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FICHTNER India
DESIGN GUIDES CONTENTS
APPROVED BY : DEPARTMENT : MECHANICAL DATE : 02/06/99 PAGE : 1
of 2
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GUIDE CONTENT.doc
Sl. No.
W.I. No. Rev. Description Date of Issue
1. WI-ME-DSN-100-001 R-1 LHV, HHV Calculations Fuel Oil
11/04/98
2. WI-ME-DSN-100-002 R-1 Flue Gas Dew Point Calculations
11/04/98
3. WI-ME-DSN-100-003 R-1 Fan Power Calculations 11/04/98
4. WI-ME-DSN-100-004 R-1 Oil Heater Steam Requirement
Calculations
11/04/98
5. WI-ME-DSN-100-005 R-1 LHV, HHV Calculations Coal 11/04/98
6. WI-ME-DSN-100-006 R-1 LHV, HHV Calculations Gaseous fuel
(Natural Gas)
11/04/98
7. WI-ME-DSN-100-007 R-1 Stoichometric Air Reqt. Solid and
Liquid Fuels
11/04/98
8. WI-ME-DSN-100-008 R-1 Recommended feed water & boiler
water quality for power plant application
11/04/98
9. WI-ME-DSN-100-009 R-1 Boiler Blow Down Calculations
11/04/98
10. WI-ME-DSN-100-010 R-1 Chimney Sizing 11/04/98
11. WI-ME-DSN-100-011 R-1 Emission / Ambient air quality
calculations
11/04/98
12. WI-ME-DSN-103-001 R-1 Ash handling system Typical write up
11/04/98
13. WI-ME-DSN-108-001 R-1 Raw Water Analysis Conversion factors
for Ionic loads
11/04/98
14. WI-ME-DSN-108-002 R-1 Raw Water Analysis Format 11/04/98
15. WI-ME-DSN-122-001 R-1 Cooling Tower Blow Down Evaporation
& Drift Loss Calculations
11/04/98
16. WI-ME-DSN-123-001 R-1 Horizontal pump Vs Typical write up
vertical pump
11/04/98
17. WI-ME-DSN-124-001 R-1 Merits / Demerits of Plate Type Heat
Exchanger
11/04/98
18. WI-ME-DSN-126-001 R-1 Water Cooled Condenser Sizing
11/04/98
19. WI-ME-DSN-126-002 R-1 Air Cooled Heat Exchanger /
condenser
11/04/98
20 WI-ME-DSN-166-001 R-0 Guidelines on Basic Aspects for Fire
Protection System
02/06/99
21. WI-ME-DSN-180-001 R-0 Standard tank size and weight chart
13/04/98
22. WI-ME-DSN-180-002 R-0 Tank cost estimates 13/04/98
23. WI-ME-DSN-180-003 R-0 Heating coil size calculation for
storage tanks
13/04/98
24. WI-ME-DSN-180-004 R-0 Heat loss calculation for vertical
cylindrical storage tank
13/04/98
25. WI-ME-DSN-196-001 R-1 Insulation Thickness Calculations
11/04/98
26. WI-ME-DSN-196-002 R-1 Steam Trap Selection 11/04/98
27. WI-ME-DSN-196-003 R-1 Pressure Temperature Rating
11/04/98
28. WI-ME-DSN-196-004 R-0 Standard flange dimension data
13/04/98
29. WI-ME-DSN-196-005 R-1 Weld Joint Quantity Calculation
11/04/98
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FICHTNER India
DESIGN GUIDES CONTENTS
APPROVED BY : DEPARTMENT : MECHANICAL DATE : 02/06/99 PAGE : 2
of 2
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GUIDE CONTENT.doc
Sl. No.
W.I. No. Rev. Description Date of Issue
30. WI-ME-DSN-196-006 R-1 LPT Quantity Calculations 11/04/98
31. WI-ME-DSN-196-007 R-1 Allowable Pipe Span 11/04/98
32. WI-ME-DSN-196-008 R-1 Scope of IBR Documentation-A Guide
Line
11/04/98
33. WI-ME-DSN-196-009 R-1 Mild Steel Pipe - Size Dimension &
Weight
11/04/98
34. WI-ME-DSN-196-010 R-1 Seamless or Electrically Welded Steel
Tubes / Pipes IS 3589
11/04/98
35. WI-ME-DSN-196-011 R-1 Pipe Thickness Calculation (IBR Ready
Reckoner)
11/04/98
36. WI-ME-DSN-196-012 R-0 Pipe sizing calculation Steam service
13/04/98
37. WI-ME-DSN-196-013 R-0 Pipe sizing calculation Water service
13/04/98
38. WI-ME-DSN-196-014 R-0 Piping sizing calculation Air service
13/04/98
39. WI-ME-DSN-196-015 R-0 Allowable velocities in pipes
13/04/98
40. WI-ME-DSN-700-015 R-0 List of Calculation in EXCEL available
in Mechanical department
02/06/99
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DOC. NO. WI-ME-DSN-100-001 REV. NO. R-A PAGE 1 OF 1
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FORM T10 REV - A
LHV, HHV CALCULATIONS - FUEL OIL
Qv = 12,400 - 2100 d2 % H = 26 - 15d Qp = Qv - 50.45 X %H Where,
Qv = Higher heating value at constant volume in kcal/kg of oil,
free of
water, ash and sulphur, final products being Co2 gas + water. Qp
= Net Heat of combustion (LHV) at constant pressure (atm) in
kcal/kg -
free of water, ash and sulphur, final products being Co2 gas +
H2O (vapour)
%H = Percentage of Hydrogen in the Hydrocarbon fuel. d =
Specific gravity of the fuel at 60F. CORRECTION VALUES FOR WATER,
ASH AND SULPHUR CONTENT IN FUEL Qv = Qv - 0.01 Qv (%H2O + % ASH
+%S) + X(%S) Qp = Qp - 0.01 Qp (%H2O + % ASH + %S) + X(%S) - Y
(%H2O) Where Qv = Higher Heating Value at constant volume per unit
quantity of fuel oil
containing water, ash, sulphur. Final products being ash,
gaseous Co2, So2 and liquid water.
Qp = Net heat of combustion (LHV) at constant pressure per unit
quantity
of fuel oil containing water, ash and sulphur. Final products
being ash, gaseous Co2, So2 and H2O.
% Ash = percentage of ash determined by ASTM D-482. % H2O =
percentage of water determined by ASTM D-95. % S = percentage of
sulphur determined by ASTM D-129. X & Y are constants which
vary in value depending upon the units in which heating
value is reported.
UNIT X Y kcal/kg 22.5 5.85
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DOC. NO. WI-ME-DSN-100-002 REV. NO. R-A PAGE 1 OF 1
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GUIDE-FICHTNER\WI-ME-DSN-100-002.doc FORM T10 REV - A
FLUE GAS DEW POINT CALCULATIONS
Flue gas Dew point temperature is determined from the following
correlation : 1000 ------- = 1.7842 + 0.0269 * log(Pw) - 0.1031 *
log(PS03) + Tdp 0.0329 * log (Pw) * log (PSo3) Tdp = Flue gas dew
point temperature in k. Pw = Partial pressure of water vapour. PS03
= Partial pressure of sulphur tri-oxide. DEW POINT : Dew point is
the temperature at which an un-saturated gas vapour mixture
becomes
saturated as a result of iso-baric cooling at constant absolute
humidity. The dew point is also the saturation temperature
corresponding to the initial partial pressure of the vapour. If the
cooling proceeds further, both temperature and the absolute
humidity decrease and rapid condensation of water vapour takes
place.
