design basis imfa
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OC No. Total Sheets
DDC 067Document No. PP 067 M B01 0
146
DESIGN BASIS REPORT FOR
MECHANICAL
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ORISSA
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MECHANICAL
PP 067 M B01 0 1 2
DESIGN BASIS REPORT MECHANICAL
INDEX
1. INTRODUCTION ...............................................................................................9
2. UNITS OF MEASUREMENT & ABBREVIATIONS.........................................10
2.1. UNITS OF MEASUREMENT .............................................................................10
2.2. ABBREVIATIONS............................................................................................10
3. CODES & STANDARDS.................................................................................11
4. POWER PLANT CONFIGURATION...............................................................14
4.1. PLANT CONFIGURATION ................................................................................14
4.2. PLANT STARTUP,OPERATION AND CONTROL PHILOSOPHY ..............................16
4 3 CUSTOMERS DESIGN INPUTS 16
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7.3.4. Pressure Gradient ............................................................................................. 47
7.3.5. Velocity Profile................................................................................................... 47
7.3.6. Safety valve details ........................................................................................... 48
7.3.6.1. Safety Valve Set Pressures .....................................................................................48
7.3.6.2. Safety Valve Relieving Capacity ..............................................................................48
7.3.7. Fuel, Limestone & Bed Material Consumption.................................................. 48
7.4. BOILER MOUNTINGS AND FITTINGS ................................................................49
7.4.1. Steam Drum ...................................................................................................... 49
7.4.2. Furnace headers ............................................................................................... 49
7.4.3. Drain Header..................................................................................................... 49
7.4.4. Superheater....................................................................................................... 50
7.4.5. Spray Water Line............................................................................................... 50
7.4.6. Economiser ....................................................................................................... 50
7.5. SOLID FUEL FIRING SYSTEM..........................................................................50
7.5.1. Fuel Bunker....................................................................................................... 51
7 5 2 Fuel Firing System 51
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7.13. ESP DESIGN BASIS .......................................................................................60
7.14. CHIMNEYDESIGN BASIS.............................................................................61
7.14.1. Calculation of Chimney Height....................................................................... 62
7.14.2. Calculation of Chimney Diameter................................................................... 62
7.14.3. Sketch of Chimney......................................................................................... 63
8. STEAM, FEED WATER AND CONDENSATE SYSTEM ................................63
8.1. STEAM SYSTEM............................................................................................63
8.1.1. Control Philosophy............................................................................................ 66
8.2. FEED WATER SYSTEM ..................................................................................66
8.2.1. Deaerator .......................................................................................................... 668.2.2. Boiler Feed Pumps............................................................................................ 68
8.2.3. HP Feed Water Heaters.................................................................................... 70
8.2.4. Feed Water Control Station.............................................................................. 70
8.2.5. Control Philosophy............................................................................................ 70
8.3. CONDENSATE SYSTEM..................................................................................71
8 3 1 S f C d 72
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9.2.1.2. System Sizing Calculation........................................................................................89
9.2.2. Auxiliary Cooling Water System For Auxiliaries ................................................ 91
9.2.2.1. System Description ..................................................................................................91
9.2.2.2. System Sizing Calculation........................................................................................92
9.2.3. Cooling Water Treatment Scheme.................................................................... 94
10. FUEL OIL SYSTEM.........................................................................................94
11. FUEL HANDLING SYSTEM............................................................................94
11.1. SYSTEM SIZING ............................................................................................95
11.2. SYSTEM DESCRIPTION ..................................................................................96
12. LIME STONE HANDLING SYSTEM .............................................................101
12.1. SYSTEM DESCRIPTION &SYSTEM SIZING .....................................................101
13. ASH HANDLING SYSTEM............................................................................102
13.1. SYSTEM DESCRIPTION ................................................................................102
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16. VENTILATION SYSTEM ...............................................................................117
16.1. SYSTEM DESCRIPTION ................................................................................117
16.1.1. Ventilation System for Power House Building & associated Areas.............. 117
16.1.2. Ventilation System for Auxiliary Buildings in Various Locations .................. 118
16.2. SYSTEM SIZING ..........................................................................................120
17. FIRE PROTECTION SYSTEM ......................................................................121
17.1. SYSTEM DESCRIPTION ................................................................................121
17.1.1. Fire Water System ....................................................................................... 122
17.1.2. Hydrant System ........................................................................................... 122
17.1.3. Spray Water System.................................................................................... 123
17.1.4. Portable & Mobile Fire Extinguishers........................................................... 124
17.1.5. Fire Detection & Alarm System.................................................................... 124
18. CRANES AND HOISTS.................................................................................125
19. ELEVATORS.................................................................................................127
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21.12. EFFLUENT ...............................................................................................137
21.13. SERVICE AND POTABLE WATER PIPE LINE...................................................138
21.14. CONDENSER COOLING WATER PIPING ........................................................138
21.15. AUXILIARY COOLING WATER PIPING ...........................................................138
21.16. FIRE WATER PIPING .................................................................................13821.17. VALVES...................................................................................................138
21.17.1. Insulation .................................................................................................. 139
21.17.2. Pipe Supports and Hangers...................................................................... 139
21.17.2.1. Constant Spring Hangers.......................................................................................139
21.17.2.2. Variable Spring Hangers ........................................................................................140
21.17.2.3. Rod Hangers ..........................................................................................................140
21.17.2.4. Pipe Clamps and Shoe / Saddle supports .............................................................140
21.17.2.5. Materials of Construction .......................................................................................140
21.18. GENERAL GUIDELINES FOR PIPING............................................................140
22. ANNEXURES ................................................................................................142
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1. INTRODUCTION
This document aims at establishing the criteria for basic and detail
engineering, sizing and specifications of the Power Plant equipment, systems,
components, and piping for the 2 x 60 MW Power Plant at Choudwar in Cuttack
district, Odisha, being set up by M/s. Indian Metals & Ferro Alloys (IMFA) Limited.
The basic design inputs like Fuel analysis, Water analysis, Site conditions,
etc. have been spelt out in various sections of this document, which are as per
IMFA inputs. Details developed in this document is generally in line with theagreed contract document.
