a report on power plant with description on Rajasthan power plants

1. A
Seminar Report on
“THERMAL POWER PLANT ”
For the partial fulfillment of the
Bachelor of Technology in MECHANICAL ENGG.
Submitted By
MUKESH KUMAR
(B.Tech. Final Year)
Department of Mechanical Engineering
Anand International College of Engineering
RAJASTHAN TECHNICAL UNIVERSITY

2. EXAMINER’S CERTIFICATE
This is to certify that Mr. mukesh kumar Student of final Year B.Tech.
MECHANICAL ENGINEERING 2013-14 was examined in the seminar
work entitled “THERMAL POWER PLANT” at anand international
college of Engineering .
(Internal Examiner) (External Examiner)
Department of Mechanical Engineering
Anand international college of engineering
RAJASTHAN TECHNICAL UNIVERSITY

3. CERTIFICATE
This is to certify that the seminar entitled “THERMAL
POWER PLANT” has been successfully completed by
Mr. MUKESH KUMAR in partial fulfillment of Degree of
Bachelor of Technology in Mechanical branch of
RAJASTHAN TECHNICAL UNIVERSITY during the
academic year 2013-14 under the guidance of
undersigned.
H.O.D GUIDED BY
(MECH. DEPTT.) ANUP DUBAY
Department of Mechanical Engineering
Anand international college of engineering
RAJASTHAN TECHNICAL UNIVERSITY

4. ACKNOWLEDGMENT
I am thankful to Mr. ANUP DUBAY (GUIDE) Mechanical
Engineering, for giving me full guidance and supports during
the course of research on the topic.
I wish to express my profound sense of gratitude to all the
faculty members of MECHANICAL ENGINEERING Branch for
their delightful guidance and constant encouragement
throughout the process, they have always been a great
inspirational motivator for me.
I take this as my opportunity to express my whole hearted
thanks to all other persons involved in the process who made
it possible to achieve the completion of summer report with
success.
DATE MUKESH KUMAR
2-04-2014 B.TECH. Final Year
Mechanical Engg.

5. CONTENTS
 1 INTRODUCTORY OVERVIEW
 2 EFFICIENCY
 3 ELECTRICITY COST
 4 TYPICAL COAL THERMAL POWER STATION
 5 BOILER AND STEAM CYCLE
o 5.1 FEED WATER HEATING AND DEAERATION
o 5.2 BOILER OPERATION
o 5.3 BOILER FURNACE AND STEAM DRUM
o 5.4 SUPERHEATER
o 5.5 STEAM CONDENSING
o 5.6 REHEATER
o 5.7 AIR PATH
 7 STEAM TURBINE GENERATOR
 8 STACK GAS PATH AND CLEANUP
o 8.1 FLY ASH COLLECTION
o 8.2 BOTTOM ASH COLLECTION AND DISPOSAL
 9 AUXILIARY SYSTEMS
o 9.1 BOILER MAKE-UP WATER TREATMENT PLANT AND
STORAGE
o 9.2 FUEL PREPARATION SYSTEM
o 9.3 BARRING GEAR
o 9.4 OIL SYSTEM
o 9.5 GENERATOR COOLING
o 9.6 GENERATOR HIGH-VOLTAGE SYSTEM
o 9.7 MONITORING AND ALARM SYSTEM
o 9.8 BATTERY-SUPPLIED EMERGENCY LIGHTING AND
COMMUNICATION
 10 TRANSPORT OF COAL FUEL TO SITE AND TO STORAGE
 11 LOCATION OF POWER PLANTS IN INDIA
 12 POWER PLANTS IN RAJASTHAN
12.1KOTA THERMAL POWER PLANT
12.2 SURATGARH SUPER THERMAL POWER STATION
12.3GIRAL LIGNITE THERMAL POWER PROJECT
12.4CHHABRA THERMAL POWER STATION
12.5KALISINDH THERMAL POWER PROJECT
12.6RAMGARH GAS THERMAL POWER STATION
12.7DHOLPUR COMBINED CYCLE POWER STATION
 REFERENCES

6. INTRODUCTORY OVERVIEW
A station thermal power is a power plant in which the prime mover is steam driven. Water is
heated, turns into steam and spins a steam turbine which drives an electrical generator. After
it passes through the turbine, the steam is condensed in a condenser and recycled to where it
was heated; this is known as a Rankine cycle. The greatest variation in the design of thermal
power stations is due to the different fossil fuel resources generally used to heat the water.
Some prefer to use the term energy center because such facilities convert forms of heat
energy into electrical energy. Certain thermal power plants also are designed to produce heat
energy for industrial purposes of district heating, or desalination of water, in addition to
generating electrical power. Globally, fossil fueled thermal power plants produce a large part
of man-made CO2 emissions to the atmosphere, and efforts to reduce these are varied and
widespread.
Almost all coal, nuclear, geothermal, solar thermal electric, and waste incineration plants, as
well as many natural gas power plants are thermal. Natural gas is frequently combusted in gas
turbines as well as boilers. The waste heat from a gas turbine can be used to raise steam, in a
combined cycle plant that improves overall efficiency. Power plants burning coal, fuel oil, or
natural gas are often called fossil-fuel power plants. Some biomass-fueled thermal power
plants have appeared also. Non-nuclear thermal power plants, particularly fossil-fueled
plants, which do not use co-generation are sometimes referred to as conventional power
plants.
Commercial electric utility power stations are usually constructed on a large scale and
designed for continuous operation. Electric power plants typically use three-phase electrical
generators to produce alternating current (AC) electric power at a frequency of 50 Hz or 60
Hz. Large companies or institutions may have their own power plants to supply heating or
electricity to their facilities, especially if steam is created anyway for other purposes. Steam-
driven power plants have been used in various large ships, but are now usually used in large
naval ships. Shipboard power plants usually directly couple the turbine to the ship's
propellers through gearboxes. Power plants in such ships also provide steam to smaller
turbines driving electric generators to supply electricity. Shipboard steam power plants can be
either fossil fuel or nuclear. Nuclear marine propulsion is, with few exceptions, used only in
naval vessels. There have been perhaps about a dozen turbo-electric ships in which a steam-
driven turbine drives an electric generator which powers an electric motor for propulsion.
Combined heat and power plants (CH&P plants), often called co-generation plants, produce
both electric power and heat for process heat or space heating. Steam and hot water lose
energy when piped over substantial distance, so carrying heat energy by steam or hot water is
often only worthwhile within a local area, such as a ship, industrial plant, or district heating
of nearby buildings.

7. EFFICIENCY
A Rankine cycle with a two-stage steam turbine and a single feed water heater.
The energy efficiency of a conventional thermal power station, considered salable energy
produced as a percent of the heating value of the fuel consumed, is typically 33% to 48% As
with all heat engines, their efficiency is limited, and governed by the laws of
thermodynamics. By comparison, most hydropower stations in the United States are about 90
percent efficient in converting the energy of falling water into electricity.
The energy of a thermal not utilized in power production must leave the plant in the form of
heat to the environment. This waste heat can go through a condenser and be disposed of with
cooling water or in cooling towers. If the waste heat is instead utilized for district heating, it
is called co-generation. An important class of thermal power station are associated with
desalination facilities; these are typically found in desert countries with large supplies of
natural gas and in these plants, freshwater production and electricity are equally important co-
products.
The Carnot efficiency dictates that higher efficiencies can be attained by increasing the
temperature of the steam. Sub-critical fossil fuel power plants can achieve 36–40%
efficiency. Super critical designs have efficiencies in the low to mid 40% range, with new

8. "ultra critical" designs using pressures of 4400 psi (30.3 MPa) and multiple stage reheat
reaching about 48% efficiency. Above the critical point for water of 705 °F (374 °C) and
3212 psi (22.06 MPa), there is no phase transition from water to steam, but only a gradual
decrease in density.
Currently most of the nuclear power plants must operate below the temperatures and
pressures that coal-fired plants do, since the pressurized vessel is very large and contains the
entire bundle of nuclear fuel rods. The size of the reactor limits the pressure that can be
reached. This, in turn, limits their thermodynamic efficiency to 30–32%. Some advanced
reactor designs being studied, such as the very high temperature reactor, advanced gas-cooled
reactor and supercritical water reactor, would operate at temperatures and pressures similar to
current coal plants, producing comparable thermodynamic efficiency.
ELECTRICITY COST
The direct cost of electric energy produced by a thermal power station is the result of cost of
fuel, capital cost for the plant, operator labour, maintenance, and such factors as ash handling
and disposal. Indirect, social or environmental costs such as the economic value of
environmental impacts, or environmental and health effects of the complete fuel cycle and
plant decommissioning, are not usually assigned to generation costs for thermal stations in
utility practice, but may form part of an environmental impact assessment.
TYPICAL COAL THERMAL POWER STATION

9. Typical diagram of a coal-fired thermal power station
1. Cooling tower 10. Steam Control valve 19. Superheater
2. Cooling water pump
11. High pressure steam
turbine
20. Forced draught (draft)
fan
3. transmission line (3-phase) 12. Deaerator 21. Reheater
4. Step-up transformer (3-phase) 13. Feedwater heater 22. Combustion air intake
5. Electrical generator (3-phase) 14. Coal conveyor 23. Economiser
6. Low pressure steam turbine 15. Coal hopper 24. Air preheater
7. Condensate pump 16. Coal pulverizer 25. Precipitator
8. Surface condenser 17. Boiler steam drum
26. Induced draught (draft)
fan
9. Intermediate pressure steam
turbine
18. Bottom ash hopper 27. Flue gas stack
For units over about 200 MW capacity, redundancy of key components is provided by
installing duplicates of the forced and induced draft fans, air preheaters, and fly ash
collectors. On some units of about 60 MW, two boilers per unit may instead be provided.
BOILER AND STEAM CYCLE
In the nuclear plant field, steam generator refers to a specific type of large heat exchanger
used in a pressurized water reactor (PWR) to thermally connect the primary (reactor plant)
and secondary (steam plant) systems, which generates steam. In a nuclear reactor called a
boiling water reactor (BWR), water is boiled to generate steam directly in the reactor itself
and there are no units called steam generators.
In some industrial settings, there can also be steam-producing heat exchangers called heat
recovery steam generators (HRSG) which utilize heat from some industrial process. The
steam generating boiler has to produce steam at the high purity, pressure and temperature
required for the steam turbine that drives the electrical generator.
Geothermal plants need no boiler since they use naturally occurring steam sources. Heat
exchangers may be used where the geothermal steam is very corrosive or contains excessive
suspended solids.
A fossil fuel steam generator includes an economizer, a steam drum, and the furnace with its
steam generating tubes and superheater coils. Necessary safety valves are located at suitable
points to avoid excessive boiler pressure. The air and flue gas path equipment include: forced
draft (FD) fan, air preheater (AP), boiler furnace, induced draft (ID) fan, fly ash collectors
(electrostatic precipitator or baghouse) and the flue gas stack.