EFFECT OF SULPHUR IN FUEL ON DEW POINT OF COMBUSTION GASES
Sulphur forms sulphur-di-oxide and a small but significant amount
of sulphur-tri-oxide,
when burnt. The sulphur tri-oxide that is formed can combine
with water vapour to form sulphuric acid. The sulphuric acid will
remain in the vapour state as long as the temperature of the
exhaust gas is above dew point of the gas. When in the vapour state
i.e above dew point it causes no corrosion.
If however, the temperature of stack gases is lowered below the
dew point, sulphuric
acid will condense out and cause corrosion of metal.
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DOC. NO. WI-ME-DSN-100-003 REV. NO. R-A PAGE 1 OF 2
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FORM T10 REV - A
FAN POWER CALCULATIONS
The Input Required for fan power calculations are : (i) Density
of the fluid (kg/m3), (ii) Flow rate of the fluid (m3/sec), Q (iii)
Head to be developed (mWC), H
(iv) Fan efficiency () (v) Accelaration due to gravity (m/sec2),
g Power of the fan drive motor Nmot, KW : m Q H g ------------ 1000
tr where m = 1.05 to 1.2 is the power reserve factor If the fan is
directly connected to the motor, the transmission efficiency tr = 1
for V - belt transmission tr = 0.92 The fan power consumption
depends on the gas quantity and the resistance through
the boiler gas passes which will be dependant on the particular
boiler design and the
range of fuels to be burned.
FAN SELECTION CRITERIA a) Capacity and Head In selecting a fan,
one is guided by the maximum capacity Q and head H required of
the fan as applied to a given air or gas duct work. A margin in
pressure and volume
over normal requirements is necessary to compensate for boiler
fouling, adverse
combustion conditions, poor fuel and to provide cover for
possible slight errors in the
estimates of draught system requirements. The margin is usually
about 20% for
volume and about 50% for system resistance. The cost of
providing margins in fan duty, is higher than for most other
items of plant owing to the
square law relating volume to pressure and to the cube law
relating volume to
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DOC. NO. WI-ME-DSN-100-003 REV. NO. R-A PAGE 2 OF 2
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FORM T10 REV - A
horsepower. If a 20% margin of volume capacity is required, the
pressure needed
would be about 1.5 times and the horsepower about 1.75 times the
requirements for
the net capacity. The penalty paid for excessive fan capacity is
therefore, severe both
in capital and operating costs.
b) Fan Speed The following is an illustration of the magnitude
of i-d fan power consumption
for one 500 MW boiler provided with two-speed i.d fans. To
handle the boiler C.M.R gas flow at the lower speed of 490 rev/min
each fan would require 1320 b.h.p. Changing to high speed at this
point closes the inlet vane gear and results in a reduction in fan
efficiency which would require an additional 200 b.h.p per fan.
With both i.d fans running at top speed at boiler C.M.R, an
additional 400 b.h.p is required and it can, therefore, be
appreciated that low speed operation should be used on all possible
occasions. In this instance, the rated i.e fan motor horse power to
cater for the fan design margins was 2290 b.h.p at 590 rev/min.
c) Density of the Fluid The capacity of the forced draft fans is
to be determined at the lowest density
condition prevailing at the site. For the same heat input to
boilers, the air quantity required in mass flow units
(kg/hr) remains the same irrespective of the ambient conditions.
W = 60 q where w = mass flow, kg/hr = density, kg/m3 q = Volumetric
flow, m3/hr Fans discharge constant volumetric flow at any density.
Hence if the fan is
sized to give a particular volumetric flow at the high density
condition, the mass flow would decrease when density decreases as
can be seen in the equation above. Hence the fan must be sized to
deliver the volumetric flow at the lowest density condition, in
which case the output will be higher at the higher density
condition, which can be then controlled.
Also, the gas pressure drop p in mmwc across the wind box is
proportional
to w2/l. If the air density decreases as at high-temperature
conditions, the pressure drop increases, because W remains
unchanged for a given heat input. Considering the fact that H/ is a
constant for a given fan, where H is the static head in mmwc, using
the lowest ensures that the head available at higher density will
be larger.
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FICHTNER India
DOC. NO. WI-ME-DSN-100-004 REV. NO. R-A PAGE 1 OF 3
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FORM T10 REV - A
OIL HEATER STEAM REQUIREMENT CALCULATIONS
a) Continuous steam requirement for Fuel Oil Tank Floor Heaters
1. Minimum temperature = tmin C 2. Temperature of oil which is to
be maintained in the fuel oil tank = t C 3. Heat transfer
coefficient between the tank surface and atmosphere = h kcal/hr/m2
C 4. Fuel oil tank dimensions Diameter = `D m. Height = `H m. 5.
Surface area of the tank = DH m2 6. Heat loss from the tank surface
to the atmosphere taking 10% margin (Hl) = h x A (t - tmin) x 1.1
7. Auxiliary steam parameters available are: Pressure = `p ata
Temperature = T C Enthalpy = Hs kcal/kg 8. Enthalpy of condensate
at outlet = Hc kcal/kg 9. Steam required for floor heater
for heating the tank = H
Hs Hckg hrl
( )/
b. Steam requirement for storage tank out flow Heater 1. Number
of heaters working at a time (Assumed one tank working at a time) =
one (1) 2. Fuel oil flow through heater = mfo
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DOC. NO. WI-ME-DSN-100-004 REV. NO. R-A PAGE 2 OF 3
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FORM T10 REV - A
3. Average temperature of fuel oil at the inlet to outflow
heater = t1 C 4. Temperature of the fuel at the outlet of outflow
heater = t2 C 5. Steam parameters available are Pressure = p kg/cm2
Temperature = T C Enthalpy = Hs kcal/kg. 6. Condensate enthalpy at
the outlet of the heater = Hc kcal/kg. 7. Specific heat of the fuel
oil = Cp kcal/kg C 8. Heat energy required for raising the
temperature of the oil = mfo * Cp * (t2 - t1) 9. Steam required for
the outflow
heater taking 10% margin = mfo Cp t t
Hs Hcx* * ( )
( ).2 1 11
C. Steam requirement for the steam coil air preheater 1. Heat
input to SG at BMCR = Q kcal/hr. 2. Coal required to give this
heat energy (mc) = Q
C V of coalkg hr
. ./
3. Coal required at 30% MCR (mc30) = mc * 0.3 kg/hr 4. The
theoretical air required for burning the coal (kg/kg of coal = ma
5. Actual air required (with 20% excess air) (mact) = 1.2 * ma
(kg/kg of coal) 6. Air required at 30% MCR (Ma) = mact x mc30
kg/hr
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FICHTNER India
DOC. NO. WI-ME-DSN-100-004 REV. NO. R-A PAGE 3 OF 3
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FORM T10 REV - A
7. Aux. Steam parameters Pressure = pata Temperature = T C
Enthalpy = Hs kcal/kg 8. Enthalpy of condensate at the outlet of
SCAPH = Hc kcal/kg 9. Minimum ambient air temperature (for the
design of SCAPH) = t1 C 10. Temperature to which the air is to be
raised = t2 C 11. Specific heat of air = Cpa kcal/kg C 12. Heat
energy required to raise air temperature to t2C = Ma * Cpa * (t2 -
t1) kcal/hr. 13. Steam required to give this heat
energy at 30% MCR = Ma Cpa t t
Hs Hc* * ( )( )
2 1
kg/hr
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DOC. NO. WI-ME-DSN-100-005 REV. NO. R-A PAGE 1 OF 1
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FORM T10 REV - A
LHV, HHV CALCULATIONS - COAL
( ){ }14500 62000 40002 8C H S+ + 2o Higher Heating Value (HHV)
= ------------------------------------------------------------- 1.8
HHV in kcal/kg { }HHV Btu lb x H W* . ( / )18 9720 11102 Lower
heating value (LHV) =
--------------------------------------------------- 1.8 LHV in
kcal/kg Where, W is the fraction by weight of moisture in fuel and
C, H2, O2 and S are fractions by
weight of carbon, hydrogen, oxygen and sulfur in the fuel.
