDC allows power transmission
between unsynchronized AC distribution systems,
it can help increase system stability, by preventing
cascading failures from propagating from one part
of a wider power transmission grid to another.Changes in load that would cause portions of an
AC network to become unsynchronized and
separate would not similarly affect a DC link, and
the power flow through the DC link would tend to
stabilize the AC network. The magnitude and
direction of power flow through a DC link can be
directly commanded, and changed as needed to
support the AC networks at either end of the DC
link. This has caused many power system operatorsto contemplate wider use of HVDC technology for
its stability benefits alone.
DISADVANTAGES:
The disadvantages of HVDC are in conversion,
switching, control, availability and maintenance.
1. HVDC is less reliable and has lower availability
than AC systems, mainly due to the extra
conversion equipment. Single pole systems have
availability of about 98.5%, with about a third of
the downtime unscheduled due to faults. Fault
redundant bipole systems provide high availability
for 50% of the link capacity, but availability of the
full capacity is about 97% to 98%. [18]
2. The required static inverters are expensive and
have limited overload capacity. At smaller
transmission distances the losses in the static
inverters may be bigger than in an AC transmission
line. The cost of the inverters may not be offset byreductions in line construction cost and lower line
loss. With two exceptions, all former mercury
rectifiers worldwide have been dismantled or
replaced by thyristor units.
3. High voltage DC circuit breakers are difficult to
build because some mechanism must be included in
the circuit breaker to force current to zero,
Otherwise arcing and contact wear would be toogreat to allow reliable switching.
4. Operating a HVDC scheme requires many spare
parts to be kept, often exclusively for one system as
HVDC systems are less standardized than AC
systems and technology changes faster.
CORONA DISCHARGE:
Corona discharge is the creation of ions in
a fluid (such as air) by the presence of a strong
electric field. Electrons are torn from neutral air,
and either the positive ions or the electrons are
attracted to the conductor, while the charged
particles drift. This effect can cause considerable
power loss, create audible and radio-frequency
interference, generate toxic compounds such asoxides of nitrogen and ozone, and bring forth
arcing.
Both AC and DC transmission lines can
generate coronas, in the former case in the form of oscillating particles, in the latter a constant wind.
Due to the space charge formed around the
conductors, an HVDC system may have about half
the loss per unit length of a high voltage AC system
carrying the same amount of power. With
monopolar transmission the choice of polarity of
the energized conductor leads to a degree of control
over the corona discharge. In particular, the
polarity of the ions emitted can be controlled,
which may have an environmental impact on
particulate condensation. (particles of different
polarities have a different mean-free path.) Negative coronas generate considerably more
ozone than positive coronas, and generate it further
downwind of the power line, creating the potential
for health effects. The use of a positive voltage will
reduce the ozone impacts of monopole HVDC
power lines.
APPLICATIONS:
01. Three different dynamics - technology
development, deregulation of electricity
industry around the world, and a quantum leap in
efforts to conserve the environment - are
demanding a change in thinking that could make
HVDC systems the preferred alternative to high
voltage AC systems in many other situations aswell. To elaborate:
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02. New technologies, such as the VSC based
HVDC systems, and the new ext
uded polyethylene
DC cables, have made it possi ble for HVDC to
become economic at lower power levels (up to
200 M¡
¢ and over a transmission distance of just
60 km.03. Li berali £ ation has brought other demands on
the power infrastructure overall. Transmission isnow a contracted service, and there is very little
room for deviation from contracted technical
and economic norms. HVDC provides much better
control of the power link and is therefore a better
way for providing contractual transmission
services.
04. Li berali £ ation has brought on the phenomenon
of trading to the electr icity sector, which would
mean bi ¤ directional power transfers, depending on
market conditions. HVDC systems enable the bi ¤
directional power f lows, which is not possi ble with
AC systems (two parallel systems would be
required).