This document is to be read in conjunction with design basis report for
Electrical Systems, Civil Works and Instrumentation systems. For an overall
understanding of the plant and design of auxiliary equipments and system, certain
d t il f j i t lik b il t t bi t h b i t d
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2. UNITS OF MEASUREMENT & ABBREVIATIONS
2.1. UNITS OF MEASUREMENT
Deg.C Degree Celsius
kg/cm2 (a) or Ata Kilograms per Square Centimetre (Absolute)
kg/cm2 (g) Kilograms per Square Centimetre (Gauge)
kV Kilo Volt
kW Kilo Watt
MLC Meters of Liquid Column
MW Mega Watt
MWC Meters of Water Column
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LP Low Pressure
MB Mixed Bed
MCW Main Cooling Water System (for Condenser)
MOC Material of Construction
MSL Mean Sea Level
PRDS Pressure Reducing & De-superheating Station
PRV Pressure Reducing Valve
Re Reynolds Number
RL Reference Level
RO Reverse Osmosis
SAC Strong Acid Cation
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Bureau of Indian Standards (BIS)
International Electro-technical Commission (IEC)
DIN Standards
British Standards (BS)
American Society of Mechanical Engineers (ASME)
American Society of Testing and Materials (ASTM)
American Welding Society (AWS)
American Institute of Steel Construction (AISC)
American Water Works Association (AWWA)
American National Standard Institute (ANSI)
Architecture Institute of Japan (AIJ)
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Standards of Manufacturer Standardization Society (MSS)
Indian Electricity Act
Indian Electricity Rule
Indian Factory Act & State Factory Act
Instrument Society of America (ISA)
Federal Occupational Safety and Health Organization (OSHA)
Loss Prevention Association of India (LPA)
Emission regulations of Central Pollution Control Board, India
Central Board of Irrigation and Power (CBIP) publications, India
Pollution Control Regulations of Dept. of Environment, Govt. of India
Permissible limits for pollutants of Orissa Pollution Control Board
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reliability.
4. POWER PLANT CONFIGURATION
4.1. PLANT CONFIGURATION
The power plant consists of the following major Mechanical systems and
equipment:
Two (2) number Boilers: Circulating Fluidized Bed Combustion (CFBC)
type, each generating 240 TPH at 101 kg/cm2 (a) pressure and 540 +
5oC temperature at the Main Steam Stop Valve using fuel as per Coal
Analysis mentioned elsewhere in this document. The boiler envisage de-
sulphuring using lime stone as per lime stone analysis mentioned
elsewhere in this document.
Two (2) number Electro Static Precipitator (ESP), one each per
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Regenerative feed heating system consists of two LP heater, one
Deaerator, two HP heater.
Turbine bypass system Capacity 60% of TMCR.
Boiler feed water pumping system with 3 x 100 % Motor driven boiler
feed water pumps. Out of these three pumps, one will be operating
normally for each boiler unit while the third pump shall remain as a
common standby and will come into operation automatically in case one
of the working pump fails.
One Main Cooling Tower for both units with 7 cells (6 working & 1
standby) induced draft counter flow design and RCC / Pultruded FRP
construction and main cooling water pumping system.
One Auxiliary Cooling Tower for both units with 2 cells (1 working & 1
standby) induced draft counter flow design and FRP / Pultruded FRP
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CW treatment plant, potable and service water system and effluent
system.
Compressed air system consists of plant air compressors and Air
drying plant for instrument air and service air compressors for service
air.
Ai r condit ioning &Venti lat ion system.
Fire protection system for the power plant, transformer area, fuel oil
area, switch yard area, coal handling area and ash handling area.
Inter-connecting piping system
EOT crane for TG building and miscellaneous hoists and monorails.
Elevators for Boiler and Power House building.
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MECHANICALPP 067 M B01 0 1 17
Sr.No.
Item Description
1. Project Title 2 X 60 MW Thermal power project
2. Location Choudwar, Distt. Cuttack, State ofOrissa.
Longitude: 8554 E
Latitude: 2031 N
3. Nearest Town Choudwar: 0 KMs, Cuttack: 12 KMs
4. Nearest City Cuttack 12 KMs.
5. Nearest Port Paradeep
6. Nearest Railway Station Charbatia 12 km away
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Sr.No.
Item Description
g. Type of atmosphere Hot and Sultry
h. Annual Mean WindVelocity
6.4 Km/hr
i. Maximum Wind velocity As per IS 875 Part III
j. Basic wind speed As per IS 875 Part III
k. Design Wind velocity As per IS code specific to the sitelocation Choudwar, Cuttack
l. Wind Direction South to North.
m. Seismic Data As per IS : 1893 (Latest Issue)
4.3.2. COALANALYSIS
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TOTAL 100.00 100.00 100.00
GCV (Kcal/Kg) 3280.00 2010.00 2645.00
PROXIMATE ANALYSIS
Ash 42.00 60.00 51.00
Volatile matter 21.00 14.00 17.50
Moisture 15.00 13.00 14.00
Fixed carbon 22.00 13.00 17.50
Total 100.00 100.00 100.00
COAL SIZE
Feed Coal size at Grizzly of GroundHopper by Customer
90 % below 100 mm.
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MECHANICALPP 067 M B01 0 1 20
Titanium as TiO2 1-2 2.32
Total carbonates as CO3 - < 0.01
Manganese oxide as
Mn3O4/MnO0.02-0.04 0.12
Zinc as ZnO - 0.02
Loss on ignition - 2.11
4.3.4. LIME STONEANALYSIS
COMPONENT % BY WT. (RANGE)
LIME STONE ANALYSIS
CaCO3 90 94% for operability. Forguaranteed sulphur capture onperformance fuel to restrict chimneyheight to 44 m, CaCO3 content shall
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TiO2 % 1.5 1.7
MnO % Traces
CaO % 0.5 0.6
MgO % 0.2 0.25
P2O5 % Less than 0.1
Na2O % Less than 0.22
K2O % Less than 0.45
BED MATERIAL SIZE
Size in Microns Unit % Passing
< 500 % 100
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8. Bi- Carbonates mg/l as CaCO3 52 60
9. Total Anions mg/l 72 89
10. Iron as Fe mg/l as CaCO3 0.8 1.0
11. Silica (Reactive) mg/l as SiO2 8.0 10
12. M- Alkalinity mg/l as CaCO3 52 60
13. Turbidity NTU 184 200
14. Total Suspended Solids mg/l 170 190
15. Total Dissolved Solids mg/l 70 80
16. pH value at 25oC 7.6 7.8
17. Conductivity at 25oC S/cm 137 150
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Convenience of fuel intake.
Convenience of Installation.
Minimum width of clear access around equipment shall be provided as 1
m.
Minimum clear height between two consecutive floors shall be determined
considering maintenance, lifting and safety requirements. A clear head
room of 2 m shall be maintained between floors and over head piping /
cabling.
All road crossing for pipe / cable rack shall be done with minimum 5.5 m
head room from top of road to bottom of rack where only Truck movement
is expected and 7.0 m where crane movement is expected. Minimum 8 m
clearance shall be kept in case of railway track with overhead traction.
Similarly top cover over any underground pipe / cable shall be minimum 1
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c) Cooling tower
d) Compressor room
f) DG room
5.1.1. POWER HOUSE
The Power House will include:
Steam Turbine Generator & auxiliaries which includes condenser, CEPs,
LP & HP heaters, Deaerator, BFPs, steam jet ejectors, gland steam condenser etc.
located in the Steam Turbine Hall.
Power house building size shall be 87 m x 31.5 m devided into AB bay
(20.5 m wide) & BC bay (11 m wide). AB bay shall have 3 floor elevations i.e.
ground floor at 0 m, mezzanine floor at 4.5 m & operating floor at 10 m. BC bay
shall have 4 floor elevations i.e. cable spreader floor at 0 m, swithgear floor at 4.0
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5. The crane rails elevation of the turbine hall shall be selected based on
turbine height and crane clearance required above turbine.