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DOC. NO. WI-ME-DSN-100-006 REV. NO. R-A PAGE 1 OF 2
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FORM T10 REV - A
LHV, HHV CALCULATIONS FOR GASEOUS FUEL - (NATURAL GAS)
% WT
NOTA- TION
COMPOSITION % VOL
MOL. WT
xiMixnMn /100
n= CH4, C2H6 etc i =cons for which % wt conversion to be
done
HHV (KCAL/KG)
LHV (KCAL/KG)
METHANE (CH4)
XCH4 16.043 XxnMn
CH 4 16 043100
./
n = CH4, C2H6 etc.
X1 13269.23077 11944.57716
ETHANE (C2H6) XC2H6 30.07 XxnMnC H2 6 30 07
100.
/
n = CH4, C2H6 etc.
X2 12403.24892 11353.32059
PROPANE (C3H8)
XC3H8 44.097 XxnMn
C H3 8 44 097100
./
n = CH4, C2H6 etc.
X3 12036.55041 11082.17869
I - BUTANE (C4H10)
XC4H10 58.124 XxnMn
C H4 10 58124100./
n = CH4, C2H6 etc.
X4 11811.99236 10907.78786
N-BUTANE (C4H10)
XC4H10 58.124 XxnMn
C H4 10 58124100./
n = CH4, C2H6 etc.
X5 11840.65934 10935.26039
I-PENTANE (C5H12)
XC5H12 72.151 XxnMn
C H5 12 72151100.
/
n = CH4, C5H12 etc.
X6 11698,51887 10822,98137
N - PENTANE (C5H12)
XC5H12 72.151 XxnMn
C H5 12 72151100.
/
n = CH4, C5H12 etc.
X7 11720.01911 10845.67606
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DOC. NO. WI-ME-DSN-100-006 REV. NO. R-A PAGE 2 OF 2
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FORM T10 REV - A
NITROGEN (N2) XN2 28.013 XxnMnN 2 28 013
100./
n = CH4,C5H12 etc.
X8
HEXANE PLUS XHEX 86.169 XxnMn
HEX 86169100
./
n = CH4,C5H12 etc.
X9 11636.40767 10781.17535
Molecular weight of the gas mixture(MW)= ( )MWi YiX where, Yi =
Volume fraction of gas i. MWi = Molecular weight of gas i.
Density of the gas g(lb/cu.ft) = 492 x MW x P
t359 460 14 7( ) .+
g(kg/M3) = fg(lb/cu.ft) * 16.033 where, P = gas pressure, psia t
= gas temperature, F MW = gas molecular weight g = gas density,
lb/cu. Ft. Higher Heating Value
of the gas (HHV) =x HHV x HHV x HHVCH C H C H1
1002
1003
1004 2 6 3 8*( ) *( ) *( )
+
+
+x HHV x HHV x HHVC H C H C H4
1005
1006
1004 10 4 10 5 12*( ) *( ) *( )
+
+
+ x HHV x HHVC H Hexane7
1009
1005 12*( ) *( )
+
plus
HHV is in kcal/kg. HHV in kcal/Nm3 = HHV(kcal/kg) x gas density
(kg/m3). Lower Heating Value
of the gas (LHV) = x LHV x LHV x LHV C HCH C H1
1002
1003
1003 84 2 6*( ) *( ) *( )
+
+
+ x LHV x LHV x LHVC H C H C H4
1005
1006
1004 10 4 10 5 12*( ) *( ) *( )
+
+
+ x LHV x LHVC H7
1009
1005 12*( ) *( )
+
Hexane Plus
LHV is in kcal/kg. LHV in kcal/Nm3 = LHV (kcal/kg) x gas density
(kg/m3).
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DOC. NO. WI-ME-DSN-100-007 REV. NO. R-A PAGE 1 OF 2
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FORM T10 REV - A
STOICHIOMETRIC AIR REQUIREMENT - SOLID AND LIQUIDFUELS
CONSTI-TUENT
FRACTION
O2 REQUIRED PER KG OF
CONSTITUENT
O2 REQUIRED
PER KG OF FUEL
Carbon Xc 2.664 Xc x 2.664
Hydrogen XH2 7.937 XH2 x 7.937
Oxygen
- - -
Sulphur Xs 0.998 Xs x 0.998
Nitrogen
- - -
Moisture
- - -
Total *T * Total O2 required per kg of fuel shall be obtained by
deducting the oxygen
present in the fuel. Stoichiometric dry air = O2 kg/kg of fuel
(T) x 4.3196 (kg/kg of fuel fired)
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DOC. NO. WI-ME-DSN-100-007 REV. NO. R-A PAGE 2 OF 2
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FORM T10 REV - A
STOICHIOMETRIC AIR REQUIREMENT - GASEOUS FUEL
Description
% by Vol.
Mol. Wt of comp.
% by wt (c) XiMi
XnMn / 100
Dry Air
A
B
kg/kg of comp.
D
kg/kg of gas (C/100xD)
Hydrogen (H2) 2.02 34.21
Carbon monoxide (CO)
28.01 2.46
Methane (CH4)
16.04 17.20
Ethane (C2H6) 30.07 16.06
Propane (C3H8)
44.09 15.64
I-Butane (C4H10)
58.12 15.43
N-Butane (C4H10)
58.12 15.43
I-Pentane (C5H12)
72.15 15.30
N-Pentane (C5H12)
72.15 15.30
Hexanes (C6H14)
86.17 15.21
Ethylene (C2H4)
28.05 14.75
Propylene (C3H6)
42.08 14.75
Air required / kg of gas =
( ) ( )% by wt of constituent (xi) x Dry Air kg / kg of
comp.(xi)i
N
=
1
Where N is the Nth number of constituent in the gas.