10. FEED WATER HEATING AND DEAERATION
The boiler feedwater used in the steam boiler is a means of transferring heat energy from the
burning fuel to the mechanical energy of the spinning steam turbine. The total feed water
consists of recirculated condensate water and purified makeup water. Because the metallic
materials it contacts are subject to corrosion at high temperatures and pressures, the makeup
water is highly purified before use. A system of water softeners and ion exchange
demineralizers produces water so pure that it coincidentally becomes an electrical insulator,
with conductivity in the range of 0.3–1.0 microsiemens per centimeter. The makeup water in
a 500 MWe plant amounts to perhaps 120 US gallons per minute (7.6 L/s) to replace water
drawn off from the boiler drums for water purity management, and to also offset the small
losses from steam leaks in the system.
The feed water cycle begins with condensate water being pumped out of the condenser after
traveling through the steam turbines. The condensate flow rate at full load in a 500 MW plant
is about 6,000 US gallons per minute (400 L/s).
Diagram of boiler feed water deaerator (with vertical, domed aeration section and horizontal
water storage section).
The water is pressurized in two stages, and flows through a series of six or seven intermediate
feed water heaters, heated up at each point with steam extracted from an appropriate duct on
the turbines and gaining temperature at each stage. Typically, in the middle of this series of
feedwater heaters, and before the second stage of pressurization, the condensate plus the
makeup water flows through a deaerator that removes dissolved air from the water, further
purifying and reducing its corrosiveness. The water may be dosed following this point with
hydrazine, a chemical that removes the remaining oxygen in the water to below 5 parts per
billion (ppb). It is also dosed with pH control agents such as ammonia or morpholine to keep
the residual acidity low and thus non-corrosive.

11. BOILER OPERATION
The boiler is a rectangular furnace about 50 feet (15 m) on a side and 130 feet (40 m) tall. Its
walls are made of a web of high pressure steel tubes about 2.3 inches (58 mm) in diameter.
Pulverized coal is air-blown into the furnace through burners located at the four corners, or
along one wall, or two opposite walls, and it is ignited to rapidly burn, forming a large
fireball at the center. The thermal radiation of the fireball heats the water that circulates
through the boiler tubes near the boiler perimeter. The water circulation rate in the boiler is
three to four times the throughput. As the water in the boiler circulates it absorbs heat and
changes into steam. It is separated from the water inside a drum at the top of the furnace. The
saturated steam is introduced into superheat pendant tubes that hang in the hottest part of the
combustion gases as they exit the furnace. Here the steam is superheated to 1,000 °F (540 °C)
to prepare it for the turbine.
Plants designed for lignite (brown coal) are increasingly used in locations as varied as
Germany, Victoria, Australia and North Dakota. Lignite is a much younger form of coal than
black coal. It has a lower energy density than black coal and requires a much larger furnace
for equivalent heat output. Such coals may contain up to 70% water and ash, yielding lower
furnace temperatures and requiring larger induced-draft fans. The firing systems also differ
from black coal and typically draw hot gas from the furnace-exit level and mix it with the
incoming coal in fan-type mills that inject the pulverized coal and hot gas mixture into the
boiler.
Plants that use gas turbines to heat the water for conversion into steam use boilers known as
heat recovery steam generators (HRSG). The exhaust heat from the gas turbines is used to
make superheated steam that is then used in a conventional water-steam generation cycle, as
described in gas turbine combined-cycle plants section below.
BOILER FURNACE AND STEAM DRUM
The water enters the boiler through a section in the convection pass called the economizer.
From the economizer it passes to the steam drum and from there it goes through downcomers
to inlet headers at the bottom of the water walls. From these headers the water rises through
the water walls of the furnace where some of it is turned into steam and the mixture of water
and steam then re-enters the steam drum. This process may be driven purely by natural
circulation (because the water is the denser than the water/steam mixture in the water walls)
or assisted by pumps. In the steam drum, the water is returned to the down comers and the
steam is passed through a series of steam separators and dryers that remove water droplets
from the steam. The dry steam then flows into the superheater coils.
The boiler furnace auxiliary equipment includes coal feed nozzles and igniter guns, soot
blowers, water lancing and observation ports (in the furnace walls) for observation of the
furnace interior. Furnace explosions due to any accumulation of combustible gases after a
trip-out are avoided by flushing out such gases from the combustion zone before igniting the
coal. The steam drum (as well as the super heater coils and headers) have air vents and drains
needed for initial start up.

12. SUPERHEATER
Fossil fuel power plants often have a superheater section in the steam generating furnace. The
steam passes through drying equipment inside the steam drum on to the superheater, a set of
tubes in the furnace. Here the steam picks up more energy from hot flue gases outside the
tubing and its temperature is now superheated above the saturation temperature. The
superheated steam is then piped through the main steam lines to the valves before the high
pressure turbine.
Nuclear-powered steam plants do not have such sections but produce steam at essentially
saturated conditions. Experimental nuclear plants were equipped with fossil-fired super
heaters in an attempt to improve overall plant operating cost.
STEAM CONDENSING
The condenser condenses the steam from the exhaust of the turbine into liquid to allow it to
be pumped. If the condenser can be made cooler, the pressure of the exhaust steam is reduced
and efficiency of the cycle increases.
Diagram of a typical water-cooled surface condenser.
The surface condenser is a shell and tube heat exchanger in which cooling water is circulated
through the tubes. The exhaust steam from the low pressure turbine enters the shell where it is
cooled and converted to condensate (water) by flowing over the tubes as shown in the adjacent
diagram. Such condensers use steam ejectors or rotary motor-driven exhausters for
continuous removal of air and gases from the steam side to maintain vacuum.
For best efficiency, the temperature in the condenser must be kept as low as practical in order
to achieve the lowest possible pressure in the condensing steam. Since the condenser
temperature can almost always be kept significantly below 100 °C where the vapor pressure
of water is much less than atmospheric pressure, the condenser generally works under
vacuum. Thus leaks of non-condensible air into the closed loop must be prevented.

13. Typically the cooling water causes the steam to condense at a temperature of about 35 °C
(95 °F) and that creates an absolute pressure in the condenser of about 2–7 kPa (0.59–
2.07 inHg), i.e. a vacuum of about −95 kPa (−28 inHg) relative to atmospheric pressure. The
large decrease in volume that occurs when water vapor condenses to liquid creates the low
vacuum that helps pull steam through and increase the efficiency of the turbines.
The limiting factor is the temperature of the cooling water and that, in turn, is limited by the
prevailing average climatic conditions at the power plant's location (it may be possible to
lower the temperature beyond the turbine limits during winter, causing excessive
condensation in the turbine). Plants operating in hot climates may have to reduce output if
their source of condenser cooling water becomes warmer; unfortunately this usually
coincides with periods of high electrical demand for air conditioning.
The condenser generally uses either circulating cooling water from a cooling tower to reject
waste heat to the atmosphere, or once-through water from a river, lake or ocean.
A Marley mechanical induced draft cooling tower
The heat absorbed by the circulating cooling water in the condenser tubes must also be
removed to maintain the ability of the water to cool as it circulates. This is done by pumping
the warm water from the condenser through either natural draft, forced draft or induced draft
cooling towers (as seen in the image to the right) that reduce the temperature of the water by
evaporation, by about 11 to 17 °C (20 to 30 °F)—expelling waste heat to the atmosphere. The
circulation flow rate of the cooling water in a 500 MW unit is about 14.2 m³/s (500 ft³/s or
225,000 US gal/min) at full load.
The condenser tubes are made of brass or stainless steel to resist corrosion from either side.
Nevertheless they may become internally fouled during operation by bacteria or algae in the
cooling water or by mineral scaling, all of which inhibit heat transfer and reduce
thermodynamic efficiency. Many plants include an automatic cleaning system that circulates
sponge rubber balls through the tubes to scrub them clean without the need to take the system
off-line.]
The cooling water used to condense the steam in the condenser returns to its source without
having been changed other than having been warmed. If the water returns to a local water
body (rather than a circulating cooling tower), it is tempered with cool 'raw' water to prevent
thermal shock when discharged into that body of water.
Another form of condensing system is the air-cooled condenser. The process is similar to that
of a radiator and fan. Exhaust heat from the low pressure section of a steam turbine runs
through the condensing tubes, the tubes are usually finned and ambient air is pushed through

14. the fins with the help of a large fan. The steam condenses to water to be reused in the water-
steam cycle. Air-cooled condensers typically operate at a higher temperature than water-
cooled versions. While saving water, the efficiency of the cycle is reduced (resulting in more
carbon dioxide per megawatt of electricity).
From the bottom of the condenser, powerful condensate pumps recycle the condensed steam
(water) back to the water/steam cycle.
REHEATER
Power plant furnaces may have a reheater section containing tubes heated by hot flue gases
outside the tubes. Exhaust steam from the high pressure turbine is passed through these
heated tubes to collect more energy before driving the intermediate and then low pressure
turbines.
AIR PATH
External fans are provided to give sufficient air for combustion. The Primary air fan takes air
from the atmosphere and, first warming it in the air preheater for better combustion, injects it
via the air nozzles on the furnace wall.
The induced draft fan assists the FD fan by drawing out combustible gases from the furnace,
maintaining a slightly negative pressure in the furnace to avoid backfiring through any
closing.
STEAM TURBINE GENERATOR