6. The vertical can type Condensate Extraction Pump will be located adjacent
to the Condenser on the ground floor.
7. The Lube Oil System will be located at mezzanine floor (4.5 m) level on
turbine side.
8. The Deaerator will be mounted on the roof of the control building i.e. at
Deaerator floor level (15 m). The Deaerator foundation design will take into
consideration any possible vibration due to steam chugging.
9. The boiler feed pumps shall be located within the power house at ground
floor (0 m). Vertical HP & LP heaters are also located on ground floor.
10. A mezzanine floor (4.5 m) would be provided to accommodate STG
auxiliaries like Gland Steam Condenser & Steam Jet Air Ejector.
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provided with necessary aviation lighting, lightning-protection, sampling ports with
platforms etc.
Adequate platform and staircase will be provided for boiler to access
different floor levels and equipment / valves / instruments of boiler for operation
and maintenance.
Both the boiler will be suitably connected through galleries at three different
levels.
5.1.3. COOLING TOWERAREA
Cooling tower area consists of Main Cooling Tower (MCT), Auxiliary
Cooling Tower (ACT), Main & Auxiliary cooling water pump house, MCC & control
room and chlorine dioxide generator room.
The MCT shall be of RCC / Pultruded FRP construction & ACT shall be of
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The inclination angle for coal conveyor will be 14 maximum. Central
walkway of 1000 mm and side walkways of 800 mm with 2.7 m clear height will be
provided along the belt conveyor gantry. A separate MCC cum control room for
coal handling plant will be provided near the crusher house.
5.3. WATER SYSTEM AREA
5.3.1. RAW WATER RESERVOIR
Raw Water Reservoir shall be developed in designated area for collection
and storage of raw water. Reservoir shall be a cut and fill arrangement withsuitable embankment around this area upto a height required to build the 10,000
m3 capacity of the reservoir. Reservoir shall have two (2) compartments so that
one half can be emptied and maintained without disturbing the plant operation.
Design and construction of the reservoir shall be done in such a fashion that no
water can escape from the reservoir through seepage.
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5.4. SWITCHYARD AREA
The 132 kV switchyard & 33 kV switchyard are located on west end side of
the plant so that HT line from the generator transformer can be conveniently
interconnected.
5.5. ASH SILO AREA
Bed & Fly ash silos of RCC construction are provided eastern side of the
plant near to the plant boundary & away form main plant area to avoid the dust
nuisance while discharging to the open truck.
5.6. MISCELLANEOUS
The interconnection pipe work between plant utilities and power block
equipment will be routed through pipe racks / sleepers and pipe trenches
depending on the layout. The Main Cooling water and Auxiliary Cooling water
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6.2. TURBINE
The Steam Turbine will be of horizontal, single casing impulse-reaction with
axial flow multistage construction. The Turbine will be designed with five bleeds,
for the regenerative heating requirement in LP Heater, Deaerator and HP Heater.
Steam Turbine Casings & Admiss ion Valves
The turbine casing is horizontally split. The upper and lower casing halves
are flanged and assembled by bolts. Steam flow through the turbine is in the axial
direction. After leaving the body of the emergency stop valve, the live steam
enters the valve chest with the control valves which forms an integral casting with
the upper half of the outer casing. The valve chest is designed as a transverse
tube with openings at both ends for assembly.
The turbine casing is divided into an admission and an exhaust section.
Depending on the initial steam conditions, the admission sections of comparable
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The guide blades are manufactured from drawn bar material and have
pronged roots. The guide blade tips are fitted with riveted shroud strips.
Bearings
By its brackets, the outer casing is supported on the two bearing pedestals
independently from the bearing housings. The vertical position of the outer casing
is determined by adjustable positioning elements located between the brackets
and the supporting plane of the pedestals. The clearance left between the
underside of the assembly-bolt head and the bracket allows for both axial and
lateral expansion of the outer casing with respect to the pedestal. The central
position is ensured by guideways in the bottom half of the casing. They leave the
casing free to expand also in the vertical direction. The fixed reference position of
the casing is at the rear end support brackets. The casing is thus free to yield to
thermal expansion by moving forward on special slide elements between the front-
end brackets and the front bearing pedestal. The turbine rotor is supported in the
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multiple segments that would be pushed in the working position by the flat springs
and by the steam pressure. The stator labyrinth rings segments can be pushed
away from the rotor in case of accidental contact and the rubbing of rotating and
stationary parts can be minimised. The shaft shall have in the gland sections
caulked sheet fins that together with the stator collars form the small chambers of
the labyrinth gland.
During normal operation, the source of sealing steam is from the turbine
itself. During start-up and low loads, an alternative source of sealing steam is
provided from the main steam.The front outer gland shall be fed from a pressure-
control valve, which shall receive the steam from the main steam line. The rear
outer gland seals during the normal operation permanently face the vacuum inside
of the turbine casing and must be therefore continuously fed by the steam. The
feeding steam shall be taken from the front gland leakage. The leakage steam
from outer labyrinths shall go to the Gland Steam Condenser (GSC). The gland
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extraction steam lines before the QCNRV connection are connected to condenser.
The downstream of QCNRV, the drains are connected to atmospheric flash tank
and taken out. Vacuum drains are connected to a manifold in the flash tank whose
top nozzle is connected to steam space of the Condenser and bottom nozzle
connected to the hotwell. The high pressure drain is connected farthest from the
condenser, where as the low pressure drains are connected closer to the
condenser. The drain manifold connection will be above the maximum level in the
condenser hotwell.
6.5. TURBINE LUBE OIL SYSTEM
6.5.1. OIL STORAGE TANKS
Each turbine will have one (1) main oil tank designed considering the
complete drain oil from lube oil system & control oil system. The capacity of the
main oil tank is about 14 m3. The main oil tank will be provided with necessary
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6.5.3. OIL PUMPS
6.5.3.1. Main & Auxiliary Lube Oil Pump
Total three (3) pumps of identical capacity i.e. 3 x 100 % have been
provided, each one capable of meeting the total lube oil requirement. One of thesepumps is designated as Main Oil Pump (MOP) and other two as Auxiliary Oil
Pump (AOP). All the three pumps are AC motor driven.
6.5.3.2. Emergency Oil Pump
The turbine will be provided with an emergency oil pump, mounted on top
of oil tank, driven by an AC & DC motor. It will cater to the needs of bearings of
turbine, gearbox and alternator in case of failure of AC motor driven auxiliary lube
oil pump.
6.5.3.3. Overhead Tank
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escaping oil.
6.5.6. LUBE OIL PURIFIER
An oil purifier will be provided with necessary filters and heater, including
the pump and motors of the purifier system. The purifier is an off-line equipmentmeant to clean the oil in the system by partial recirculation (operated for one shift
per day). Desludging of the purifier shall be done manually periodically. The
system will purify the re-circulating lubricating oil from entrained moisture &
suspended solids. The purifier capacity will be 2000 LPM.
6.6. JACKING OIL PUMP
The turbine will have a 1 x 100 % AC motor driven and 1 x 100 % DC motor
driven jacking oil pump for turbine and generator shaft lifting during starting,
designed so as to lift the rotor from standstill condition.