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DOC. NO. WI-ME-DSN-100-008 REV. NO. R-A PAGE 1 OF 9
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FORM T10 REV - A
RECOMMENDED FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING DEMINERALISED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION UPTO 20 BAR(g)
FEED WATER BOILER WATER 1 HARDNESS 1 - 2 pH@25 C 8.8-9.2
10.0-10.5 3 IRON,TOTAL ppm 0.05 - 4 SILICA, SiO2 ppm 1 25 5
CONDUCTIVITY
micro s/cm
10
1000 6 HYDRAZINE
RESIDUAL ppm - -
7 PHOSPHATE
RESIDUAL ppm -
20.0-40.0 8
OXYGEN max,ppm
0.02
-
9
TDS max, ppm
-
500
10
COPPER,TOTAL,ppm
0.01
-
11 SODIUM SULPHATE AS Na2 SO3 ppm
- 20-40
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DOC. NO. WI-ME-DSN-100-008 REV. NO. R-A PAGE 2 OF 9
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FORM T10 REV - A
RECOMMENDED FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING DEMINERALISED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION 21-40 BAR(g)
FEED WATER BOILER WATER 1
HARDNESS
0.5
-
2
pH@25 C
8.8-9.2
10.0-10.5
3
IRON ,TOTAL ppm
0.02
-
4
SILICA, SiO2 ppm
0.3
15
5
CONDUCTIVITY micro s/cm
5
400 6
HYDRAZINE RESIDUAL ppm
-
-
7
PHOSPHATE RESIDUAL ppm
-
20.0-40.0 8
OXYGEN max,ppm
0.02
-
9
TDS max, ppm
-
200
10
COPPER,TOTAL,ppm
0.01
-
11
SODIUM SULPHATE AS Na2 SO3 ppm
-
5-10
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FORM T10 REV - A
RECOMMENDED FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING DEMINERALISED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION 41-60 BAR(g)
FEED WATER BOILER WATER 1
HARDNESS
NIL
-
2
pH@25 C
8.8-9.2
9.8-10.2
3
IRON ,TOTAL ppm
0.01
-
4
SILICA, SiO2 ppm
0.1
10
5
CONDUCTIVITY micro s/cm
2
300 6
HYDRAZINE RESIDUAL ppm
0.02-0.04
-
7
PHOSPHATE RESIDUAL ppm
-
15.0-25.0 8
OXYGEN max,ppm
0.01
-
9
TDS max, ppm
-
150
10
COPPER,TOTAL,ppm
0.01
-
11
SODIUM SULPHATE AS Na2 SO3 PPM
-
-
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FORM T10 REV - A
RECOMMENDED FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING DEMINERALISED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION 61-100 BAR(g)
FEED WATER BOILER WATER 1
HARDNESS
NIL
-
2
pH@25 C
8.8-9.2
9.8-10.2
3
IRON ,TOTAL ppm
0.01
-
4
SILICA, SiO2 ppm
0.02
10
5
CONDUCTIVITY micro s/cm
0.5
200 6
HYDRAZINE RESIDUAL ppm
0.01-0.02
-
7
PHOSPHATE RESIDUAL ppm
-
15.0-25.0 8
OXYGEN max,ppm
0.007
-
9
TDS max, ppm
-
150
10 COPPER,TOTAL,ppm
0.01
-
11
SODIUM SULPHATE AS Na2 SO3 PPM
-
-
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FICHTNER India
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FORM T10 REV - A
RECOMMENDED FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING DEMINERALISED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION 100&ABOVE
BAR(g)
FEED WATER BOILER WATER 1
HARDNESS
NIL
-
2
pH@25 C
8.8-9.2
9.4-9.7
3
IRON ,TOTAL ppm
0.01
-
4
SILICA, SiO2 ppm
0.02
*
5
CONDUCTIVITY micro s/cm
0.3
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FORM T10 REV - A
FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING SOFTENED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION UP TO 20
BAR(g)
FEED WATER BOILER WATER 1 Iron as Fe ppm 0.100 - 2 Copper as Cu
ppm 0.05 - 3 Total hardness as
CaCO3 ppm
0.300 -
4 Silica, SiO2 ppm - 150 5 Total alkalinity as CaCO3 - 700 6
Specific conductance micro s/cm
-
7000
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FORM T10 REV - A
FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING SOFTENED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION 21 - 40 BAR(g)
FEED WATER BOILER WATER 1 Iron as Fe ppm 0.030 - 2 Copper as Cu
ppm 0.020 - 3 Total hardness as
CaCO3 ppm
0.200 -
4 Silica, SiO2 ppm - 40 5 Total alkalinity as CaCO3 - 500 6
Specific conductance
micro s/cm -
5000
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FICHTNER India
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FORM T10 REV - A
FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING SOFTENED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION 41 - 60 BAR(g)
FEED WATER BOILER WATER 1 Iron as Fe ppm 0.020 - 2 Copper as Cu
ppm 0.015 - 3 Total hardness as
CaCO3 ppm
0.100 -
4 Silica, SiO2 ppm - 20 5 Total alkalinity as CaCO3 - 300 6
Specific conductance
micro s/cm -
3000
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FICHTNER India
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FORM T10 REV - A
FEEDWATER & BOILERWATER QUALITY FOR
POWER PLANT APPLICATION
(USING SOFTENED WATER)
DRUM OPERATING PRESSURE OF SL.NO. DESCRIPTION 60 - 100
BAR(g)
FEED WATER BOILER WATER 1 Iron as Fe ppm 0.020 - 2 Copper as Cu
ppm 0.015 - 3 Total hardness as
CaCO3 ppm
0.050 -
4 Silica, SiO2 ppm - 8 5 Total alkalinity as CaCO3 - 200 6
Specific conductance
micro s/cm -
2000
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FICHTNER India
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FORM T10 REV - A
BOILER BLOW DOWN CALCULATIONS
DEFINITION Boiler Blowdown is defined as the process of removal
of a fraction of water from boiler
unit and its replacement by feed water. This is done to prevent
build up of excessive
concentration of undesirable substances in Boiler Water.
Continuous Blowdown is carried out to maintain dissolved solid
concentration within
prescribed limits in the Boiler Water.
Intermediate Blowdown is carried out to reduce the sludge level
in the Boiler Water
and also to accelerate the Continuous Blow down process.
E - Evaporation rate (TPH)
S - Solid content of Feed Water (g/m3)
V - Boiler Water content (m3)
C - Maximum allowable concentration of solids in Boiler Water
(g/m3)
C1 - Concentration of solids in Boiler Water on completion of
Intermittent
Blowdown (g/m3).
B - Actual Intermittent or Continuous Blowdown rate as
percentage of Evaporation
rate.
BA - Average Intermittent Blowdown as percentage of Evaporation
rate.
d - Duration of Intermittent Blowdown operation (h).
t - Interval between completion of one Blowdown operation and
completion of the
next (h).
Q - Quantity of Boiler Water discharge during each Intermittent
Blowdown
operation (m3).
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FORM T10 REV - A
Continuous Blowdown
C1 = C
BA = B
d = t
B = 100 x [S/(C-S)]
The above relationship is valid for various constituents of
water like Alkalinity, salt
content, silica etc., Check for the Blowdown rate for each
constituent separately and
the minimum value of Blowdown rate shall be considered and the
corresponding
constituent shall be the governing factor. Refer document no.
100/11 for Boiler Water
limits for various drum pressure levels.
Intermittent Blowdown B = tsv x 100/[d(CV-0.5SE(t-d)-VS)] Q =
EtSV/[CV-0.5SE(t-d)-VS] C1 = C - [(t-d) SE/V]
BA = Q x 100/tE
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FORM T10 REV - A
CHIMNEY SIZING
Introduction Chimneys, as we know them today, are tall slender
structures which fulfill an
important function. They had a humble beginning as house hold
vents and over the years, as vents grew larger and taller, they
came to be known as chimneys. A cluster of them is a stack.