15. The turbine generator consists of a series of steam turbines interconnected to each other and a
generator on a common shaft. There is a high pressure turbine at one end, followed by an
intermediate pressure turbine, two low pressure turbines, and the generator. As steam moves
through the system and loses pressure and thermal energy it expands in volume, requiring
increasing diameter and longer blades at each succeeding stage to extract the remaining
energy. The entire rotating mass may be over 200 metric tons and 100 feet (30 m) long. It is
so heavy that it must be kept turning slowly even when shut down (at 3 rpm) so that the shaft
will not bow even slightly and become unbalanced. This is so important that it is one of only
five functions of blackout emergency power batteries on site. Other functions are emergency
lighting, communication, station alarms and turbogenerator lube oil.
Superheated steam from the boiler is delivered through 14–16-inch (360–410 mm) diameter
piping to the high pressure turbine where it falls in pressure to 600 psi (4.1 MPa) and to
600 °F (320 °C) in temperature through the stage. It exits via 24–26-inch (610–660 mm)
diameter cold reheat lines and passes back into the boiler where the steam is reheated in
special reheat pendant tubes back to 1,000 °F (540 °C). The hot reheat steam is conducted to
the intermediate pressure turbine where it falls in both temperature and pressure and exits
directly to the long-bladed low pressure turbines and finally exits to the condenser.
The generator, 30 feet (9 m) long and 12 feet (3.7 m) in diameter, contains a stationary stator
and a spinning rotor, each containing miles of heavy copper conductor—no permanent
magnets here. In operation it generates up to 21,000 amperes at 24,000 volts AC (504 MWe)
as it spins at either 3,000 or 3,600 rpm, synchronized to the power grid. The rotor spins in a
sealed chamber cooled with hydrogen gas, selected because it has the highest known heat
transfer coefficient of any gas and for its low viscosity which reduces windage losses. This
system requires special handling during startup, with air in the chamber first displaced by
carbon dioxide before filling with hydrogen. This ensures that the highly explosive
hydrogen–oxygen environment is not created.
The power grid frequency is 60 Hz across North America and 50 Hz in Europe, Oceania,
Asia (Korea and parts of Japan are notable exceptions) and parts of Africa. The desired
frequency affects the design of large turbines, since they are highly optimized for one
particular speed.
The electricity flows to a distribution yard where transformers increase the voltage for
transmission to its destination.
The steam turbine-driven generators have auxiliary systems enabling them to work
satisfactorily and safely. The steam turbine generator being rotating equipment generally has
a heavy, large diameter shaft. The shaft therefore requires not only supports but also has to be
kept in position while running. To minimize the frictional resistance to the rotation, the shaft
has a number of bearings. The bearing shells, in which the shaft rotates, are lined with a low
friction material like Babbitt metal. Oil lubrication is provided to further reduce the friction
between shaft and bearing surface and to limit the heat generated.
STACK GAS PATH AND CLEANUP
As the combustion flue gas exits the boiler it is routed through a rotating flat basket of metal
mesh which picks up heat and returns it to incoming fresh air as the basket rotates, This is

16. called the air preheater. The gas exiting the boiler is laden with fly ash, which are tiny
spherical ash particles. The flue gas contains nitrogen along with combustion products carbon
dioxide, sulfur dioxide, and nitrogen oxides. The fly ash is removed by fabric bag filters or
electrostatic precipitators. Once removed, the fly ash byproduct can sometimes be used in the
manufacturing of concrete. This cleaning up of flue gases, however, only occurs in plants that
are fitted with the appropriate technology. Still, the majority of coal-fired power plants in the
world do not have these facilities. Legislation in Europe has been efficient to reduce flue gas
pollution. Japan has been using flue gas cleaning technology for over 30 years and the US has
been doing the same for over 25 years. China is now beginning to grapple with the pollution
caused by coal-fired power plants.
Where required by law, the sulfur and nitrogen oxide pollutants are removed by stack gas
scrubbers which use a pulverized limestone or other alkaline wet slurry to remove those
pollutants from the exit stack gas. Other devices use catalysts to remove Nitrous Oxide
compounds from the flue gas stream. The gas travelling up the flue gas stack may by this
time have dropped to about 50 °C (120 °F). A typical flue gas stack may be 150–180 metres
(490–590 ft) tall to disperse the remaining flue gas components in the atmosphere. The tallest
flue gas stack in the world is 419.7 metres (1,377 ft) tall at the GRES-2 power plant in
Ekibastuz, Kazakhstan.
In the United States and a number of other countries, atmospheric dispersion modeling
studies are required to determine the flue gas stack height needed to comply with the local air
pollution regulations. The United States also requires the height of a flue gas stack to comply
with what is known as the "Good Engineering Practice (GEP)" stack height. In the case of
existing flue gas stacks that exceed the GEP stack height, any air pollution dispersion
modeling studies for such stacks must use the GEP stack height rather than the actual stack
height.
FLY ASH COLLECTION
Fly ash is captured and removed from the flue gas by electrostatic precipitators or fabric bag
filters (or sometimes both) located at the outlet of the furnace and before the induced draft
fan. The fly ash is periodically removed from the collection hoppers below the precipitators
or bag filters. Generally, the fly ash is pneumatically transported to storage silos for
subsequent transport by trucks or railroad cars .
BOTTOM ASH COLLECTION AND DISPOSAL
At the bottom of the furnace, there is a hopper for collection of bottom ash. This hopper is
always filled with water to quench the ash and clinkers falling down from the furnace. Some
arrangement is included to crush the clinkers and for conveying the crushed clinkers and
bottom ash to a storage site. Ash extractor is used to discharge ash from Municipal solid
waste–fired boilers.

17. AUXILIARY SYSTEMS
BOILER MAKE-UP WATER TREATMENT PLANT AND
STORAGE
Since there is continuous withdrawal of steam and continuous return of condensate to the
boiler, losses due to blowdown and leakages have to be made up to maintain a desired water
level in the boiler steam drum. For this, continuous make-up water is added to the boiler
water system. Impurities in the raw water input to the plant generally consist of calcium and
magnesium salts which impart hardness to the water. Hardness in the make-up water to the
boiler will form deposits on the tube water surfaces which will lead to overheating and failure
of the tubes. Thus, the salts have to be removed from the water, and that is done by a water
demineralising treatment plant (DM). A DM plant generally consists of cation, anion, and
mixed bed exchangers. Any ions in the final water from this process consist essentially of
hydrogen ions and hydroxide ions, which recombine to form pure water. Very pure DM water
becomes highly corrosive once it absorbs oxygen from the atmosphere because of its very
high affinity for oxygen.
The capacity of the DM plant is dictated by the type and quantity of salts in the raw water
input. However, some storage is essential as the DM plant may be down for maintenance. For
this purpose, a storage tank is installed from which DM water is continuously withdrawn for
boiler make-up. The storage tank for DM water is made from materials not affected by
corrosive water, such as PVC. The piping and valves are generally of stainless steel.
Sometimes, a steam blanketing arrangement or stainless steel doughnut float is provided on
top of the water in the tank to avoid contact with air. DM water make-up is generally added at
the steam space of the surface condenser (i.e., the vacuum side). This arrangement not only
sprays the water but also DM water gets deaerated, with the dissolved gases being removed
by a de-aerator through an ejector attached to the condenser.
FUEL PREPARATION SYSTEM
In coal-fired power stations, the raw feed coal from the coal storage area is first crushed into
small pieces and then conveyed to the coal feed hoppers at the boilers. The coal is next
pulverized into a very fine powder. The pulverizers may be ball mills, rotating drum grinders,
or other types of grinders.

18. Some power stations burn fuel oil rather than coal. The oil must kept warm (above its pour
point) in the fuel oil storage tanks to prevent the oil from congealing and becoming
unpumpable. The oil is usually heated to about 100 °C before being pumped through the
furnace fuel oil spray nozzles.
Boilers in some power stations use processed natural gas as their main fuel. Other power
stations may use processed natural gas as auxiliary fuel in the event that their main fuel
supply (coal or oil) is interrupted. In such cases, separate gas burners are provided on the
boiler furnaces.
BARRING GEAR
Barring gear (or "turning gear") is the mechanism provided to rotate the turbine generator
shaft at a very low speed after unit stoppages. Once the unit is "tripped" (i.e., the steam inlet
valve is closed), the turbine coasts down towards standstill. When it stops completely, there is
a tendency for the turbine shaft to deflect or bend if allowed to remain in one position too
long. This is because the heat inside the turbine casing tends to concentrate in the top half of
the casing, making the top half portion of the shaft hotter than the bottom half. The shaft
therefore could warp or bend by millionths of inches.
This small shaft deflection, only detectable by eccentricity meters, would be enough to cause
damaging vibrations to the entire steam turbine generator unit when it is restarted. The shaft
is therefore automatically turned at low speed (about one percent rated speed) by the barring
gear until it has cooled sufficiently to permit a complete stop.
OIL SYSTEM
An auxiliary oil system pump is used to supply oil at the start-up of the steam turbine
generator. It supplies the hydraulic oil system required for steam turbine's main inlet steam
stop valve, the governing control valves, the bearing and seal oil systems, the relevant
hydraulic relays and other mechanisms.
At a preset speed of the turbine during start-ups, a pump driven by the turbine main shaft
takes over the functions of the auxiliary system.
GENERATOR COOLING
While small generators may be cooled by air drawn through filters at the inlet, larger units
generally require special cooling arrangements. Hydrogen gas cooling, in an oil-sealed
casing, is used because it has the highest known heat transfer coefficient of any gas and for its
low viscosity which reduces windage losses. This system requires special handling during
start-up, with air in the generator enclosure first displaced by carbon dioxide before filling
with hydrogen. This ensures that the highly flammable hydrogen does not mix with oxygen in
the air.
The hydrogen pressure inside the casing is maintained slightly higher than atmospheric
pressure to avoid outside air ingress. The hydrogen must be sealed against outward leakage

19. where the shaft emerges from the casing. Seal oil is used to prevent the hydrogen gas leakage
to atmosphere.
The generator also uses water cooling. Since the generator coils are at a potential of about 22
kV, an insulating barrier such as Teflon is used to interconnect the water line and the
generator high-voltage windings. Demineralized water of low conductivity is used.
GENERATOR HIGH-VOLTAGE SYSTEM
The generator voltage for modern utility-connected generators ranges from 11 kV in smaller
units to 22 kV in larger units. The generator high-voltage leads are normally large aluminium
channels because of their high current as compared to the cables used in smaller machines.
They are enclosed in well-grounded aluminium bus ducts and are supported on suitable
insulators. The generator high-voltage leads are connected to step-up transformers for
connecting to a high-voltage electrical substation (usually in the range of 115 kV to 765 kV)
for further transmission by the local power grid.
The necessary protection and metering devices are included for the high-voltage leads. Thus,
the steam turbine generator and the transformer form one unit. Smaller units may share a
common generator step-up transformer with individual circuit breakers to connect the
generators to a common bus.
MONITORING AND ALARM SYSTEM
Most of the power plant operational controls are automatic. However, at times, manual
intervention may be required. Thus, the plant is provided with monitors and alarm systems
that alert the plant operators when certain operating parameters are seriously deviating from
their normal range.
BATTERY-SUPPLIED EMERGENCY LIGHTING AND
COMMUNICATION
A central battery system consisting of lead acid cell units is provided to supply emergency
electric power, when needed, to essential items such as the power plant's control systems,
communication systems, turbine lube oil pumps, and emergency lighting. This is essential for
a safe, damage-free shutdown of the units in an emergency situation.
TRANSPORT OF COAL FUEL TO SITE AND TO STORAGE
Main article: Fossil fuel power plant
Most thermal stations use coal as the main fuel. Raw coal is transported from coal mines to a
power station site by trucks, barges, bulk cargo ships or railway cars. Generally, when
shipped by railways, the coal cars are sent as a full train of cars. The coal received at site may
be of different sizes. The railway cars are unloaded at site by rotary dumpers or side tilt