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MECHANICALPP 067 M B01 0 1 35
516 Gr.70) construction. The condenser will be designed with 85% cleanliness
factor. The hot well storage capacity will be minimum 3 minutes between normal
and low level at MCR condition.
6.9. MAIN TECHNICAL PARAMETERS OF STEAM TURBINE
(A) At 100 % TMCR Condition
Parameter Unit Value
Power at generator terminal kW 60,000
Main Steam Pressure at Turbine inlet Ata 98
Main Steam Temperature at Turbine inlet OC 535
Main Steam Flow at Turbine inlet TPH 224
Main steam requirement for auxiliaries TPH 0.5
Exhaust steam pressure Ata 0.1
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Main Steam Pressure at Turbine inlet Ata 98
Main Steam Temperature at Turbine inlet OC 535
Main Steam Flow at Turbine inlet TPH 219
Main steam requirement for auxiliaries TPH 0.5
Exhaust steam pressure Ata 0.1
Exhaust flow TPH 166.33
(D) At Both HP Heaters out Condi tion
Parameter Unit Value
Power at generator terminal kW 60,000
Main Steam Pressure at Turbine inlet Ata 98
Main Steam Temperature at Turbine inlet OC 535
Main Steam Flow at Turbine inlet TPH 210.6
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(F) At 80 % TMCR Condition
Parameter Unit Value
Power at generator terminal kW 48,000
Main Steam Pressure at Turbine inlet Ata 98
Main Steam Temperature at Turbine inlet OC 535
Main Steam Flow at Turbine inlet TPH 180.8
Main steam requirement for auxiliaries TPH 0.5
Exhaust steam pressure Ata 0.1
Exhaust flow TPH 132
(G) At 50 % TMCR Condi tion
Parameter Unit Value
Power at generator terminal kW 30,000
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MECHANICALPP 067 M B01 0 1 38
Sl.No.
Parameters Unit Value
1.0 Capacity
1.1Maximum Continuous Rating [BMCR]
at main steam stop valveTPH 240
2.0 Pressure
2.1Steam Pressure at main steam Stopvalve outlet
Kg/cm2(a) 101
3.0 Temperature
3.1 Steam temperature at main steamStop valve outlet.
C 540 5
3.2Steam temp. control range for designperformance fuel
% MCR 60% MCR -100% MCR
3.3Feed water temperature at Deaeratoroutlet
C 158
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MECHANICALPP 067 M B01 0 1 39
3. 100 % Washery rejects.
The boiler is designed and manufactured as per Indian Boiler Regulations
(IBR) codes. All the requirement of IBR will be taken care for safe operation of
boiler. The pressure part materials will be as per IBR codes and standard. Piping
design will be as per IBR / ASME B31.1 (latest addition). The calculations of all
pressure parts will be submitted to the Chief Inspector of Boilers for their approval.
Major boiler parts can be described as Pressure retaining parts (steam and
water circuit), Bunker and fuel feeding equipments, Air-preheater and air ducting
component, Flue gas system, Boiler supporting structure and platforms, Hoppersand fly ash system.
The complete furnace section will be of fusion welded wall type arranged as
a gas and pressure tight envelope. The circulation system will be complete with
the necessary number of down comers, supply and riser tubes piping. Steam
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pressure. The boiler is provided with necessary access platform, galleries and
stair case to approach all equipments and pressure part. The boiler top is well
enclosed by canopy with side sheeting / lovers up to drum level. The required
structural supporting steelwork for the boiler, galleries, staircases and outer casing
will be provided for the boiler, auxiliaries, ducting etc.
The boiler has been provided with three storage bunkers for application of
coal (as a main fuel), lime stone (an additive) and bed material.
The fuel feeding system will consist of drag chain feeders and fuel feed
lines. The fluidised bed is located at the bottom most part of the furnace.
The boiler will be provided with two nos. (2 x 60% MCR) ID, SA and PA
fans and the complete air and gas ducting with required dampers and expansion
joints. All the fans will be provided with variable speed fluid coupling.
The feed water system will consist of three (3) nos (3 x 100 %) motor
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7.2.2. STEAM DRUM
Steam drum will be of welded construction, completely radiographed to
prove weld soundness, stress relieved and hydraulically tested. The boiler quality
plate for the drums will be fabricated to the appropriate specification and
constructed in accordance with the codes and regulations of Indian Boiler
Regulations.
Drum will be provided with suitable hemispherical dished ends and
manholes, each with a swing type cover opening internally.
The steam drum will be of fusion welded construction, with material
specification conforming to SA 516 Gr. 70. The steam drum will have nozzles for
saturated steam supply pipes to Primary super heater inlet headers, Feed water
inlet piping from economiser, water level gauges, pressure gauges, continuous
blow-down and intermittent blow down, chemical injection, sampling, air vent etc.
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Beams are supported by bolts through water cooled roof.
7.2.3.2. Divisional Wall
Divisional wall is placed in the furnace. Divisional wall is of carbon steel
construction and is a water cooled part of the boilers. This is located in the furnace
and helps is achieving / maintaining the combustor temperature.
7.2.3.3. Headers
The headers will be of adequate size and design in accordance with Indian
Boiler Regulations, and the material specification will conform to SA 106
Gr. B / SA 335 Gr. P11 / SA 335 Gr. P22 depending on the fluid temperature. The
necessary drain connections and hand-holes will be provided as required.
The connections to the steam drum and the connections to the headers will
be designed so as to form an integral circuit providing adequate natural circulation
under all operating conditions
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water line before the feed water control station.
7.2.6. ECONOMISER
The economiser will be made of bare carbon steel tubes conforming to SA
210 Gr A1 seamless and of continuous inline type with inlet and outlet headers. Itwill be supported in a structural steel frame and enclosed within welded steel
casing. Doors will be provided for observation and also access for maintenance.
The economiser will be of non-steaming type. Temperature of economiser shall
always below the saturated steam temperature.
Necessary drains, vents, temperature, pressure gauges, etc. shall be
furnished as per Indian Boiler Regulation requirement.
7.3. BOILER PERFORMANCE DATA
7.3.1. PRESSURE PART DETAILS
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MECHANICALPP 067 M B01 0 1 44
Tube OD mm 44.45
Tube thickness mmAs per IBR calculation.
Min. 4.06
Tube material SA213 GR. T22 / SA213GR. T11 / SA210 GR. A1
Header size NB 200 / 250
Header thickness mmAs per IBR code
calculation.
Header material SA 106 GR.B / SA 335GR. P11
Secondary Superheater
Descript ion Unit Value
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Tube material SA210 GR. A1
Header size NB 200
Header thickness mm As per IBR calculation.
Header material SA 106 GR.B
At temperator
Descript ion Unit Value
Header size NB 200 / 250
Header thickness mm As per IBR calculation.