Function A chimney is a means by which flue gases are discharged
at a high elevation so that
after dilution due to atmospheric turbulence, their
concentration and that of their entrained solid particulates is
with in acceptable limits on reaching the ground. A chimney
achieves simultaneous reduction in concentration of a number of
pollutants (such as SO2 , NOx , CO, Suspended\Particulate Matter
(SPM), Respirable Particulate Matter (RPM). Size less than 10 m,
lead etc) and being highly reliable it does not require a stand by,
while these are its merits, it is well to remember that a chimney
is not the complete solution to the problem of pollution
control.
Chimney classification Chimney are classified based on their
height (tall or short), number of flues (single or
multi), material of construction (Brick, RCC, steel, FRP),
structural support (Guyed or self supporting), lining (Lined or
unlined). When Multiflue chimney is selected ? often, a single
chimney serves more than one boiler. In such a case when one of the
gas sources is shut down for maintenance the gas exit velocity will
reduce because of a reduction in the total volume of gases to be
handled. This can lead to heavy pollution and in order to overcome
this problem, a chimney serving more than one boiler can be
provided with a separate flue for each gas source with such flues
housed in a common enclosing concrete wind shield. These are called
as Multi-flue chimneys.
Exit Velocity Flue gases emerging from a chimney experience a
field of increasing wind speed,
soon a speed will be reached (termed critical wind speed) when
the wind will shear off the emerging gas plume and this can lead to
excessive pollutant deposition. If the exit velocity is low, it can
permit cold air to flow down a part of the chimney causing acids
contained in flue gases to condense on the walls and cause damage.
In order to avoid this, the flue gas velocity (ie. when chimney is
operating in part load) should be such that 1.5 times the wind
velocity.
A part from this, a larger exit velocity will result in higher
plume rise which in turn will
lead to a diminished GLC of pollutants. For the above reasons, a
high exit velocity is preferred but this can damage the lining due
to erosion. With steel liners, velocities upto 45 m/s can be used
and with brick liners velocities higher than 30 m/s is not
recommended.
For power plant chimneys handling more than 2000 M3 /min of flue
gases, exit
velocities will be in the range of 20-25 m/s. In general for our
calculations purpose we use flue gas velocity as 1.5 times the
wind velocity, which is recommended in IS 4998 and Tall chimneys
by S.N Manohar.
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FICHTNER India
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FORM T10 REV - A
Physical Dimensions Shape Any shape for the chimney, other than
circular, offers greater resistance to wind
currents and is more prone to oscillation. Hence circular shape
is recommended. Exit size The top dimensions of a flue are fixed
such that a given volume of gases can be
discharged at the design exit velocity. A 20% increase in the
cross sectional area shall be provided for the effect of reduced
velocity near the inner surface of the chimney due to friction. If
a chimney has to handle a range of gas volumes, then the exit
velocity should be high at minimum load and at the same time should
not exceed the limiting values when operating at full load.
Physical height The following two consideration dictate the
physical height of a chimney. 1. To generate a draft which will
cause gases to flow out with the desired exit velocity. 2. To
satisfy local regulations in respect of permissible GLC of
Pollutants. CHIMNEY SIZING CRITERIA Step : 1 Chimney height based
on IS: 4998 (Part-I) 1975.
Height of the chimney `H = AQFK
Cn
V TP
1 2 1 6/
*/
where A = a coefficient depending upon the atmospheric vertical
temperature distribution
which determines the condition for vertical and horizontal
dispersion of the substances in air. these value for Indian
condition may be taken as 200.
Q = total emission of impurities from all chimneys (mg/s) F = a
coefficient to account for the substances settling velocity in the
atmosphere.
This value may be taken as 1 for SO2 , since the settling
velocity of SO2 is nearly zero ; and 2 for dust if the average
practical dust collecting efficiency is not less then 90 percent
and 2.5 if the efficiency is less then 90% percent.
K = a coefficient accounting for the effect of flue gas exit
velocity for the chimney
Vo . The values are given below. Flue gas Exit Velocity
Vo m/s Value of K
10-15
1
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FORM T10 REV - A
20-25 0.9
30-35
0.8 Cp = Maximum expected concentration of the pollutant at
grade level (mg/M3 ) n = Number of chimneys V = Total volume of
flue gases discharged from chimneys (M3 /s ) T = Temperature
difference between flue gas Tg and ambient air temperature Ta (C) =
Tg - Ta Step - 2 If background pollution is already in existence in
the area under consideration, the
chimney height calculated shall be modified as follows.
Hc = H C
C Cp
p e
1 2/
Where Hc = corrected chimney height in (m) Ce = existing
background concentration in (Mg/m3 ) Step - 3 CHIMNEY HEIGHT AS PER
POLLUTION CONTROL BOARD NORMS. However, as per pollution control
norms the stack height requirement for sulphur di-
oxide control shall be as follows. H = 14 (Q)0.3 Where H =
Chimney height (m) Q = SO2 emission rate (kg/hr) Chimney height
calculated based on the above two methods has to be compared,
and
the tallest one shall be selected. Stack height requirement as
per pollution control norms for larger capacity power
plants is as follows. For Boiler size less than 200 MW above
steps shall be followed, if Boiler size is above 200 MW & less
then 500 MW then 220 M height chimney shall be selected if the
Boiler size is more than 500 MW then 275 M height chimney shall be
selected.
Step - 4
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FORM T10 REV - A
CHIMNEY DIAMETER Chimney diameter at the exit shall be
calculated as given below
De =4
0
VV
Where De = diameter at exit (m) V = total volume of flue gas (M3
/sec) V0 = allowable velocity at the exit (M/Sec.) ie. 1.5 x wind
speed. As explained earlier the calculated diameter has to be
increased by 20% Dec = 1.2 x De Where Dec = corrected diameter at
the exit. Stack Draft Calculations :- After finishing the above
calculation, stack draft calculation shall be done and draft
available shall be checked. The following are the procedure to
calculate the net draft available.
Net draft available is nothing but theoretical draft calculated
less the dynamic head
loss due to kinetic energy of gases leaving a chimney and the
head lost in overcoming friction along the internal surface of a
flue.
Net draft = theoretical draft - (Dynamic loss + Friction
loss).
Net draft = 13.6 * 0.029 BHd 1 1
T V T Va a g g
15.4x10-9 x Q2 g x Vg H fT
B DT
B DT
BeDd
gm
m m
gt
E t
ge
e5 4 4+
MM of H2O
where B = Barometer pressure (mm of Hg) Hd = height of chimney
above breeching (m) Ta = air temperature ( K) Va = Sp. volume of
air at STP = 0.775 (m3/kg) Tg = Temperature of flue gas ( K) Vg =
Sp. volume of flue gas at STP (m3 /kg) Qg = Mass emission rate of
flue gas (g/sec)
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FORM T10 REV - A
f = friction factor (refer enclosed chart) Tgm = Temp of flue
gas at mean height (k) Bm = Barometric pressure at Mean height (mm
of Hg) Dm = Diameter of chimney at mean height (m) Tgt =
Temperature of flue gas at top of chimney ( K) Bt = Barometric
pressure at top (mm of Hg) Dt = Diameter of chimney at top (m) Tge
= Temperature of flue gas at breeching level (m) Be = Barometric
pressure at breeching level (mm of Hg) De = Diameter of chimney at
breeching level (m) Clearances The following clearances has to be
obtained for installing a chimney 1. Stack height clearance from
National Air port Authority 2. Environmental clearance from state
pollution control board and from Ministry of
Environment & Forest, Government of India.