20. dumpers to tip over onto conveyor belts below. The coal is generally conveyed to crushers
which crush the coal to about 3
⁄4 inch (19 mm) size. The crushed coal is then sent by belt
conveyors to a storage pile. Normally, the crushed coal is compacted by bulldozers, as
compacting of highly volatile coal avoids spontaneous ignition.
The crushed coal is conveyed from the storage pile to silos or hoppers at the boilers by
another belt conveyor system.
LOCATION OF POWER PLANTS IN INDIA
Thermal power is the "largest" source of power in India. There are different types of Thermal
power plants based on the fuel used to generate the steam such as coal, gas, Diesel etc. About
75% of electricity consumed in India are generated by thermal power plants.
More than 51% of India's commercial energy demand is met through the country's vast coal
reserves. Public sector undertaking NTPC and several other state level power generating
companies are engaged in operating coal based Thermal Power Plants. Apart from NTPC and
other state level operators, some private companies are also operating the power plants. Here
is some list of currently operating coal based thermal power plants in India. As on July 31,
2010, and as per the Central Electricity Authority the total installed capacity of Coal or
Nuclear power is the fourth-largest source of electricity in India after thermal, hydro and
wind power. As of 2010, India had 19 nuclear power reactors in operation generating 4,560
MW while 4 other are under construction and are expected to generate an additional 2,720
MW.
Nineteen nuclear power reactors operated at six sites by the Nuclear Power Corporation of
India produce 4,560.00 MW, 2.9% of total installed base.

21. Power station
Opera
tor
Locat
ion
District State Region
Reactor
(MW)units
Installe
d
capacity
(MW)
Narora Atomic
PowerStation
NPCI
L
Naror
a
Buland
shahr
Uttar
Pradesh
Norther
n
220 x 2 440
Rajasthan
AtomicPowerSta
tion
NPCI
L
Rawa
tbhata
Chittor
garh
Rajasthan
Norther
n
(100 x 1,
200 x 1,
220 x 4)
1180
Tarapur
AtomicPowerSta
tion
NPCI
L
Tarap
ur
Thane
Maharasht
ra
Western
160 x 2,
540 x 2
1,400
Kakrapar
Atomic Power
Station
NPCI
L
Kakra
par
Surat Gujarat Western 220 x 2 440
Kudankulam
Nuclear Power
Plant
NPCI
L
Kuda
nkula
m
Tirunel
veli
Tamilnadu
Souther
n
1000 x 2 -
Madras Atomic
Power Station
BHAV
INI
Kalpa
kkam
Kanche
epuram
Tamilnadu
Souther
n
500 x 1 -
Kaiga Nuclear
Power Plant
NPCI
L
Kaiga
Uttara
Kannad
a
Karnataka
Souther
n
220 x 4 660
Madras Atomic
Power Station
NPCI
L
Kalpa
kkam
Kanche
epuram
Tamil
Nadu
Souther
n
220 x 2 440
Total 6 19 4,560
Thermal Power
Thermal power is the largest source of power in India.There are different types of Thermal
power plants based on the fuel used to generate the steam such as coal, gas, Diesel etc. About
75% of electricity consumed in india are generated by Thermal power plants.

22. Coal or Lignite Based
More than 50% of india’s commercial energy demand is met through the country’s vast coal
reserves. Public sector undertaking National Thermal Power Corporation and several other
state level power generating companies are engaged in operating coal based Thermal Power
Plants.Apart from NTPC and other state level operators, some private companies are also
operating the power plants. Here is some list of currently operating Coal based Thermal
power plants in India. As on July 31, 2010, and as per the Central Electricity Authority the
total installed capacity of Coal or Lignite based power plants in india are 87093.38 MW.
Power
station
Operator Location District State
Re
gio
n
Unit
wise
Capacit
y
Installed
Capacit
y
(MW)
Rajghat
Power
Station
IPGCL Delhi Delhi NCT Delhi
Nor
ther
n
2 x 67.5 135.00
Deenba
ndhu
Chhotu
Ram
Thermal
Power
Station
HPGCL
Yamunan
agar
Yamunana
gar
Haryana
Nor
ther
n
2 x 300 600.00
Panipat
Thermal
Power
Station I
HPGCL Assan Panipat Haryana
Nor
ther
n
4 x 110 440.00
Panipat
Thermal
Power
Station
HPGCL Assan Panipat Haryana
Nor
ther
n
2 x 210,
2 x 250
920.00

23. II
Faridab
ad
Thermal
Power
Station
HPGCL Faridabad Faridabad Haryana
Nor
ther
n
1 x 55 55.00
Rajiv
Gandhi
Thermal
Power
Station
HPGCL Khedar Hisar Haryana
Nor
ther
n
1 x 600 600.00
Guru
Nanak
dev TP
PSPCL Bathinda Bathinda Punjab
Nor
ther
n
4 x 110 440.00
Guru
Hargobi
nd TP
PSPCL
Lehra
Mohabbat
Bathinda Punjab
Nor
ther
n
2 x 210,
2 x 250
920.00
Guru
Gobind
Singh
Super
Thermal
Power
Plant
PSPCL Ghanauli Rupnagar Punjab
Nor
ther
n
6 x 210 1260.00
Suratgar
h Super
Thermal
Power
Plant
RVUNL Suratgarh
Sri
Ganganag
ar
Rajasthan
Nor
ther
n
6 x 250 1500.00
Kota
Super
Thermal
Power
Plant
RVUNL Kota Kota
Rajastha
n
Nor
ther
n
2 x 110, 3 x
210, 2 x 195
1240.00
Giral
Lignite
Power
Plant
RVUNL Thumbli Barmer
Rajastha
n
Nor
ther
n
2 x 125 250.00

24. Chhabra
Therma
Power
lant
RVUNL
Mothipur
a
Baran
Rajastha
n
Nor
ther
n
2 x 250 500.00
Orba
Thermal
Power
Station
UPRVUN
L
Obra Sonebhadra
Uttar
Pradesh
Nor
ther
n
X40,
3 x 94, 5 x 200 1,322.00
Anpara
Thermal
UPRVUN
L
Anpara Sonebhadra
Uttar
Pradesh
Nor
ther
n
3 x 210, 2 x
500
1630.00
Panki
Thermal
Power
Station
UPRVUN
L
Panki Kanpur
Uttar
Pradesh
Northern 2 x 105 210.00
Parichh
a
Thermal
Power
Station
UPRVUN
L
Parichha Jhansi
Uttar
Pradesh
Northern
2 x 110,
2 x 210
640.00
Hardua
ganj
Thermal
Power
Station
UPRVUN
L
Harduaga
nj
Aligarh
Uttar
Pradesh
Northern
1 x 55, 1
x 60, 1 x
105
220.00
Badarpu
r
Thermal
power
plant
NTPC Badarpur New Delhi
NCT
Delhi
Northern
3 x 95, 2
x 210
705.00
Singrauli
Super
Thermal
Power
Station
NTPC
Shaktinag
ar
Sonebhadra
Uttar
Pradesh
Northern
5 x 200,
2 x 500
2000.00
Barsingsar Lignite Power Plant NLC Barsingsar Bikaner Rajasthan Northern 1 x 125 125.00

25. Rihand
Thermal
Power
Station
NTPC
Rihand
Nagar
Sonebhadra
Uttar
Pradesh
Northern 4 x 500 2000.00
Nationa
l
Capital
Thermal
Power
Plant
NTPC
Vidyutna
gar
Gautam
Budh Nagar
Uttar
Pradesh
Northern
4 x 210,
2 x 490
1820.00
Feroj
Gandhi
Unchah
ar
Thermal
NTPC Unchahar Raebareli
Uttar
Pradesh
Northern
5 x 210 1050.00
Tanda
Thermal
Power
Plant
NTPC
Vidyutna
gar
Ambedkar
Nagar
Uttar
Pradesh
Northern 4 x 110 440.00
Raj
west
Lignite
Power
Plant
JSW Barmer Barmer Rajasthan Northern 1 x 135 135.00
VS
Lignite
Power
Plant
KSK Gurha Bikaner Rajasthan Northern 1 x 125 125.00
Rosa
Thermal
Power
Plant
Stage I
Reliance Rosa
Shahjahanpu
r
Uttar
Pradesh
Northern 2 x 300 600.00

26. Northern
Ukai
Thermal
Power
Station
GSECL Ukai dam Tapi Gujarat Western
200, 1
x 210
850
Gandhin
agar
Thermal
Power
Station
GSECL
Gandhinaga
r
Gandhinag
ar
Gujarat Western
2 x
120, 3
x 210
870
Wanakb
ori
Thermal
Power
Station
GSECL Wanakbori Kheda Gujarat Western 7 x 210 1470
Sikka
Thermal
Power
Station
GSECL Jamnagar Jamnagar Gujarat Western 2 x 120 240
Dhuvara
n
Thermal
Power
Station
GSECL Khambhat Anand Gujarat Western 2 x 110 220
Kutch
Thermal
Power
Station
GSECL Panandhro Kutch Gujarat Western
2 x 70,
2 x 75
290
Surat
Thermal
Power
Station
GIPCL Nani Naroli Surat Gujarat Western 4 x 125 500
Akrimot
a
Thermal
Power
Station
GMDC Chher Nani Kutch Gujarat Western 2 x 125 250

27. Satpura
Thermal
Power
Station
MPPGCL Sarni Betul
Madhya
Pradesh
Western
5 x
37.5, 1
x 200,
3 x 210
1017.5
Sanjay
Gandhi
Thermal
Power
Station
MPPGCL Birsinghpur Umaria
Madhya
Pradesh
Western
4 x
210, 1
x 500
1340
Amarka
ntak
Thermal
Power
Station
MPPGCL Chachai Anuppur
Madhya
Pradesh
Western
2 x
120, 1
x 210
450
Korba
East
Thermal
Power
Plant
CSPGCL Korba
Chattisg
arh
Western
4 x 50,
2 x 120
440
Dr
Shyama
Prasad
Mukharj
ee
Thermal
Power
Plant
CSPGCL Korba
Chattisg
arh
Western 2 x 250 500
Korba
West
Hasdeo
Thermal
Power
Plant
CSPGCL Korba
Chattisg
arh
Western 4 x 210 840
Koradi
Thermal
Power
Station
MAHAG
ENCO
Koradi Nagpur
Maharas
tra
Western
4 x
105, 1
x 200,
2 x 210
1040