05. In the past, when the transmission service was par t of a government owned, ver tically integrated
utility, the land acquisition and obtaining r ights-of-
way was relatively easier, and very of ten was done
under the pr inci ple of ³Eminent Domain´ of the
State. With li berali £ ation, transmission service
provision is by and large in the domain of
corporati £ ed, sometimes pr ivati £ ed, entities. Landacquisition and/or obtaining r ights-of-way is now a
signif icant por tion of the pro ject ¥ s costs. Once
these costs are included in their entirety in the
economical analysis of HVDC versus AC
alternatives, it would be seen that HVDC is much
more economical in this regard, since it requires
much less land/r ight-of-way for a given level
of power.
06. In an environmentally sensitive areas, such as
national parks and protected sanctuar ies, the
lower foot pr int of HVDC transmission systems
becomes the only feasi ble way to build a power link.
07. The functional specif ications could lay down
the power capacity, distance, availability and
reliability requirements; and last but not least, the
environmental conditions.
08. The bidders should be allowed to bid either an
HVDC solution or an AC solution; and the best
option chosen. It is quite conceivable that with
changed circumstances in the electr icity industry,
the technological developments, and environmental
considerations, HVDC would be the preferredalternative in many more transmission pro jects.
CONFIGUR ATIONS:
1. MONOPOLE AND EAR TH R ETUR N:
MONOPOLAR CONVER TER STATION 600MW
± 450 KV DC
In a common conf iguration, calledmonopole, one of the terminals of the rectif ier is
connected to ear th ground. The other terminal, at a
potential high above or below ground, is connected
to a transmission line. The ear thed terminal may be
connected to the corresponding connection at the
inver ting station by means of a second conductor.If no metallic conductor is installed, current f lows
in the ear th between the ear th electrodes at the two
stations. Therefore it is a type of single wire ear th
return. The issues surrounding ear th-return current
include:
y Electrochemical corrosion of long bur ied
metal ob jects such as pi pelines
y Underwater ear th-return electrodes in
seawater may produce chlor ine or
otherwise affect water chemistry.
y An unbalanced current path may result in
a net magnetic f ield, which can affect
magnetic navigational compasses for shi ps passing over an underwater cable.
These effects can be eliminated with installation of
a metallic return conductor between the two ends of
the monopolar transmission line. Since one
terminal of the conver ters is connected to ear th, the
return conductor need not be insulated for the full transmission voltage which makes it less costly
than the high-voltage conductor. Use of a metallic
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return conductor is decided based on economic,
technical and environmental factors. Modern
monopolar systems for pure overhead lines carry
typically 1,500 MW.[25]
If underground or
underwater cables are used, the typical value is
600 MW.
Most monopolar systems are designed for future bi polar expansion. Transmission line towers
may be designed to carry two conductors, even if
only one is used initially for the monopoletransmission system. The second conductor is
either unused, used as electrode line or connected
in parallel with the other (as in case of Baltic-
Cable).
2. BIPOLAR:
Block diagram of a bi polar system that also has an
ear th return
In bi polar transmission a pair of conductors isused, each at a high potential with respect to
ground, in opposite polar ity. Since these conductors
must be insulated for the full voltage, transmission
line cost is higher than a monopole with a return
conductor. However, there are a number of
advantages to bi polar transmission which can make
it the attractive option.
y Under normal load, negligi ble ear th-
current f lows, as in the case of monopolar
transmission with a metallic ear th-return.
This reduces ear th return loss and
environmental effects.
y When a fault develops in a line, with ear threturn electrodes installed at each end of
the line, approximately half the rated
power can continue to f low using the ear thas a return path, operating in monopolar
mode.
y Since for a given total power rating each
conductor of a bi polar line carr ies only
half the current of monopolar lines, the
cost of the second conductor is reduced
compared to a monopolar line of the same
rating.
y In very adverse terrain, the secondconductor may be carr ied on an
independent set of transmission towers, so
that some power may continue to be
transmitted even if one line is damaged.
A bi polar system may also be installed with a
metallic ear th return conductor. Bi polar systems
may carry as much as 3,200 MW at voltages of +/-
600 kV. Submar ine cable installations initiallycommissioned as a monopole may be upgraded
with additional cables and operated as a bi pole.