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FICHTNER India
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FORM T10 REV - A
EMISSION/AMBIENT AIR QUALITY CALCULATIONS
PARTICULATE EMISSION LEVELS Particulate emission data are needed
to size dust collectors for coal-fired boilers. In
coal-fired boilers, about 75% of the ash is carried away by the
flue gases and 25% drops into the ash pit. The following expression
may be used for determining the Ash concentration in the flue
gas.
Ca = 2,40,000 x (% ash/100)
------------------------------------------------------------------
T x [7.6 x 10-6 x HHV x (100+E) + 1 - (% ash/100)] Where Ca = ash
concentration, grains / cu.ft E = excess air % T = gas temperature,
OR HHV = Higher Heating value, Btu/lb To convert ash concentration
in grains/cu.ft to kg/m3 Ca = 0.01 x A x 7000 x Ash concentration
in lb/ft3 = Ca ---- 70 Ash concentration (kg/m3) = Ca ---- * 16.033
70 = gas density, lb/Cu.ft = 39.5 / (460+t) t = gas temperature , F
Ca = ash content, grains/acf or grains/scf depending on whether
density is computed at actual temperature or at 60F A = ash
content, % by weight The expression for density is based on
atmospheric flue gases having molecular
weight of 28.8 The ESP is sized to achieve an outlet dust
concentration of 150 mg/Nm3
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FICHTNER India
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FORM T10 REV - A
SO2 Emission LEVEL Emission of S02 in lb/mmBtu (e) = 2 x 104 S
------- HHV Where S is the % sulfur in the fuel. HHV = Higher
Heating value of the fuel Btu/lb Conversion S02 Emission rate in
lb/mmBtu to PPM Weight flow rate of flue gas produced / MMBtu Wg =
106 + (1+%E)*A HHV 100 Air/MMBtu of fuel (A) = 760 for Bituminous
coals = 745-750 for furnace oil and lignite = 780 for Anthracite =
800 for coke Moles of flue gas = Wg ; Mf : Molecular weight of flue
gas (mf) Mf Moles of SO2 = e MSO2 : Molecular weight of SO2 ---
(MSO2) = MSO2 (SO2) in ppm = M SO2 x 106 --------- Mf NOX in
Volumetric Units on dry Basis 100 * (w/46) (W/Mw) Vn(ppmvd) =
100-%H2O --------- (1) where %H2O = Volume of water vapour MW =
Molecular weight of the Exhaust Gases M = Flow rate of NO2, lb/hr W
= Turbine Exhaust Gas Flow, lb/hr The value of V obtained with Eq-1
must be converted to 15% Oxygen on dry basis to
give ppmvd of Nox at 15% O2 . V * (21-15) * 166 Vn(ppmvd 15% 02)
= 21 - 100%02/(100-%H2O) ------- (2) = V * F where %O2 = Oxygen
present in the wet exhaust gases. Factor F converts V to 15%
Oxygen basis, which is the usual basis for reporting
emissions.
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FICHTNER India
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FORM T10 REV - A
Co-Emission in ppmvd Vc = 1.642 * Vn (for the same Wlb/hr rate)
Because the ratio of Molecular weights of NO2 and Co is 1.642.
NOISE EMISSION LEVELS NOISE LEVEL LIMITATIONS 1. NOISE LEVEL
LIMITATIONS AROUND EQUIPMENTS During normal operating conditions
(70% load to 100% load), the noise level
around the equipments shall not exceed 90 db (A) measured at a
distance of 1 m from the nearest surface of the machine and at a
height of 1.2 m from the floor level.
2. NOISE LEVEL LIMITATIONS AT THE CONTROL PROPERTY BOUNDARY The
noise level at the Control property boundary shall be limited to
the values
as given in the table below:- Ambient Air quality standards in
respect of Noise
AREA CODE
CATEGORY OF AREA
LIMITS IN DB(A)
DAY- TIME
NIGHT TIME
A. Industrial area 75 70 B. Commercial area 65 55 C. Residential
area 55 45 D. Silence area 50 40
Day time is between 6 a.m to 9 p.m Night time is between 9 p.m
to 6 a.m The noise levels at the property boundary line shall be
specified as per the above
table which should remain within the prescribed limits
throughout the plant operating range (i.e) 70% load to 100% load.
It is to be noted that the noise limit is for total noise
(background noise + plant noise)
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FORM T10 REV - A
NOISE LEVEL MEASUREMENT AROUND EQUIPMENTS The noise level
limitations as stipulated in the above table shall be
demonstrated
around the following equipments:
1. Gas Turbine 2. Steam Turbine 3. Circulating Water Pumps 4.
Boiler Feed pumps 5. Condensate Extraction pumps 6. Steam Jet air
Ejectors 7. Pulverising Mills 8. F.D fans, I.D fans & P.A.
fans
For equipments inside the building, the noise monitoring should
be done for 8 hours
continuously as the worker is exposed to the noise of 8 hours
during a shift. The noise limits for industrial workers has been
prescribed as 90dB(A)
Noise measurements should be done on the prescribed paths. After
carrying out the
pilot survey, detailed baseline noise data should be collected.
These should be atleast four key measuring points which depend upon
the size of the machine and the symmetry of the acoustic radiation.
The noize measurement should be done at 4 key measuring points and
successive measuring locations. The successive measuring locations
should be on the prescribed path at intervals of not more than 1
meter commencing from the 4 key measuring points.
EXCLUSIONS Noise levels during plant transients, upset
conditions and noise levels resulting from
the actuation of safety devices may exceed the limits specified
for a short period of time.
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FICHTNER India
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FORM T10 REV - A
MONITORING OF NOISE The monitoring of noise shall be done
inaccordance with the following IS standards.
IS 4758 : 1968 Methods of Measurement of noise emitted by
machines
IS 6098 : 1971 Methods of Measurement of air borne noise emitted
by rotating electrical machinery
IS 7194 : 1973 Assessment of noise exposure during work for
hearing conservation purposes
IS 9779 : 1981 Sound level meters (superseding IS:3931 - 1966)
and (IS 3932 - 1966)
IS 9989 : 1981 Assessment of noise with respect to community
response
IS 10423 : 1982 Personal sound exposure meter.
IS 10534 : 1983 Methods of measurement of airborne noise emitted
by gas turbine installations
IS 9876 : 1981 Guide to measurement of airborne acoustical noise
and evaluation of its effect on man.
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FICHTNER India
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FORM T10 REV - A
ASH HANDLING SYSTEM
1.0.0 Introduction
This document is a guide line applied to ash handling facilities
for solid fuel fired
steam generators, extending from ash collection points of the
combustion residues
upto the places of dispatch from the power station area.
1.1.0 Fuel Used & Ash Content
The fuels normally considered are solid fuels like
coal/lignite/washery middlings etc.
When other fuels are used appropriate considerations are to be
made. A decisive
influence on the properties of ash is exerted by the physical,
chemical and
technological conditions of combustion. Generally either
fluidized bed furnaces or
pulverised coal fired furnaces are adopted depending on the
generating capacity of
the plant. Normally it is considered that for coal the total ash
percentage will be about
45% and for lignite about .....% for designing the ash handling
system. The correct
data shall be obtained from the design spec for fuel.