28. Nashik
Thermal
Power
Station
MAHAG
ENCO
Nashik Nashik
Maharas
tra
Western
2 x
125, 3
x 210
880
Bhusaw
al
Thermal
Power
Station
MAHAG
ENCO
Deepnagar Jalgaon
Maharas
tra
Western
1 x 50,
2 x 210
470
Paras
Thermal
Power
Station
MAHAG
ENCO
Vidyutnagar Akola
Maharas
tra
Western
1 x 55,
2 x 250
555
Parli
Thermal
Power
Station
MAHAG
ENCO
Parli-
Vaijnath
Beed
Maharas
tra
Western
2 x 20,
3 x
210, 2
x 250
1170
Kaparkh
eda
Thermal
Power
Station
MAHAG
ENCO
Kaparkheda Nagpur
Maharas
tra
Western 4 x 210 840
Chandra
pur
Super
Thermal
Power
Station
MAHAG
ENCO
Chandrapur Chandrapur
Maharas
tra
Western
4 x
210, 3
x 500
2340
Vindhya
chal
Super
Thermal
Power
Station
NTPC
Vidhya
Nagar
Sidhi
Madhya
Pradesh
Western
6 x
210, 4
x 500
3260
Korba
Super
Thermal
Power
NTPC Jamani Palli Korba
Chattisg
arh
Western
3 x
200, 3
x 500
2100

29. Plant
Sipat
Thermal
Power
Plant
NTPC Sipat Bilaspur
Chattisg
arh
Western 2 x 500 1000
Bhilai
Expansi
on
Power
Plant
NTPC-
SAIL(JV)
Bhilai Durg
Chattisg
arh
Western 2 x 250 500
Sabarma
ti
Thermal
Power
Station
Torrent
Ahamadaba
d
Gujarat Western
1 x 60,
1 x
120, 2
x 110
400
Mundra
Thermal
Power
Station
Adani Mundra Kutch Gujarat Western 2 x 330 660
Jindal
Megha
Power
Plant
jindal Tamnar Raigarh
Chattisg
arh
Western 4 x 250 1000
Lanco
Amarka
ntak
Power
Plant
Lanco Pathadi Korba
Chattisg
arh
Western 2 x 300 600
Tromba
y
Thermal
Power
Station
Tata Trombay Mumbai
Maharas
tra
Western
1 x
150, 2
x 500,
1 x 250
1400
Dahanu
Thermal
Power
Station
Reliance Dahanu Thane
Maharas
tra
Western 2 x 250 500

30. Wardha
Warora
Power
Station
KSK Warora Chandrapur
Maharas
tra
Western 1 x 135 135
Gas or Liquid Fuel Based
As on July 31, 2010, and as per the Central Electricity Authority the total installed capacity of
Gas based power plants in india is 17,353.85 MW. This accounts for 10% of the total
installed capacity.GAIL is the main source of fuel for most of these plants. Here is some list
of presently operating plants.
Power
station
Operator Location District State Sector Unit
wise
Capacity
Install
ed
Capac
ity
(MW)
IPGCL
Gas
Turbine
Power
Station
IPGCL New Delhi NCT Delhi State 9 x 30 270.00
Pragati
Gas
Power
Station
PPCL New Delhi NCT Delhi State 2 x
104.6, 1
x 121.2
330.40
Pampore
Gas
Turbine
Station I
J&K Govt Pampore Pulwama Jammu &
Kashmir
State 3 x 25 75.00
Pampore
Gas
Turbine
Station II
J&K Govt Pampore Pulwama Jammu &
Kashmir
State 4 x 25 100.00
Ramgarh
Gas
Thermal
Power
RVUNL Ramgarh Rajasthan State 1 x 3, 1 x
35.5, 1 x
37.5, 1 x
37.8
113.80

31. Station
Dholpur
Combined
Cycle
Power
Station
RVUNL Purani
Chaoni
Dholpur Rajasthan State 3 x 110 330.00
Anta
Thermal
Power
Station
NTPC Anta Baran Rajasthan Central 3 x 88, 1
x 149
413.00
Auraiya
Thermal
Power
Station
NTPC Dibiyapu
r
Auraiya Uttar
Pradesh
Central 4 x 110,
2 x 106
652.00
Faridabad
Thermal
Power
Plant
NTPC Mujedi Faridabad Haryana Central 2 x 143,
1 x 144
430.00
National
Capital
TPP
NTPC Vidyutna
gar
Gautam
Budh Nagar
Uttar
Pradesh
Central 4 x 131,
2 x 146.5
817.00
Northern
Dhuvaran
Gas
Based
CCPP-I
GSECL Khambha
t
Anand Gujarat State 1 x
67.85, 1
x 38.77
106.62
Dhuvaran
Gas
Based
CCPP-II
GSECL Khambha
t
Anand Gujarat State 1 x
72.51, 1
x 39.94
112.45
Utran Gas
Based
CCPP
GSECL Utran Surat Gujarat State 3 x 30, 1
x 45, 1 x
228
363.00
Vadodara GIPCL Vadodara Vadodara Gujarat State 3 x 32, 1 145.00

32. Gas
Based
CCPP-I
x 49
Vadodara
Gas
Based
CCPP-II
GIPCL Vadodara Vadodara Gujarat State 1 x 111,
1 x 54
165.00
Uran Gas
Turbine
Power
Station
Mahagenco Bokadvir
a
Raigarh Maharastra State 4 x 60, 4
x 108, 2
x 120
912.00
Kawas
TPS
NTPC Adityana
gar
Surat Gujarat Central 4 x 106,
2 x 110.5
645.00
Jhanor-
Gandhar
TPS
NTPC Urjanaga
r
Bharuch Gujarat Central 3 x 131,
1 x 255
648.00
Goa Gas
Power
Station
RSPCL Zuarinag
ar
Goa Goa Private 1 x 32, 1
x 16
48.00
Vatva
Combined
Cycle
Power
Plant
Torrent Vatva Ahamadabad Gujarat Private 2 x 32.5,
1 x 35
100.00
SUGEN
Combined
Cycle
Power
Plant
Torrent Akhakho
l
Surat Gujarat Private 3 x 382.5 1147.5
0
Essar
Combined
Cycle
Power
Plant
Essar Hazira Surat Gujarat Private 3 x 110,
1 x 185
515.00
GSEG
Combined
Cycle
GSEG Hazira Surat Gujarat Private 3 x 52 156.00

33. Power
Plant
GPEC
Combined
Cycle
Power
Plant
GPEC Paguthan Bharuch Gujarat Private 3 x 135,
1 x 250
655.00
Trombay
Gas
Power
Station
Tata Trombay Mumbai Maharastra Private 1 x 120,
1 x 60
180.00
Diesel Based
As on July 31, 2010, and as per the Central Electricity Authority the total installed capacity of
Diesel based power plants in india is 1,199.75 MW.[4]
. Normally the diesel based power
plants are either operated from remote locations or operated to cater peak load demands. Here
is some list of presently operating plants.
Power
station
Operator Location State Reactor
(MW)units
Installed
Capacity
(MW)
Under
construction
(MW)
Ambala
Diesel Power
Station
Haryana
Govt
Haryana Northern 1 x 2.18,
1 x 0.34,
1 x .4, 1
x 1
3.92
Keylong
Diesel Power
Station
HP Govt Himachal
Pradesh
Northern 1 x 0.13 0.13
Bemina
Diesel Power
Station
J&K
Govt
Jammu &
Kashmir
Northern 1 x 5 5.00
Kamah Diesel
Power Station
J&K
Govt
Jammu &
Kashmir
Northern 1 x 0.06 0.06
Leh Diesel J&K Jammu & Northern 1 x 2.18 2.18

34. Power Station Govt Kashmir
Upper Sindh
Diesel Power
Station
J&K
Govt
Jammu &
Kashmir
Northern 1 x 1.7 1.70
Northern 6 8 12.99
Yelahanka
Diesel Power
Station
KPCL Yelahanka Karnataka Southern 6 x 21.32 127.92
Brahmapuram
Diesel Power
Station
KSEB Brahmapuram Kerala Southern 5 x 21.32 106.60
Kozhikode
Diesel Power
Station
KSEB Kozhikode Kerala Southern 8 x 16.00 128.00
Southern 3 19 362.52
Gangtok
Diesel Power
Station
Sikkim
Govt
Gangtok Sikkim Eastern 4.00
Ranipool
Diesel Power
Station
Sikkim
Govt
Ranipool Sikkim Southern 1.00
Eastern 2 5.00
Suryachakra
Diesel Power
Station
SPCL A & N Andaman
&
Nicobar
Islands 20
Islands 1 20.00
Total 12 27 400.51

35. POWER PLANTS IN RAJASTHAN
1 KOTA THERMAL POWER PLANT
kota Super Thermal Power Station is the first coal based Electricity Generating Power Plant
in Rajasthan. At present the total installed capacity of KSTPS is 1240MW.
Kota Super Thermal Power Station is located on the left bank of river Chambal in
Rajasthan’s principal industrial city Kota. Infrastructural facilities like adequate water
availability in Kota Barrage throughout the year.
SANCTION OF SCHEMES (STAGE-I to V)
Kota Super Thermal Power Station is located on the left bank of river Chambal in
Rajasthan’s principal industrial city Kota. Infrastructural facilities like adequate water
availability in Kota Barrage throughout the year.
Stage Unit No. Capacity(MW) Synchronising Date Cost(Rs.Crore)
I 1 110 17.1.1983 143
2 110 13.7.1983
II 3 210 25.9.1988 480
4 210 1.5.1989
III 5 210 26.3.1994 480
IV 6 195 31.7.2003 635
V 7 195 30.5 2009 880

36. (1) Location KOTA(RAJASTHAN)
(2) Installed Capacity 1240MW
(3) Land Details
(a) Plant Area 204 Hectare
(b) Ash Dump Area 423 Hectare
(4) Cooling Water
(a)
Source Of Cooling
Water
Kota Barrage (Chambal River)
(b)
Method Of
Cooling:
i) Unit # 1 to 5 Once through Cooling System(Open Cycle)-1180 Cusecs
i) Unit # 6 to 7
Re-circulating through Cooling Tower - 18 Cusecs (Including
Consumptive use)
(5) Coal
(a) Type Bituminous Coal
(b) Linked Coal Mines SECL (Korea-Rewa & Korba) & NCL (Singrauli)
(c)
Average Ash
Content
28-32%
(6) Fuel Oil
(a) Type Furnace Oil / HSD
(b)
Available Storage
Capacity
HSD - 3100 KL & FO - 18600 KL