Header material SA106 GR.B
Risers
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MECHANICALPP 067 M B01 0 1 46
2 Economiser m2 3561
3 Airpreheater ( PA + SA ) m2 10003
4Furnace (water walls +enclosure walls + divisionalwalls etc.)
m2 1441
7.3.3. TEMPERATURE GRADIENT
Sl. No. Description Unit Value
1 Combustion air side
1.1 Air pre heater In Deg. C 35
1.2 Air pre heater out Deg. C 140-150
2 Flue gas temperatures
2.1 Super heater In Deg. C 800-820
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MECHANICALPP 067 M B01 0 1 47
3.8 Sec. Super heater Out Deg. C 535-555
3.9 Spray water temperature Deg. C 220-230
4 Feed water temperature
4.1 Economizer In Deg. C 220-230
4.2 Economizer out Deg. C 290-310
7.3.4. PRESSURE GRADIENT
Sl. No. Description Unit Value
1 Steam / water side pressure drop
1.1 Sec superheater Kg/cm2 4.6
1.2 Pri superheater Kg/cm2 0.95
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MECHANICALPP 067 M B01 0 1 48
1.4 Airpreheater m/s 11-13
2 Air
2.1 Airpreheater m/s 10-12
7.3.6. SAFETY VALVE DETAILS
7.3.6.1. Safety Valve Set Pressures
Sl. No. Description Unit Value
1
1stdrum safety valve set
pressure Kg/cm2 (g) 119
2 2nddrum safety valve setpressure
Kg/cm2 (g) 120
3Superheater safety valveset pressure
Kg/cm2 (g) 108
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MECHANICALPP 067 M B01 0 1 49
1.2 ROM coal Kg/hr 51564
1.3 Washery rejects Kg/hr 88746
2 Limestone
2.1 Performance fuel case Kg/hr 4030
2.2 ROM coal Kg/hr 3430
2.3 Washery rejects Kg/hr 4780
3 Bed material Kg/hr Nil
7.4. BOILER MOUNTINGS AND FITTINGS
The Boiler will be provided with a complete set of mountings and fittings in
accordance with the Indian Boiler Regulations, for the safe operation of the Boiler
and the details of the mountings and fittings including:
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7.4.4. SUPERHEATER
-Safety valve (secondary outlet)
-Motor operated main steam stop valve with integral by-pass valve
-Steam outlet check valve
-Start-up vent will be sized for 30% of BMCR capacity.
-Pressure gauges with isolation valves and drain valves
-Sampling valves
-Drain valves
-Air vent valves
-Valves for pressure transmitters and flow transmitters
-Main steam flow nozzle
-Thermocouples
7.4.5. SPRAY WATER LINE
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100 % ROM Coal.
100 % Washery rejects.
7.5.1. FUEL BUNKER
Each boiler will be provided with following bunker of mild steel construction.
Fuel bunker 1600 m3
Lime stone silo 120 m3
Bed material silo 80 m3
Fuel Bunker sizing basis
Sl.No.
Description Basis ofDesign
Consumptionof Material perBoi ler, TPH
BunkerCapacityRequired,m3
BunkerVolumeProvided,m3
a) Fuel bunker 50 % WasheryRejects + 50
Consumption offuel at 100%
64.42 TPHx 16 Hrs /
1600 m3(Bunker
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For each boiler there are separate bunkers. Fuel is fed into drag chain
feeder. The drag chain feeder speed is controlled through VFD. The outlet of drag
chain feeder is connected to the furnace.
7.5.3. FLUIDIZED BED
The fluidised bed will consist of compartments (sections). Each
compartment will be provided with stainless steel fuel feeding nozzles and
adequate number of stainless steel fluidizing air nozzles fitted on to the distributor
plate.
7.6. OIL FIRING SYSTEM
Three (3) nos. of burners will be installed in the front side of the furnace
panel. Burner will be used for start-up of the boiler. Burner support will be required
till 20% of boiler loading. Each Burner will be 1500 litre capacity and combined
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guard. The impeller is provided with tip liners and dynamically
balanced. ID fan will be with inlet damper (multilouver) control. ID fan
shall be with variable speed fluid coupling.
Two (2) Secondary Air (SA) fan of 60% boiler MCR capacity supplying
the necessary amount of combustion air for fluidised bed combustion of
the different fuels with sufficient pressure to overcome the resistance of
ducts, measuring devices, dampers, fluidising air nozzles, air heater
and burners. The SA fan is centrifugal type with suitably sized impeller.
The fan impeller shall be dynamically balanced and is complete with
inspection door, foundation bolts and guard. The SA fan shall be
provided with silencer to meet the noise level. The control shall be
through Inlet Guide vane. SA fan shall be with variable speed fluid
coupling.
Two (2) Primary Air (PA) fan of 60% boiler MCR capacity boosting hot
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d) Ambient temp. C 50 35 35 35
e) Back end temp. C 160 140 140 140
f) ID fan gas Qty kg/s 56.42 52.27 56.42 49.46
g)Margin onCapacity
% 20
h) ID fan Capacity kg/s 67.7
II) Head Details
a) dP SH mmWC 15 12 15 12
b) dP economiser mmWC 20 17 20 15
c) dP APH mmWC 60 50 60 44
d) dP ESP + MDC+ U Beam
mmWC 140 117 140 101
e)dP Ducts +Dampers
mmWC 25 21 25 20
f) Chi WC 10 8 10 8
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h) SA fan Capacity kg/s 19.78
II) Head Details
a) dP Bed mmWC 430 430 388 421
b) dP flowmeasuring +OFA + Duct andDamper +Silencer
mmWC 560 533 560 522
c) dP APH mmWC 50 47 50 47
d) Total dP mmWC 1040 1010 1000 990
e) Margin on head
(only on variablehead)
% 45
f) SA fan Head mmWC 1375
C) PA Fan ( 2 X 60 % MCR)
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Silencer + Ductand Damper
c) dP APH mmWC 60 54 60 53
d) dP bubble cap mmWC 400 360 400 351
e) Total dP mmWC 1585 1440 1460 1420
f) Margin on head
(only on variablehead)
% 45
g) SA fan Head mmWC 1920
7.7.2. DUCTWORK AND DAMPERS
Ducts will be sized considering a maximum velocity of 14 m/sec for air and
12 m/sec upto Air Pre-heater & 16 m/sec after Air Pre-heater for flue gas
applications. The ducts will be rectangular in cross section and will be of welded
construction, properly stiffened and reinforced. All ducts handling air and flue gas
will be fabricated with carbon steel plates of thickness not less than 5 mm for air
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7.7.3. AIR PRE-HEATER
A tubular air pre-heater is provided as the last stage of heat recovery unit.
The shell and tube side fluid shall be combustion air and flue gas respectively.
The air pre heater tubes shall be fitted into the tube sheets on both sides. Entire
Air Pre-heater shall be supported in a structural steel frame and enclosed within
welded steel casing. Air Pre-heater shall be provided with BS 6323 / 82 Part V ERW
tubes.
The clean air passes through tubes and those tubes are surrounded by hot
flue gases which help to increase the temperature of air. This hot air is used in
boiler to help combustion process.
7.7.4. ASH RECYCLE SYSTEM
Mechanical Dust Collector (MDC) is positioned in the exit of Economiser.