2.0.0 Type of ash generation
The type of ash produced due to burning of solid fuel such as
coal/lignite is Bed ash /
Bottom ash, Cyclone ash and fly ash. The bed / bottom ash is a
coarse ash
discharged from the boiler bed area or furnace hopper. Normally
the quantity of bed
ash is about 20% of total ash content of the fuel. The density
of bed ash is about 800
to 1100 kg/m3 . The average particle size range is 1.0 to 10mm
and maximum is
30mm. The fly ash is entrained in the flue gas and collected in
the Economiser / Air
preheater hoppers, downstream electrostatic precipitator hoppers
and in the chimney
ash hopper. Normally the quantity of fly ash is about 80% of
total ash content of the
fuel. The density of fly ash is about 500 to 900 kg/m3 . The
average particle size
range is 0.1 to 3.0 mm. Maximum is 10 mm.
The ash handling system is distinguished according to the type
of ash such as.
- Coarse ash or granulate
- fly ash.
3.0.0 Ash handling systems
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FORM T10 REV - A
The ash handling systems are classified as
- Mechanical conveying systems
- Hydraulic conveying systems
- Pneumatic conveying systems
The mechanical conveying systems generally consists of
- Submerged scrapper conveyors
- Belt conveyors
Hydraulic conveying system uses water as a conveying medium. The
system
consists of pumps, ejectors, sluiceways and conveying
pipelines.
Pneumatic conveying systems are specifically used for collection
points where dust is
obtained. The system uses air as the conveying medium.
3.1.0 Mechanical Conveying Systems
Submerged scrapper conveyors are provided below the combustion
chambers of
boilers and are used for the quenching and discharge of the bed
ash discharged. The
scrappers are generally spaced at 0.5 to 1.0m between two
endless chains at the
bottom of a water filled through and operate at low speed at
about 0.3 to 1m/min
before discharge.
The boiler outlet is sealed off by means of a submerged chute
immersing in the water
bath. Boiler downward expansion must be considered in the
immersion depth. The
maximum cooling water outlet temperature shall not exceed 50C.
Depending on the
water temperature difference the required amount of water is
about 6 to 20 times of
the amount of ash generated. The drainage water is polluted with
fine ash and hence
the overflow / drain pipe shall be adequately sized and
necessary down stream
classifying equipment is installed.
Belt conveyors are provided when longer distance conveying is
required. Care must
be taken to ensure that sufficiently cool bed ash is conveyed.
Maximum inclinet of
belt conveyor is limited to 16.
3.2.0 Hydraulic conveying systems
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FORM T10 REV - A
3.2.1 The hydraulic handling system of ash consists of slurry
pumps. Ejectors, sluiceways,
sump etc. The bottom ash collected is normally stored in a water
impounded ash
hopper for 8hrs. Then the ash is crushed to a handling particle
size of maximum
50mm and pumped to disposal site by slurry pumps. Because of
high heat dissipation
rate water must be fed in continuously as the water temperature
is limited to 60C.
The water impounded hopper is a steel shell with a temperature
resistant lining on the
inside.
3.2.2 The slurry pumps used for conveying are normally of single
stage non-clog centrifugal
pumps having a maximum speed of 1000 rpm for transport distance
upto 3 km.
(horizontal). When the distance is more 2 to 3 pumps are
connected in series or
intermediate pump stations are provided.
3.2.3 Ejectors
When Ejectors are used ash to water ratio is 1:4 to 1:10
depending on the ash size,
feeding configuration. The necessary water pressure upstream is
about 6 to 8 times
the pressure in the delivery piping after the ejector. This
pressure level depends on
ejector efficiency, delivery length, delivery head and piping
resistance. Ejectors are
simple in design, replacement is easy and less maintenance
compared to slurry
pumps. Ejector system is normally adapted for fly ash
conveying.
Sluiceways conveyance is adapted for bed ash / coarse ash.
Sluiceways are suitable
only for short distance up to the slurry sump from where the ash
slurry is conveyed by
pumps. The slope of sluiceway is about 2 to 3% and water
requirement is about 20
times the ash handled.
3.3.0 Pneumatic Conveying Systems
In Pneumatic conveying systems the ash is discharged by means of
compressed air
either directly from the hoppers or from a collecting vessel and
conveyed to the silos
through piping. The piping resistance is over come by conveying
air pressure. Two
types of pneumatic conveying systems are
- dilute phase conveying and
- dense phase conveying
Advantages of pneumatic systems are
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FORM T10 REV - A
a) Long distance conveying so that storage can be located for
off from the plant.
b) Ash can be conveyed directly from multiple hoppers to the
disposal point.
c) Higher conveying capacity over longer distances.
Hence medium capacity powerstations normally select pneumatic
systems.
The system components are
1) Conveying pipe line with required fittings.
2) Positive displacement air supply blower or compressor.
3) Pressure feeders attached to the collection hoppers to feed
into the conveying
pipe. 4) Storage bin.
5) Silo unloading systems.
3.3.1 Lean Phase Conveying
In Dilute phase / lean phase conveying system the gas velocities
are much greater
than the settling velocity of the individual grain.
The velocity of conveying air in lean phase is about 15 m/sec to
20 m/sec at a mass
flow ratio about 10 and pressure loss is about 0.1 to 1
bar/100m. The particle velocity
is about 0.9-1 m/sec.
3.3.2 Dense Phase Conveying
In dense phase conveying the velocity of conveying is low but
higher pressure is used
where the material to be transported completely fills the pipe
and transported in
separate plugs.
The velocity of coveying air in dense phase is 1 to 10m/s with
mass flow ratio 20 to
150 and the pressure loss is about 0.5 to 1 bar/100m. The
particle velocity is 0.5 to
0.9 m/sec.
3.3.3 System description
3.3.1 Dense phase conveying system
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FORM T10 REV - A
The system envisages removal of fly ash/bedash pneumatically by
means of pressure
conveying system. Fly ash would be collected in various hoppers
located in flue gas
path viz. economiser, air preheater, ESP and the chimney hopper
which amount to a
maximum of 80% of total ash produced in the furnace. Bed ash
will be collected from
the bed ash discharge points after necessary cooling by the bed
ash coolers or water
cooled hoppers which amount to 20% of total ash generated.
The bedash / flyash collected would be fed into the individual
transmitter vessel
located below the hoppers. At each hopper level probe shall be
provided for initiating
the conveying cycle. The system can operated both in level /
timer mode. The ash
collecting surge hopper shall be provided with water cooling
arrangement whenever
hotash (generally for / bedash / cycloneash) is handled. The
isolation seal valves are
also water cooled.
The operation of the system is fully automatic. When the system
is operated in auto -
timer mode the system shall have continuous cycle after a preset
interval of time. In
level mode level prope provided in the surge hopper shall
initiate the conveying cycle.
The isolation valve shall open and allow ash by gravity into the
transmitter vessel by
gravity till it is closed automatically by the timer preset as
per process parameters. On
closure of the isolation valve. The valve seal gets inflated and
the conveying air is
injected into the vessel. The vessel is pressurised and the
material resistance helps
pressure build up which conveys the material to the destination
silo. When conveying
is complete the pressure drop down to nearly atmospheric
pressure and is sensed by
the control system, the air supply to the system is stopped. The
transmitter vessel is
ready for the next cycle.