A block diagram of a bi polar HVDC
transmission system, between two stations
designated A and B. AC ± represents an alternating
current network CON ± represents a conver ter
valve, either rectif ier or inver ter, TR represents a
power transformer, DCTL is the direct-current
transmission line conductor, DCL is a direct-
current f ilter inductor, BP represents a bypass
switch, and PM represent power factor correction
and harmonic f ilter networks required at both ends
of the link. The DC transmission line may be veryshor t in a back-to-back link, or extend hundreds of
miles (km) overhead, underground or underwater.One conductor of the DC line may be replaced by
connections to ear th ground.
A bi polar scheme can be implemented sothat the polar ity of one or both poles can be
changed. This allows the operation as two parallel
monopoles. If one conductor fails, transmission can
still continue at reduced capacity. Losses may
increase if ground electrodes and lines are not
designed for the extra current in this mode. To
reduce losses in this case, intermediate switching
stations may be installed, at which line segments
can be switched off or paralleli ¦ ed. This was done
at Inga±Shaba HVDC.
3. BACK TO BACK :
A back-to-back station (or B2B for shor t) is a
plant in which both static inver ters and rectif iers
are in the same area, usually in the same building.
The length of the direct current line is kept as shor t
as possi ble. HVDC back-to-back stations are used
for
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y coupling of electricity mains of different
frequency (as in Japan; and the GCC
interconnection between UAE [50 Hz] and
Saudi Arabia [60 Hz] under construction
in§
2009§
2011)
y coupling two networks of the samenominal frequency but no fixed phase
relationship (as until 1995/96 inEtzenricht, Dürnrohr, Vienna, and the
Vyborg HVDC scheme).
y different frequency and phase number (for
example, as a replacement for traction
current converter plants)
The DC voltage in the intermediate circuit can
be selected freely at HVDC back-to-back stations
because of the short conductor length. The DC
voltage is as low as possible, in order to build a
small valve hall and to avoid series connections of
valves. For this reason at HVDC back-to-back
stations valves with the highest available current
rating are used.
4. SYSTEMS WITH TRANSMISSION
LINES:
The most common configuration of an HVDC link
is two inverter/rectifier stations connected by an
overhead power line. This is also a configuration
commonly used in connecting unsynchronised
grids, in long-haul power transmission, and in
undersea cables. Multi-terminal HVDC links,connecting more than two points, are rare. The
configuration of multiple terminals can be series,
parallel, or hybrid (a mixture of series and parallel).
Parallel configuration tends to be used for largecapacity stations, and series for lower capacity
stations. An example is the 2,000 MW Quebec -
New England Transmission system opened in
1992, which is currently the largest multi -terminal
HVDC system in the world. [26]
5. TRIPOLE: CURRENT-MODULATING
CONTROL:
A scheme patented in 2004 (Current modulation of
direct current transmission lines) is intended for
conversion of existing AC transmission lines to
HVDC. Two of the three circuit conductors areoperated as a bipole. The third conductor is used as
a parallel monopole, equipped with reversing
valves (or parallel valves connected in reverse
polarity). The parallel monopole periodically
relieves current from one pole or the other,
switching polarity over a span of several minutes.
The bipole conductors would be loaded to either
1.37 or 0.37 of their thermal limit, with the parallel
monopole always carrying +/- 1 times its thermal
limit current. The combined RMS heating effect isas if each of the conductors is always carrying 1.0
of its rated current. This allows heavier currents to be carried by the bipole conductors, and full use of
the installed third conductor for energy
transmission. High currents can be circulated
through the line conductors even when load
demand is low, for removal of ice.
As of 2005, no tri-pole conversions are in
operation, although a transmission line in India has
been converted to bipole HVDC. Cross-Skagerrak
consists of 3 poles, from which 2 are switched in
parallel and the third uses an opposite polarity with
a higher transmission voltage. A similar
arrangement is HVDC Inter-Island, but it consists
of 2 parallel-switched inverters feeding in the same pole and a third one with opposite polarity and
higher operation voltage.
CONCLUSION:
Thus the various advantages of the HVDC system
over the normal transmission lines , its
temperament and characteristics were discussed in
this paper. The proper implementation of this
system ensures lesser loss of energy during
transmission.