Th h ll t d i th MDC ill b l d th h th
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7.8. BOILER STRUCTURES AND AUXILIARIES
7.8.1. STRUCTURAL STEEL
The complete structural steel necessary to support/suspend the various
components and equipment, ducts etc. will include all auxiliary columns, duct
supporting columns, bracing, and all equipment structures etc. The structure is of
fully welded construction. Only for erection purpose, erection bolts are provided.
All structural steel will be designed for horizontal seismic forces as applicable
under the latest Revision of IS 1893 and wind forces as per latest revision of IS
875, whichever governs the design. All structural steel work will be designed as
per IS 800 and material specification conforming to IS 2062. The structure will
incorporate necessary lifting beams and hoist blocks required for maintenance of
fans, pumps etc.
7.8.2. PLATFORM,STAIRWAYS AND GRATING
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7.9.2. DESIGN TEMPERATURE DIFFERENTIAL -CRITERIA
The thickness of wool mattress will be calculated such that insulation
surface temperature shall remain within 65OC at an ambient temperature 35OC
with 1 m/s wind velocity. Insulation will be provided for equipment and ducts
where the temperature exceeds 60OC.
7.9.3. EXTERNAL INSULATION
The machine made mineral wool mattresses will be used as external
insulating layer and will have a uniform density of 120 kg/m3. The mineral wool
specifications and thermal conductivity figures will be as per IS: 8183.
The wire netting to be provided on both sides of mattresses will be of GI /
SS material.
7.9.4. BINDING AND STITCHING WIRE
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etc.
7.11. SAMPLING LINES
The sampling lines and sample coolers will be provided for feed water,
drum water, saturated steam and superheated steam. Sampling lines andnozzles will be of suitable material to take care of high chloride content in
circulating water.
7.12. BLOW DOWN TANKS
One (1) continuous blow down (CBD) tank and one (1) intermittent blow
down (IBD) tank of appropriate capacity, separate for each boiler, shall be
provided to receive all the continuous and intermittent blow downs and all other
drain discharges from the boilers. Necessary level control station for the
continuous blow down tank along with other fittings shall be provided.
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MECHANICALPP 067 M B01 0 1 61
1 Design flue gas flow m3/sec 124 134 117
2 Flue gas temperature oC 140 140 140
3 Gas Analysis (wet)
CO2 % v./v. 13.31 12.62 13.70
H2O % v./v. 14.07 16.16 12.87
N2 % v./v. 69.54 68.20 70.32
O2 % v./v. 3.06 3.00 3.1
SO2 % v./v. 0.0064 0.0074 0.0056
4Gas density (wetbasis)
Kg/Nm3 1.2875 1.2732 1.2957
5 Dust concentration atESP inlet (wet)
gm/Nm3 70 70 70
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Stack emission shall be monitored to satisfy the requirements of Orissa Pollution
Control Board.
The design data for the chimney shall be as per the table below :
7.14.1. CALCULATION OF CHIMNEY HEIGHT
Sl. No. Particulars Units Value
1 Coal Consumption per Boiler Kg/Hr 64420
2 Sulphur Percentage % 0.34
3 Total Sulphur from Fuel Kg/Hr 219.0
4 Percentage Sulphur capture % 89.65 Sulphur at Stack Kg/Hr 22.7
6 SO2 From Fuel Combustion Kg/Hr 45.5
7 Stack height required m 44.0
7.14.2. CALCULATION OF CHIMNEY DIAMETER
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7.14.3. SKETCH OF CHIMNEY
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Following tapping point will be provided in main steam line
a. For steam jet air ejector and turbine gland auxiliary PRDS.
b. For turbine bypass system (sized for 60% TMCR flow).
c. For deaerator pegging steam line.
Suitable drain and vent connections shall be provided between
isolation valves of each boiler in line with IBR requirements. These
drain / vent isolation valves shall be manually operated.
Each boiler superheater outlet would be provided with superheater
safety valve and electromatic relief valve for over-pressure protection
of boiler superheater. Start-up vent valveof 30% BMCR flow capacity
is also provided.
(B) Auxiliary steam system for steam jet air ejector & turb ine gland
sealing steam system
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(D) MP steam system for Deaerator
From steam turbine, 3rd bleed with pressure around 6.6 kg/cm2 (a) will
be taken for deaerator. This line will be provided with pneumatic
operated quick closing non-return valve (QCNRV), normal non-return
valve and motor operated valve. Pegging steam line from main steam
will also be connected to this bleed line through a PRDS station for
pegging of deaerator during start-up and low load.
(E) LP steam system for LP heater
Two (2) nos. low pressure bleeds with pressure at around 2.5 kg/cm2
(a) & 0.735 kg/cm2 (a) will be taken for LP heaters. These lines will be
provided with pneumatic operated quick closing non-return valve
(QCNRV) and motor operated valve except low pressure line which will
be provided with normal non-return valve.
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vents shall be provided with manually operated double isolation valves.
8.1.1. CONTROL PHILOSOPHY
Steam Temperature & pressure will be maintained by combustion control
loop and attemperator in the respective boiler. The control range for temperature,
as indicated earlier, is 60 100 % for the individual boilers for 100% coal firing. In
the event of load throw-off, the main steam line pressure will tend to increase
which will activate turbine bypass control valve and excess steam (maximum 60%
of TMCR) will be bypassed to surface condenser. At the same time the
combustion control loop of boiler will also activate and once the same is stabilised
turbine bypass system will close.
8.2. FEED WATER SYSTEM
The feed water system will supply feed water to each boiler. It will also
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The deaerator-cum-storage tank unit will be complete with necessary
internal trays, water sprays, water level control system, temperature control
system, safety valve, water level indicator and alarm, access ladders and
platforms.
Chemical dosing would be performed inside the deaerator by means of
sparger pipe inside the storage tank.
Steam for heating will be supplied from the extraction of steam turbine.
Provision will also be made for supply of steam from the main steam line through
a system of pressure reducing valve and utilising flash steam from continuous
blow-down tank. The oxygen content on the outlet water will be not more than
0.007 ppm.
Details of Deaerator & Feed water storage tank is as follows.
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8.2.2. BOILER FEED PUMPS
Boiler feed water pumping system with 3 x 100% motor driven boiler feed
water pumps is provided. Out of these three pumps, one will be operating
normally for each boiler unit while the third pump shall remain as a common
standby and will come into operation automatically in case one of the working
pump fails.
Variable speed hydraulic coupling is provided to vary the speed of the feed
pump smoothly and stably over the entire range to minimise the throttling losses in
feed control valves.