37. (7) Steam Generator M/s. BHEL make
(8) Turbo Generator M/s. BHEL make
(9)
Coal Handling
Plant
(a)
Stock Yard
Capacity
5,00,000 MT
(b) Wagon Tipplers 5 Nos.
(c) Coal Crushers 10 Nos
(d) Conveyor System 1.595 Kms
(10)
Transmission
Lines
Power evacuation through 9 Nos. 220 KV outgoing feeders.
Further 2 Nos. of new 220 KV feeders are under construction
RECORDS OF EXCELLENCE :
Kota Super Thermal Power Station is reckoned as one of the best, efficient and prestigious
power station of the country. KSTPS has established a record of excellence and has earned
meritorious productivity awards from the Ministry of Power, Govt. of India during 1984,
1987, 1989, 1991 and every year since 1992-93 onwards.
KSTPS has earned golden shield award from Union Ministry of Power for Consistent
outstanding performance during 2000-01 to 2003-04. The Golden Shield was presented by
Hon’ble President of India Dr. A.P.J. Abdul Kalam on 24.8.04.
KSTPS has achieved the distinction of about 100% fly ash utilization during the year 2010-
11. An all time high generation level of 9891 MU at an annual PLF of 91.06% was achieved
during 2010-11. The achievements made by KTPS during 2010-11 are as under:-
record achievements : 2010-11
total station generation _ 9891 mu(highest since commissioning)
plant load factor _ 91.06 %
station availability _ 94.23 %
no. of forced outages _ 6 nos.(lowest since commissioning)

38. sp. oil consumption _ 0.24 ml/kwh(lowest since commissioning)
sp. oil consumption _ 0.76 ml/kwh(lowest since commissioning)
dry fly ash utilisation _ 99.40%(highest since commissioning)
boiler tube leakage unit _ nil (during yr. 2010-11)
continuous run 210 mw unit # 4 _ 100 days (dt. 16.02.10 to 26.05.10)
station generation (in a day) _ 30.895 mu(highest in a day on 13.03.11)
Special Achievements current year 2010-11
Continuous
run
Capicity From To
No. of
Hrs
No of
days
Unit-2 110MW
13.18 hrs
dt26.01.11
01:58 hrs
dt.09.6.11
3205 134
Unit-6 195MW 17:05 hrs dt30.1.11
03:19 hrs
dt18.05.11
2578 107
Unit-4 210MW
07:18 hrs dt
17.2.11
Contd. 2849 119(+)
Further, it is worthwhile to mention that KTPS managed efficient unloading of coal rakes
within the duration as prescribed by the Railways and there by achieved unloading of about
155 coal rakes without any demurrage charges since 19th April 2010. Though KTPS Units 1
to 4 are very old (110 MW Unit No. 1 & 2 being 27 years old & 210 MW Units No. 3 & 4
being 21 years old), the station performance is consistently well above the National average
as depicted in the operational parameters for last 5 years as under:-
YEA
R
GEN(M
U)
PLF(%
)
SPCFC. OIL
CONSUMP.(ml/kw
h)
AUX.
CONSUMP(
%)
AVAIL.
FACTO
R (%)
FLY ASH
UTILIZATIO
N (%)
2005-
2006
8294 90.60 0.48 9.27 91.51 79.45
2006-
2007
8163 89.17 0.57 9.36 89.86 88.51

39. 2007-
2008
8395 91.46 0.50 9.37 94.27 98.12
2008-
2009
8674 94.76 0.43 9.37 95.34 99.14
2009-
2010
8584 89.65 0.70 9.54 90.41
2010-
2011
9891 91.06 0.52 9.67 94.23 97.31
2011-
2012
10084.77
6
92.59 0.47 9.59 93.95 97.31
ENVIRONMENTAL PROFILE :
 adequate measures have been taken at ktps to control pollution and comply to the norms
laid by environment protection act. 1986. being a power station, located in the heart of kota
city, continuous efforts are made to ensure atmospheric emission of suspended particulate
matter within the prescribed limits.
 180 meter high stacks have been provided to release flue gases into the atmosphere at an
approx. velocity of 25 m/sec. so as to disperse the emitted particulate matter over a wide
spread area.
 the on-line stack spm monitoring system of codel Germany has been installed as per
requirement of central pollution control board.
 microprocessor based intelligent controllers to optimize the esp of 99.82% efficiency have
been provided. esps of 110 mw units # 1 & 2 were augmented under r&m scheme with
installation of 7 additional field to enhance efficiency upto 99.82%. dummy fields provided
in esp of 210 mw units # 3 & 4 were also filled in with installation of 7th field as such the
efficiency has increased up to 99.84%.
 adequate water spraying arrangements have been provided at coal unloading, transfer and
conveying system to arrest and restrict fugitive emission. the system is now further upgraded
with latest technology.
 development of green belt, about 3 lakhs plants of various species have already been
planted in kstps and ash dyke. the survival rate of plants is watched periodically.
*existing green cover area within plant - 90 hect.

40. *existing green cover area within ash dyke - 100 hect.
 regular monitoring of stack emission, ambient air quality and trade effluent is carried out.
 all the drains in the esp area and boiler area have been diverted to dedicated tanks and the
effluent collected is utilized for transportation of bottom ash disposal of the various units.
ASH UTILIZATION
FLY ASH :
In compliance to Govt. of India Gazette Notification issued on 14th Sept. 1999 for making
available ash free of cost ,KSTPS has achieved 100% Dry Fly ash utilization. KSTPS signed
agreements for dedicated generating units allocations including Construction & Operation of
complete dry fly ash evacuation system from each unit in two phases i.e. from ESP to
Intermediate Silo and Intermediate Silo to Main Supply Silo near KSTPS boundary with
following cement manufacturing companies -
• Unit # 1&2 - M/s. Associated Cement Co. Ltd.
• Unit # 3 - M/s. Birla Cement Works Ltd.
• Unit # 4 - M/s. Grasim Industries Ltd.
• Unit # 5 - M/s. Grasim Industries Ltd
• Unit # 6 - M/s. Shree Cement Ltd.
• Unit # 7(50% each) - M/s. Grasim Industries & M/s. Shree Cement Ltd.
POND ASH :
Concerted efforts have been made towards utilization of disposed fly & bottom ash
accumulated in KSTPS ash dykes. The ash is provided free of cost and has been utilized by
various small entrepreneurs i.e. Brick-kiln industries, small fly ash product industries,
Cement manufacturing Industries and for land filling by National Highway Authority of
India in construction of NH-12 and NH-76.
2 SURATGARH SUPER THERMAL POWER STATION
 suratgarh thermal power station is the first super thermal plant of rajasthan.
 it has installed capacity of 1500 mw, which is highest in the state.

41. LOCATION
suratgarh super thermal power station is located 27 km from suratgarh -15 km from suratgarh
to biradhwal on nh15,then 12km in east from nh15.it is having extreme hot & cold climate
and temperature varies between -1 to 50 ˚c
SANCTION OF SCHEMES (STAGE-I to V)
Stage Unit No. Capacity(MW) Cost(Rs.Crore)
I I & II 2x250 2300
II III & IV 2X250 2057
III V 1X250 753
IV VI 1X250 1117
TOTAL 6227
COMMISSIONING TARGETS AND ACHIEVEMENTS
UNITS
ZERO
DATE
TARGET
ACTUAL
DATE
DATE
OF
COAL
FIRING
DATE OF
COMMERCIAL
OPERATION
Remarks
UNIT-
1
Jun-91
MAR-
1997
10-MAY-
1998
04-OCT-
1998
01-FEB-1999
UNIT-
2
Jun-91 SEP-2000
28-MAR-
2000
07-JUN-
2000
01-OCT-2000
COMMISSIONED 6
MONTH AHEAD OF
SCHEDULE
UNIT-
3
23-
Jun-99
MAR-
2002
29-OCT-
2001
08-DEC-
2001
15-JAN-2002
COMMISSIONED 6
MONTH AHEAD OF
SCHEDULE

42. UNIT-
4
23-
Jun-99
SEP-2002
25-MAR-
2002
17-JUN-
2002
31-JUL-2002
COMMISSIONED 6
MONTH AHEAD OF
SCHEDULE
UNIT-
5
1-Feb-
01
JUN-2003
30-JUN-
2003
30-JUN-
2003
19-AUG-2003
COMMISSIONED IN
RECORD TIME OF
29 MONTH
UNIT-
6
15-
Jun-06
OCT-
2008
31-MAR-
2009
24-
AUG-
2009
30-DEC-2009 -
ACHIEVEMENTS
IT HAS ACHIEVED MANY MILESTONES SINCE COMMISSIONING OF ITS 1ST
UNIT DESPITE BEING LOCATED AT PLACE WHERE CLIMATIC CONDITIONS ARE
VERY ADVERSE.
2.Fly Ash Utilisation
sstps has achieved almost 100% fly ash utilization in 2010-11. working more efficiently
auxiliary power consumption has been reduced from 9.16% in 2009-10 to 9.12% in 2010-11.
we have also managed to reduce demurrage hours for unloading of coal rakes by remarkable
81% in 2010-11 from 2009-10. in 2009-10 number of demurrage hours were 3787 while for
2010-11 it has been reduced to just 708 hours.
3.Mini-Micro Hydel Plant
for financial year 2010-11 there is an increase of 206 % in total generation by mini/micro
hydroelectric plants (under sstps) from last year 2009-10. generation for 2010-11 is 67.89
lakh units while generation for 2009-10 was 22.18 lakh units.
4.CSR
under corporate social responsibility , bus facility has been started from sstps township to
nearby villages ,enabling village children to have quality education in kendriya vidyalaya and
dav school situated in sstps township
PERFORMANCE INDICES AT A GLANCE

43. Year
Total
Generation
(MU)
PLF
(%)
%
Aux.
Cons.
Sp. Oil
Cons.
(ml/Kwh)
Sp. Coal
Cons.
(Kg/Kwh)
Station Heat
Rate
(Kcal/Kwh)
Fly Ash
Utilisation
2001-
2002
4112.540 85.04 9.31 1.56 0.607 2505 0.97
2002-
2003
7145.676 88.94 9.18 1.07 0.614 2576 2.34
2003-
2004
8186.633 80.74 9.37 0.98 0.607 2429 12.62
2004-
2005
9362.319 85.50 9.30 0.83 0.635 2444 16.16
2005-
2006
9951.223 90.88 9.15 0.64 0.613 2478 40.37
2006-
2007
10205.589 93.20 9.16 0.53 0.624 2469 63.26
2007-
2008
10222.515 93.10 9.12 0.59 0.634 2491 81.55
2008-
2009
9740.606 88.96 9.19 0.77 0.669 2499 87.50
2009-
2010
9192.409 79.94 9.16 1.02 0.669 2476 88.74
2010-
2011
9409.777 71.61 9.12 1.340 0.665 2493 96.53
2011-
2012
9735.59 81.61 8.79 0.85 0.65 2502 91.38
2012-
2013
10570.321 80.44 9.05 1.06
STATION PERFORMANCE
HIGHLIGHTS & ACHIEVEMENTS (2010-11)
ENVIRONMENTAL MEASURES
1. 100 % ash utilization has been achieved in 2010-11 resulting in considerable reduction in
raw water consumption required for disposal of ash.
2. disposal of fly ash is ensured through closed containers only
3. green belt development is being done as per action plan to achieve 33% cover.