Three (3) nos. motor driven boiler feed pumps with all pipe works and
valves will be supplied for the boilers. The pumps will be identical and
interchangeable. The pump will be of multistage centrifugal type, complete with
suction strainer, balance chamber and necessary suction and delivery valves,
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margin will be provided on head calculated based on 2nd drum safety valve set
pressure. With such margin, it shall be checked and ensured that even at 47.5 Hz
frequency the boiler feed water pump is capable of delivering 100 % TMCR flow
rate and required head during TMCR operation of unit. The BFP sizing basis is as
follows.
a) Pump Capacity Calculation
Feed water flow at BMCR240 TPH
As per boiler datasheet
Feed water density at 158Ctemperature
909.4 kg/m3 As per HBD
MCR volume flow 263.9 m3/hr
MCR volume flow with 3% make-up 271.8 m3/hr
Margin 10% 27.2 m3/hr
C l l d fl 299 3/h
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Suction pressure (H) 7.8 kg/cm2 (a)As per HBD &prelim. equipmentlayout
Required TDH in water column (G-H/ density)
1375 mWC
Required Rated Head (includingMargin 5%)
1444 mWC
Selected Rated Head 1495 mWC
8.2.3. HPFEED WATER HEATERS
Two (2) nos. HP heaters will be located on the down stream side of boilerfeed pumps and will be used for raising the boiler feed water temperature to
230oC. The HP heater shall be mounted vertically in the turbine house. The
heating steam for the HP heaters shall be supplied from the high pressure turbine
bleeds. The normal condensate drain from the HP heater shall cascaded back to
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% capacity pneumatically operated control valve is provided to control the feed
water flow at low load. Full load control valve shall be operated through single
element or three element control mode. Low load control valve shall be operated
in single element mode. The upstream isolation valves for the control stations are
motorised for automatic changeover.
In order to avoid excessive throttling and power loss at feed control station,
the differential pressure across feed control valves under steady state shall be
maintained at a constant value by varying hydraulic coupling of boiler feed pump.
HP heater shell side level is maintained by a control station leading the
condensate to the earlier HP heater or deaerator. In case of deaerator high level
or at low load & starting, this condensate will be diverted to the HP flash tank
through another control station.
In case of very high level in the shell, extraction steam line motorised valve
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cooled surface condenser. Drain condensate from LP heaters, GSC and inter-
after ejector condensers are taken to the flash pipe of the condenser.
8.3.1. SURFACE CONDENSER
The condenser shall condense all the steam at the steam turbine exhaust,
and shall receive all the condensate from the steam jet ejector condensers, gland
steam condenser and LP heaters. At an emergency condition of very high level in
HP heater, the condensate drain will be diverted to condenser through HP flash
tank instead of the deaerator. A flash pipe mounted near the condenser will
receive all the drains. The vent and drain from the HP flash tank and flash pipe will
be connected to the shell and hotwell of the condenser respectively.
The condenser shall be designed as per Heat Exchanger Institute (HEI)
standard for surface condensers.
The condenser shall be of horizontal two-pass type and shall be so
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maintenance. Condenser (tube side) shall be hydro-statically tested according to
the Heat Exchange Institute Standards.
Condenser water box shell shall be of carbon steel (SA 516 Gr. 70)
material. Condenser tube sheet shall be of carbon steel (SA 516 Gr. 70) material.
Suitable drain and vent connections complete with necessary valve shall be
provided for all the water boxes to obtain a smooth flow path in the water boxes
and even water distribution to the tubes and to avoid any unvented air pockets.
The condenser shall be provided with a hotwell made of carbon steel (SA
516 Gr. 70) having a total storage capacity of at least three (3) minutes of the totaldesign condensate flow (between normal and low level) at maximum steam load
condition. The hotwell shall be provided with suitable access doors. Drain valves
with blind flanges shall be provided on hotwell.
A rupture disc designed as per manufacturers standard shall be provided
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Cooling water temperature(inlet / outlet)
33 C / 42 C
Cleanliness factor 85 %
Plugging margin 3 %
Condenser heat load
(corresponding to VWOoperation)
87142367 Kcal/hr
Surface area 4900 m2
Hotwell capacity 3 minutes storage of the totaldesign condensate flow betweennormal level to low level atmaximum steam load condition
Material of Construction :
Shell Carbon steel (SA 516 Gr. 70)
Tube sheet Carbon steel (SA 516 Gr. 70)
Hot-well Carbon steel (SA 516 Gr. 70)
T b St i l t l (SS 304)
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condenser are provided. Each service air ejector is of two stages with an inter-
condenser between the Ist and IInd stage and an after-condenser located after
the IInd stage. The condensate from the inter-condenser and after-condenser is
led to the main condenser through a loop seal and trap station respectively.
Condensate from the CEP discharge passes through the tube side of the inter and
after-condensers.
The following are the brief details of the Ejectors: -
No. of ejectors Service - Two (1 W + 1 S)
Start up One (1)
Design CalculationsStandard
HEI
Location Indoor
Medium to be handledMixture of air, steam and non-condensable gases
C li M di C d t
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Condenser hotwell level is very low.
Motor is overloaded.
The standby pump will come on auto if:
Running pump trips.
Discharge header pressure drops below a predetermined value as sensed
by a pressure switch.
In order to prevent the operation of the CEP on shut off head and to ensure
minimum flow through the inter/after ejector condenser and gland steam
condenser, a minimum flow recirculation facility is provided for the CEP. This
consists of a control valve and CEP discharge flow transmitter. The recirculation
flow is routed back to the condenser hotwell.
The condensate outlet from the CEP is routed to the deaerator after
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b) Pump Head Calculation
Deaerator safety valve setpressure (A)
8 kg/cm2 (a)As per deaeratordata sheet
Pressure drop at deaeratorspray water nozzle (B)
0.75 kg/cm2As per deaeratordata sheet
Pressure drop in Piping (C) 0.4 kg/cm2As per prelim.piping layout
Pressure drop across flownozzle (D)
0.2 kg/cm2 Estimated
Pressure drop in LP heaters (E) 1.6 kg/cm2 As per LP heaterdata sheet
Pressure drop in ejectorcondenser (F)
0.5 kg/cm2 As per ejector datasheet
Pressure drop GSC (G) 0.5 kg/cm2 As per GSC data
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8.3.4. LPFEED WATER HEATERS
The LP heaters will be located on the down stream side of condensate
extraction pumps after gland steam condenser and will be used for raising the
condensate water temperature to 123C. The LP heater shall be mounted
vertically in the turbine house. The heating steam for the LP heater shall besupplied from the low pressure turbine bleeds. The normal condensate drain from
the LP heater shall be cascaded back to earlier LP heater and then to the
condenser. An emergency condensate drain of LP heater 1 is also provided
directly to the condenser flash pipe. The condensate water side of the LP heater
shall be designed to withstand the CEP shut-off pressure. The steam side of theLP heater shall be designed to suit the highest bleed steam pressure obtainable.
The condensate water outlet from LP heater will be connected to the deaerator
through level control station.
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Cooling media Condensate
8.3.6. MAKE-UP WATER
The normal DM water make up to the power cycle shall account for the loss
of water from the system due to blowdown from the boilers (considered @ 1 %normal & 3 % maximum), loss of steam from service air ejectors, deaerator losses
and leakage of water from the system. DM water from DM water storage tank will
be transferred to overhead condensate storage tank (CST) by DM water transfer
pumps. Make-up for above losses is provided in condenser hotwell through gravity
from this CST through a control valve. The control valve will be sized for 3 %make-up water requirement.
8.3.7. CONTROL PHILOSOPHY
Condenser hotwell level shall be maintained by regulating condensate flow
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9. WATER SYSTEM
9.1. PLANT WATER SYSTEM
9.1.1. RAW WATER SYSTEM &RAW WATER RESERVOIR
Water from Mahanadi river will be pumped by means of raw water intake
pumps to the raw water reservoir. The raw intake pumps and piping upto raw
water reservoir are in Owners scope. The EPC contractors scope starts from the
raw water reservoir.
Raw Water Reservoir, for collection and storage of raw water, of total
capacity 10,000 m3 in two (2) compartments along with gates and accessories
shall be provided. Inside and bottom surface shall be lined with impermeable
HDPE lining of thickness 1 mm. Design and construction of the reservoir shall be
done in such a fashion that no water can escape from the reservoir through
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9.1.2. RAW WATER PRE-TREATMENT PLANT &CLARIFIED WATER TANK
The water pre-treatment plant mainly comprises of cascade aeration cum
stilling chamber (1 x 100 %), inlet channel with parshall flume (1 x 100 %), flash
mixture (1 x 100 %), flocculation tank (1 x 100 %), Klari-tube settlers (2 x 100 %),
sludge sump (1 x 100 %) and sludge transfer pumps (2 x 100 %).
Various chemical preparation and injection systems in the raw water pre-
treatment plant shall be designed generally based on the following guidelines:
Alum : 60 ppm
Polyelectrolyte : 1 ppm
Sodium
Hypochlorite
: Equivalent to 5 ppm chlorine
Chemical house to accommodate chlorination system, storage space for
chemicals, chemical solution preparation tanks, dosing pumps, MCC, Control
Room etc and all other accessories shall be provided
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Clarified water pump house will also house fire water pumps. A dead
capacity, as per the requirement of TAC, to supply firewater in case of emergency,
will be kept below the minimum submergence level of clarified water storage tank.
The clarified water storage tank shall meet the entire water requirement of
the various power plant consumers like DM water, cooling tower make-up water,service water, potable water, fire water etc. The water balance diagram showing
the water requirement by various consumers is attached in Annexure-II.
9.1.3. MAIN COOLING TOWER MAKE-UP SYSTEM
Make-up water needs to be supplied to the main cooling tower to recover
the water lost in CT blowdown, evaporation & drift losses and SSF backwashing.
This make-up water to main cooling tower is supplied by 2 x 100 % main CT make
up pumps from the clarified water storage tank.
The main cooling water make-up requirement has been calculated as
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Capacity of pumps with 10% Margin : 380 m3/hr
9.1.4. DMFEED-CUM-AUXILIARY COOLING TOWER MAKE-UP SYSTEM
Make-up water needs to be supplied to the auxiliary cooling tower to
recover the water lost in CT blowdown and evaporation & drift losses. This make-
up water to auxiliary cooling tower is supplied by 3 x 50 % DM feed-cum-auxiliary
CT make up pumps. A tapping is taken after dual media filter header to supply a
better quality filtered water as a make-up to auxiliary cooling tower.
The auxiliary cooling water make-up requirement has been calculated as
follows:
Auxiliary cooling water requirement for the
auxiliary coolers
: 1,976 m3/hr
Cooling Range (from 40C to 33C) : 7 deg C
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potable water + filter backwash water
= 29 + 20.25 + 3 + 1.25
= 53.5 m3/hr
Number of DM feed-cum-auxiliary CT makepumps & DMF : 3 x 50 %
Capacity of DM feed-cum-auxiliary CT makepumps & DMF with 10% Margin : 30 m3/hr
9.1.5. DEMINERALIZATION WATER SYSTEM
The filtered water from DMF is fed to a DM Plant (2 x 25 m3/hr capacity) to
generate boiler quality water. A tapping is taken after duel media filters to store
filtered water in a filtered water storage tank of capacity 40 m3. Potable water (3
m3/hr) and backwashing water for DMF (1.25 m3/hr) will be fed from this filtered
water storage tank.
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Bed (MB) exchanger. Acid and alkali measuring tanks (common to both streams)
with ejectors shall form part of the system to provide these chemicals for
regeneration. Hydrochloric acid and sodium hydroxide shall be the chemicals
used for this purpose.
The DM Plant shall be designed to operate continuously for 18 hoursbefore regeneration of the exhausted resin in the ion exchangers. The
regeneration of the exchangers shall be completed in a maximum period of 6
hours. Regeneration water heater for regeneration of anion resins will be
provided.
The waste from the regenerated waste of DM plant shall be collected in
drain pits near the vessels and routed through acid/alkali proof lined trenches to a
neutralizing pit. Acid or alkali as required shall be dosed in this pit and the effluent
shall be neutralized by recirculation before being pumped to the guard pond.
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shall also be provided.
Design quality of treated water at the DM Plant outlet shall be maintained
with silica content maximum : 0.02 ppm and conductivity not to exceed 0.1
micromho/cm.
9.1.6. DMWATER DISTRIBUTION SYSTEM
DM Water from the DM water storage tanks shall be pumped by 2 x 100%
DM transfer (power cycle make-up) pumps of capacity 17 m/hr (with 10 % margin
on cycle make-up water requirement i.e. 15.4 m/hr). Power cycle make-up pumps
shall be located outdoor near the DM water storage tank. The DM water shall be
stored in the Condensate Storage Tank (CST). The CST tank shall be horizontal
cylindrical steel tank with capacity sufficient to hold 3% make-up water
requirement of two (2) hours i.e. 30 m. The tank shall be designed as per IS:803
and provided with inlet, outlet, drain, overflow and vent connections. Power cycle
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Type of pump Horizontal centrifugal
Location of pumps Near clarified water tank
Capacity of each service water tank m 1 or 2 (as required)
Selected pump capacity with margin m/hr 6
Location of tank STG Building, DM plant
building, Pre-treatmentplant building, ESPcontrol room-cum-compressor house, Ashhandling area etc.
Distribution of service water from tank By gravity
9.1.8. POTABLE WATER SYSTEM
A tapping is taken after Duel media filters to store a filtered water in a
filtered water storage tank of capacity 40 m3. The potable water treatment further
comprises of dosing with sodium hypochlorite for chlorination. Two (2) nos. pumps
f it 3 3/h h h ll b id d t t t bl t i t t
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house, Administrativebuilding, Medical building,canteen, store, workshopetc.
Distribution of potable water from potablewater tank
By gravity
9.2. COOLING WATER SYSTEM
9.2.1. MAIN COOLING WATER SYSTEM FOR CONDENSER
9.2.1.1. System Description
The main cooling water system will be used to cool the circulating water
used for condensing steam in the surface condenser.
Main cooling water system for surface condenser will be closed cycle
cooling system employing a cooling tower common for two units, cooling water
pumping system, CW treatment system and associated piping & valves.
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will be vertical turbine type pumps located in a pump house at the end of the fore
bay. There will be a total of three (3) number of CW pumps, one will be working
for each unit and the third will remain as common stand by. Overhead EOT c