44. energy conservation measures
switching of cooling tower fans & reduction of raw water consumption through utilization of
waste water for fly ash preparation and green belt development.
strengthening of power evacuation system
commissioning of 400 kv stps-bikaner & 220 kv stps- bhadra feeders.
deployment of cisf
deployemnt of cisf for ensuring safety & security of the power station in line with the
directives of security agencies.
concrete road at rayanwali village
construction of cement concrete road at rayanwali village taken up by cement companies on
the behest of sstps authorities.
awards by g.o.i.
year generation award
1999-2000
meritorious productivity - shield
& 3.74 lacs
2000-2005
meritorious productivity gold
shield awarded by hon'ble
president of india dr. a. p. j. abdul
kalam on 24-aug-2004
2005-2006
shield awarded by hon'ble prime
minister of india dr. manmohan
singh on 21-3-2007
expansion plans
super critical units 7& 8
(1) proposed capicity 2x660 mw
(2) location suratgarh(rajasthan)
(3) total plant area 446 hectares
(4) project cost rs. 7920 crores
(5) fuel
primary fuel: coal
secondary fuel : hsd / hfo
(6) fuel requirement 6.5 mtpa
(7) source of water : indra gandhi canal project
(8) water allocation 60 cusecs
(9) ash generated
2.21 mtpa on 34% ash
content coal

45. (10) ash pond location
south west of plant about
3.0 km away
(already existing) land size : 576 hectares
(11) stack twin flue stack (275 metre)
(12)
nearest railway
station
biradhwal
highlights :-
1. administrative and financial approval accorded on 02-03-2009.
2. land acquisition completed
3. resolution of compensation related issues
4. water allocation has been made.
4 GIRAL LIGNITE THERMAL POWER PROJECT
SALIENT FEATURES
1.Plant capacity 2 X 125MW
2.Location Village: Thumbli At Giral,43 Km from Barmer.
3
Dates of Project Approval/Allocation
:
U#1 U#2
(i) Confirmation of Lignite supply 30.01.02 31.12.04
(ii) Administrative approval 04.10.02 11.04.05
(iii) Financial approval 07.07.03 11.04.05
(iv) Appointment of consultant 16.07.03 14.10.05
(v) Laying of foundation stone 19.07.03 -
(vi)
Allocation of water from Indira Gandhi
canal
04.09.03 04.09.03
4.Statutory no objection clearances :
U#1 U#2
(i) Defence Clearance 07.05.03 31.10.05
(ii) Stack Height Clearance 07.08.03 12.04.05
(iii) Environment Clearance (MOE&F) 23.11.04 05.01.06

46. 5.Fuel
(i) Lignite 6000 MT per day. ii) Lime 1500 MT per
day.
6.Water
* Indira Gandhi canal at Mohangarh through 600
mm & 165 km longpipeline.
* Canal Water made available at site on 8.07.06.
7.Land Cost 661.25 Bighas : Rs.41.08 Lacs
8.Project cost
Unit-I 764 Crores
Unit-II 750 Crores
9.Schedule of Commissioning Unit#1 Commissioned on 28.02.07.
Unit#2 Commissioned on 26.12.08
Unit#1 COD on 18.10.11
Unit#2 COD on 12.03.11
Performance Indices at a Glance GLPL,Barmer.Unit-I
Parameter
2006-
07
2007-08 2008-09 2009-10 2010-11 2011-12 2012-13
Generation
(LU)
1.24 1800.01 4170.55 3133.61 2889.22 2619.17

47. Plant Load
Factor (%)
0.011 16.38 38.09 28.62 26.39 22.24 23.92
Running Hours 9:43:00 2433:50:00 5860:52:00 4580:14:00 4168:39:00
Availability
Factor (%)
0.11 27.78 66.90 52.28 47.58
Performance Indices at a Glance GLPL,Barmer.Unit-II
Parameter 2008-09 2009-10 2010-11 2011-12 2012-13
Generation (LU) 442.51 3518.06 3076.59 2914.10 2099.81
Plant Load Factor (%) 15.36 32.13 28.10 26.54 19.18
Running Hours 714:21:00 4508:34:00 4531:06:00
Availability Factor
(%)
31.03 48.49 51.17
5CHHABRA THERMAL POWER STATION
* Chhabra Thermal Power Station is the coal based Electricity Generating Power Plant of
Rajasthan.
location
Chhabra Thermal Power Station is located at 22km from Chhabra, near village Chowki
Motipura, Tehsil Chhabra, Distt. Baran (Rajasthan).
sanction of schemes (stage-i to v)
Phase
Unit
No.
Capacity(MW) Cost(Rs.Crore)
I I & II 2x250 2820
II III & IV 2X250 2991
operational parameters
Year Gen(MU) PLF(%) SPCFC OIL AUX.

48. CONSUMPTION CONSUMPTION
2009-2010 246.92 22.61 -- --
2010-2011 1227.28 56.04 8.37 9.78
2011-2012 1998.74 70.50 3.15 11.60
2012-2013(Upto
Feb.13)
2598.86 64.88 2.213 10.75
Project Highlights:
(1) Planned capacity 2320MW
(2) Location Near village Chowki Motipura, Tehsil Chhabra, Baran District
(3) Site Features
Gently sloping 400M – 390M
Extent of Area : About 1100 acres
Site Elevation : 400M above MS(Highest Flood level 385M)
Uninhabited Site
No major township or industries in the vicinity
Well connected to State Highway – 51
Well connected to West Central Railway line (Bina-Kota
(4) Primary Fuel
Coal from South Eastern/Northern Coal fields (Near Korba)
Calorific value : 3500K Cal/kg)
Coal requirement : 2.5MTPY for 500MW
5.0MTPY for 1000MW
(5) Water
Source : (i) From nearby Parvati River
(ii) From nearby Bethali Dam
Water Requirement : 70,000 Cu.m/day (15.5MGD)
(6) Power Eqation 400kV/220kV Switchyard with Interconnecting Transformers
(7)
Environmental
Issues
Liquid effluent: Zero discharge concept will be adopted.
Complete effluent water will be treated re-used.
Emission levels (Particulars, SO X, NO X): will be maintained
well within the statutory stipulations. 250M tall common
chimney for 2 units.
Thermal Pollution: Nil
Noise Pollution levels: Will be maintained well within the
statutory stipulations
Solid Waste management: 100% utilisation of fly ash for

49. commercial utilization.
super critical units 5 & 6
(1) proposed capicity 2x660 mw
(2) location
near village chowki motipura, tehsil chhabra, baran
district
(3) total plant area 709 hectares
(4) project cost rs. 7920 crores
(5) fuel
primary fuel: coal
secondary fuel : hsd / hfo
(6) fuel requirement 6.5 mtpa
(7) source of water : lashi, parwan irrigation project
(8) water allocation 1570 mcft
(9) stack twin flue stack (275meter)
(10)
nearest railway
station
chowki motipura
gas based units
(1) proposed capicity 3x110 mw
(2) location
near village chowki motipura, tehsil chhabra, baran
district
(3) total plant area 67 acres
(4) project cost rs. 1320 crores
(5) fuel primary fuel: liquefied natural gas
(6) fuel requirement 1.70 mmscmd
(7) source of water : parwan dam
(8) water allocation 10 cusec (315 mcft)
(9) stack 70 meter
(10)
nearest railway
station
chowki motipura
HIGHLIGHTS :-
1. Administrative & Financial approved accorded on 02.03.2009.
2. Land Acquisition completed.
3. Water allocation has been made.
4. MOEF Clearance awaited.

50. 6 KALISINDH THERMAL POWER PROJECT
The site of Kalisindh Thermal Power Project is located in Nimoda, Undal, Motipura,
Singharia and Devri villages of Tehsil Jhalarapatan, Distt. Jhalawar. The proposed capacity
of coal based Thermal Power Project is 1200 MW. The project site is about 12 km from
Jhalawar (Distt. Head quarter ) and NH-12 .It is 2km from state highway No.19 and 8 km
from proposed RamganjMandi - Bhopal broad gauge rail line.
The site selection committee of Central Electricity Authority has visited the
Nimoda and its adjoining villages of Jhalawar Distt. and site was found techno-economical
feasible for setting up of a Power Project. The Govt. of Raj. have included that project in 11
th five year plan. The estimated revised cost of the project is Rs.7723 Crores. M/s. TCE
Bangalore has been appointed as the technical consultant for the project. The state irrigation
department has alloted 1200 mcft water for the project from proposed Kalisindh dam. The
origin of the Kalisindh river is from northern slop of Vindya Mountains. The river enters
from MP to Rajasthan near village Binda. After flowing 145 km in Rajasthan, the Kalisindh
river merges in Chambal river near Nanera village of Distt.Kota. Its catchment area is about
7944 sq.km in Jhalawar & Kota Distt. The existing Dam is located at Bhawarasa village,
primarily for P.H.E.D. purpose is being uplifted for providing a storage of 1200mcft water

51. for this power project.
The GOR has allotted 842 bigha Government land and acquired 1388 bigha private khatedari
land for the thermal project .Phase-1 will be constructed on 1400 bigha land only..
EPC contract has been awarded to M/s. BGR Energy System Chennai on
dt.09.07.2008. Total project cost is Rs.7723Crores (Revised).
Ministry of Coal, Govt. of India has allotted ‘Paras east and Kanta basin
‘coal blocks to RVUN in Chhatisgarh state. The RVUN has formed new company under
joined venture with M/s. Adani Enterprises for mining of coal blocks and new company
started the work. Annual coal requirement for the project is 56 Lacs TPA.
Progress Status as on 31.05.13
Unit#I
Commissioning activities for Rolling and Synchronization of this 600 MW commenced from
April’2013, Steam Blowing, Turbine Box-up, Barring Gear etc. have been achieved till date.
The Rolling and Synchronization was completed on dt.30 May 2013 on oil. The erection
work of Coal Mills, Coal Handling System, Ash Handling System is in progress, the unit is
scheduled to synchronized on designated fuel i.e. Coal prior to 31st July 2013.
The Rail Linking between serving station i.e. Jhalawar City to KaTPP Plant is also in
progress for receiving of coal by rail, expected to be completed in the mid of July’2013.
The water supply for the 2x600 MW Kalisindh Super Thermal Power Project is from
proposed Kalisindh Dam near village Bhanwarasi. This dam is being constructed by Water
Resources Department, GoR. The cost of the dam is being born by RRVUNL, the
construction of dam is in full swing and expected completion of dam is June’2014. However
the contingency arrangement have been made by raising the height of existing anicut situated
near the Kalisindh Dam.The mechanical work of Water Conductor System i.e. Construction
of Intake Well, Erection of Pumps, Laying of Pipeline from Kalisindh Intake Well (situated
at Kalisindh Dam Site) to KaTPP plant have been completed.
Unit#II
The erection work of Boiler for this unit have been completed. The erection work of Turbine,
Generator and its auxiliaries is in advanced stage. The Turbine Box-Up, Oil Flushing, Steam
Blowing and Turbine Barring Gear is scheduled to be completed by 31.08.2013. The Rolling
and Synchronization of the unit is scheduled on 30.11.2013 on coal.
Salient Features
Project Kalisindh Super Thermal Power Project Jhalawar
Capacity 1200 MW(2x600 MW)
Project Site
Village-Undel, Motipura, Nimoda, Singhania & Deveri of
Tehsil Jhalarapatan, Distt. Jhalawar
Project Location
The project site is about 12 km from NH-12, 2km from state
highway and 8 km from proposed RamganjMandi - Bhopal
broad gauge rail line.

52. Land Area 2230 Bigha/564 Hq. (1400 bigha/350 Hq. in I stage)
Water source and quantity Dam on Kalisindh river. 3400 CuM/ Hrs.
Fuel Source
Main Fuel- Coal from captive coal blocks (Paras east and
kanta Basin in Chhatisgarh state)
Secondary Fuel- FO/HSD.
Quantity of Fuel (at 80% PLF)
Coal-56 Lacs TPA
FO/HSD-13000-14000 KL/A
Electro Static Precipitator 99.98 % Capacity
Stack Height 275 Mtr.
Estimated revised Cost Rs.7723 Crores
Synchronization Date
Unit-I August 2013 achieved
Unit-II November 2013
SI
NO.
Activity
As per L-2
Sch(Unit#1)
Actual
Date
Anticipated
As per L-2
Sch.(Unit#2)
Actual Anticipated
01
Boiler Civil
Works Start
30.12.08 24.01.09 11.03.09 23.03.09 -
02
Boiler Erection
Start
14.09.09 23.10.09 02.12.09 26.03.10 -
03
Boiler Drum
Lifting
01.03.10 19.05.10 20.05.10 14.08.10 -
04
Boiler Hyd. Test
(non-Drainable)
07.12.10 08.04.11 24.01.11 15.12.11 -
05 Boiler Light Up 12.03.11 30.12.12 07.06.11 - 31.08.13
06 SBO 19.05.11 26.03.13 10.08.11 - 30.09.13
07
Condenser
Erection Start
03.04.10 27.11.10 24.06.10 25.08.11 -
08
TG Erection
Start
23.06.10 20.12.10 31.08.10 25.08.11 -
19
TG Box Up
(Final)
31.03.11 31.01.13 10.06.11 - 28.08.13
11 TG Oil Flushing 17.05.11 25.01.13 27.07.11 - 25.08.13
11
Turbine on
Barring Gear)
27.05.11 03.02.13 06.08.11 - 31.08.13
12
Synchronization
(on Oil)
14.06.11 30.05.13 05.09.11 - 30.09.13
13 Coal Firing 19.07.11 - 31.07.13 10.10.11 - 30.11.13
14 Full Load 07.10.11 - 30.09.13 06.01.12 - 31.12.13

53. 7 Ramgarh Gas Thermal Power Station
• Ramgarh gas thermal power station is the first gas thermal power plant of Rajaisthan.(On
dated 13-11-1994)
LOCATION
Ramgarh gas thermal power plant station is situated near village Ramgarh and 60 kms away
from Jaisalmer. It is the installed capacity of 223.5 MW.
Stage Unit No.
Capacity
(MW)
Cost
(Rs.
Crore)
Synchronising
Date
I *1(Gas Turbine) 3MW* 19 ----
I 1(Gas Turbine) 35.5 180 12.01.1996
II 2(Gas Turbine) 37.5
300
07.08.2002
3(Steam Turbine) 37.5 25.04.2003
III 4(Gas Turbine) 110 640 30.03.2013
Operational Performance of Plant
Particulars
2004-
05
2005-
06
2006-
07
2007-
08
2008-
09
2009-
10
2010-
11
2011-
12
2012-
13
Gross
Generation
(LU)
3611.3
92
4356.2
09
4041.4
40
4141.1
53
3486.7
82
3539.4
4
3028.8
5
5367.9
4
4979.0
6
Plant Load
Factor (%)
37.30% 45.00% 41.75% 42.78% 36.00% 36.57% 31.29% 55.30% 51.44%
Aux.Power
Consumption
(LU)
241.28
311.66
2
268.17
9
551.61
333.11
6
279.02
9
161.45
2
95.796 90.245
Gas
Consumption(
SCM)
219671
057
238364
647
240482
508
248875
773
209782
021
213635
298
183481
825
297151
090
273012
213

54. EXPANSION
GAS THERMAL POWER STATION STAGE III
1.
Proposed
capacity
160MW
2. Location Ramgarh
3. Total plant area 796 bigha,17 biswa
4. Project cost 640 crores
5. Fuel GAS and HSD
6. Source of water Indra Gandhi canal
7. Fuel required 9.5 lac. SCM per day
8 Water allocation 10.8 cusecs
The gas and steam unit are schedule to be syncronised on respect Jan. 2012 & May 2012
respectively
At present a combined gas cycle power unit of 160MW under stage III is under construction.
7 DHOLPUR COMBINED CYCLE POWER STATION
The Installed Capacity of Dholpur Combined Power Station is 330MW.
Unit
No
Capacity(MW) Cost(Rs.Crore) Synchronising Date
1 GT 110
1100
29.03.2007
2 GT 110 16.06.2007
3 ST 110 27.12.2007

55. Location
Dholpur Combined Power Station is located in Dholpur City in eastier part of Rajasthan State
and is situated above 7Km from District HeadQuarter.
Environmental Profile
Based on Gas This Project is Compatively safe in view of environment & water pollution.70
Meter high stack has been provided to release fuel gases into the atmosphere so as to disperse
the emitted matter over a wide spread area.
Highlights
Area 143 Bigha
Water Requirement 20 Cuses from Chambal River
Fuel Requirement 1.5 MM SC MD gas
Fuel Supplier ONGC
Fuel Transporter GAIL
Operational Performance of Plant
Particulars
2007-
08
2008-09 2009-10 2010-11
2011-
12
2012-13
Gross Generation (MU)
214.9
0
2288.78 2424.74 1994.83
2254.1
4
11624.3091
8
Plant Load Factor 87.53 79.17 83.88 69.01 77.76 40.21
Aux.Power
Consumption(%)
- 2.61 2.49 2.84 2.73
Gas
Consumption(MMBTU
)
-
17598464.35
4
18324175.3
5
1512476.1
2
References
1. Electricity
2. http://books.google.com/books?id=ZMw7AAAAIAAJ&pg=PA175&dq=central+stati
on+steam+engine+turbine&hl=en&ei=uzfQTKX9EsKXnAfF2cSNBg&sa=X&oi=bo
ok_result&ct=result&resnum=6&ved=0CEMQ6AEwBQ#v=onepage&q=central%20s
tation%20steam%20engine%20turbine&f=false The early days of the power station
industry, Cambridge University Press Archive, pages 174-175

56. 3. Maury Klein, The Power Makers: Steam, Electricity, and the Men Who Invented
Modern America Bloomsbury Publishing USA, 2009 ISBN 1-59691-677-X
4. Climate TechBook, Hydropower, Pew Center on Global Climate Change, October
2009
5. British Electricity International (1991). Modern Power Station Practice:
incorporating modern power system practice (3rd Edition (12 volume set) ed.).
Pergamon. ISBN 0-08-040510-X.
6. Babcock & Wilcox Co. (2005). Steam: Its Generation and Use (41st edition ed.).
ISBN 0-9634570-0-4.
7. Thomas C. Elliott, Kao Chen, Robert Swanekamp (coauthors) (1997). Standard
Handbook of Powerplant Engineering (2nd edition ed.). McGraw-Hill Professional.
ISBN 0-07-019435-1.
8. Pressurized deaerators
9. Tray deaerating heaters
10. Air Pollution Control Orientation Course from website of the Air Pollution Training
Institute
11. Energy savings in steam systems Figure 3a, Layout of surface condenser (scroll to
page 11 of 34 pdf pages)
12. Robert Thurston Kent (Editor in Chief) (1936). Kents’ Mechanical Engineers’
Handbook (Eleventh edition (Two volumes) ed.). John Wiley & Sons (Wiley
Engineering Handbook Series).
13. EPA Workshop on Cooling Water Intake Technologies Arlington, Virginia John
Maulbetsch, Maulbetsch Consulting Kent Zammit, EPRI. 6 May 2003. Retrieved 10
September 2006.
14. Beychok, Milton R. (2005). Fundamentals Of Stack Gas Dispersion (4th Edition ed.).
author-published. ISBN 0-9644588-0-2. www.air-dispersion.com
15. Guideline for Determination of Good Engineering Practice Stack Height (Technical
Support Document for the Stack Height Regulations), Revised, 1985, EPA Publication
No. EPA–450/4–80–023R, U.S. Environmental Protection Agency (NTIS No. PB 85–
225241)
16. Lawson, Jr., R. E. and W. H. Snyder, 1983. Determination of Good Engineering
Practice Stack Height: A Demonstration Study for a Power Plant, 1983, EPA
Publication No. EPA–600/3–83–024. U.S. Environmental Protection Agency (NTIS
No. PB 83–207407)