Ash is conveyed by M.S ERW pipes conforming to is............
heavy grade with long
radius allow CI bends upto the terminal box located on top of
the silo. The terminal
box help the ash to be discharged into the silo. The conveying
air escapes by the
vent provided on top of the silo. The vent is provided with
reverse pulsejet type bag
filter to filter the vent air. The size of the ash silo is
depending upon the quantity of
ash generated and the silo discharging operation cycle.
The ash conveying pipe line should have minimum number of bends
as far as
possible to avoid choking of the line and reduce maintenance
problems. The bends
should have long radius about 10 D of the pipe dia.
Incase two or more silos are to be used for collecting the ash
from single line
pneumaticaly operated divertor valves are used to divert the ash
to the required silo.
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FORM T10 REV - A
3.3.2 The lean phase conveying system also functions similar to
the dense phase system
only with the difference of high volume air supply source at low
pressure.
The general system configurations are enclosed in the Annexure
-1.
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FORM T10 REV - A
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FORM T10 REV - A
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FORM T10 REV - A
RAW WATER ANALYSIS CONVERSION FACTORS FOR IONIC LOADS
Raw Water contains impurities which can be classified as
Suspended Solids and
Dissolved Solids. Suspended solids can be removed by Filtration.
The Dissolved
Solids can be removed only by Distillation, Reverse osmosis and
Ion Exchange
process.
The constituents of Dissolved solids are salts of Calcium,
Magnesium, Sodium and
Potassium existing in the form of CaCO3, MgCO3, CaSO4, Na2, SO4,
etc.
The most popularly used scale for measurement of Ionic load is
mg/l or Parts Per
Million (PPM). The constituents are measured on the basis of As
CaCO3 or As
such. The actual load of constituent Ion measured on As such
basis are converted
to As CaCO3 basis by multiplying the PPM As such by the factor
Atomic weight of
constituent / Atomic weight of CaCO3. Atomic weight of CaCO3 is
100.
It is imperative to convert all Ionic loads to As CaCO3. Basis
in order to check for
Ionic balance. Ionic balance is achieved if total Cation load is
equal to total Anion load.
Another scale for measurement of Ionic load is Equivalent Mass/I
(Eq.m/l). The
Equivalent Mass of given substance is the quantity of the
substance that will combine
with or replace in a given reaction one atom of Hydrogen (or
another monovalent
element as the amount of the substance corresponding to the
transition of one
electron (in oxidising reducing reactions).
Eq = M/n.
But this scale is not used extensively because the equivalent of
many chemical
compositions is not constant as it depends on the type of
reaction involved.
The multiplication factors for conversion of Ionic load from AS
SUCH to AS CaCO3
are as follows:
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FORM T10 REV - A
SL.NO. IONS MULTIPLICATION FACTOR
1. Calcium (Ca++) 2.50 2. Magnesium (Mg++) 4.10 3. Sodium (Na+)
2.18 4. Potassium (K+) 1.28 5. Sulphur (S++) 3.13 6. Aluminium
(Al+) 5.58 7. Fluorine (F+) 2.56 8. Bicarbonates (HCO3) 0.82 9.
Sulphates (SO4) 1.04 10. Chloride (CI) 1.41 11. Nitrate (NO2) 0.81
12. Iron (Fe) 0.79 13. Silica (Si) 0.83 Sl.No.1 to 7 gives the
Cation part and Sl.No.8 to Sl.No.11 indicates the Anion part.
Total cationic load shall be equal to Total anionic load which
is called ionic balance.
Add the Cation load, Anion load, Iron and Silica in AS SUCH
basis to obtain Total
Dissolved Solids (TDS).
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FORM T10 REV - A
RAW WATER ANALYSIS
Raw water available at the site shall be analysed in a
laboratory and its physical,
chemical and Bacteriological Characteristics shall be furnished
as per the format
given below. These data shall be obtained for four seasons over
one year. To work
out the seasonal average water analysis over a period of atleast
3 years shall be
made available.
These details are important to decide the treatment scheme for
the raw water to make
it suitable for the end user.
Source of water 1. Bore Well 2. Open Well 3. River 4. Sea 5.
Others Physical Characteristics 1. Colour 2. Taste 3. Odour 4.
Temperature (C)
Chemical characteristics
1. Ph
2. Specific conductance (micro siemens / cm)
3. Turbidity (NTU)
4. Total Dissolved solids in ppm
5. Total Suspended Solids in ppm
6. Total Alkalinity as CaCO3 in ppm
7. Bicarbonates as HCO3 in ppm
8. Calcium as CaCO3 in ppm
9. Magnesium as CaCO3 in ppm
11. Sodium as CaCO3 in ppm
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FORM T10 REV - A
12. Potassium as CaCO3 in ppm
13. Chlorides as CaCO3 in ppm
14. Sulphates as CaCO3 in ppm
15. Fluorides as CaCO3 in ppm
16. Total Phosphorus As P in ppm
17. Nitrates as CaCO3 in ppm
18. Nitrites as CaCO3 in ppm
19. Ammonical Nitrogen As NH3-N
20. Total Chlorine As Cl2 in ppm
21. Bromides As Br in ppm
22. Oil & Grease in ppm
23. Total Cyanides As CN in ppm
24. Phosphates as CaCO3 in ppm
25. Dissolved Oxygen in ppm
26. Chemical Oxygen Demand in ppm
27. Biochemical Oxygen Demand (for 5
days at 20C)
in ppm
28. Total Organic Carbon in ppm
29. Total Silica as SiO2 in ppm
30. Reactive Silica as SiO2 in ppm
31. Colloidal Silica as SiO2 in ppm
32. Total Iron as Fe in ppm
33. Dissolved Iron as Fe in ppm
34. Total Manganese as Min in ppm
35. Dissolved Manganese as Min in ppm
36. Total Lead as Pb in ppm
37. Total Cadmium as Cd in ppm
38. Total Copper as Cu in ppm
39. Total Strontium as Sr in ppm
40. Total Barium as Ba in ppm
41. Total Aluminium as Al in ppm
42. Total Lithium as Li in ppm
43. Total Zinc as Zn in ppm
44. Total Nickel as Ni in ppm
45. Total Selenium as Se in ppm
46. Total Tin as Sn in ppm
47. Total Mercury as Hg in ppm
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FORM T10 REV - A
48. Total Cobalt as Co in ppm
49. Total Arsenic as As in ppm
50. Total Chromium as Cr in ppm
51. Silt Density Index
Bacteriological Characteristics
1. Aerobic bacterial plate count at 37C
(72 hrs)
as CFU per ml
2. Total Faecal Coliform count, as Most
Propable Number (MPN) per 100 ml
as CFU per ml
3. Total E. Coli bacteria in
100 ml
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FORM T10 REV - A
COOLING TOWER BLOW DOWN, EVAPORATION & DRIFT LOSS
CALCULATIONS
DEFINITION The Circulating Water of the Cooling Water System
gains heat in the Condenser &
other Auxiliaries and rejects the same in the Cooling Tower. In
the Cooling Tower the
spray of water comes in contact with air. A part of the Water is
evaporated and the
remaining water is cooled. The latent heat for evaporating a
part of Water is obtained
from the balance water which is getting cooled.
In the Cooling Water System Water loss takes place in three
different ways.
1. Evaporation loss
2. Blowdown loss
3. Drift loss
Evaporation loss
A part of Water evaporated in order to cool the remaining Water
is Evaporation loss.
Evaporation loss is calculated by the relation
E = T/6.11
E - Evaporation loss in %
T - Temperature of Cooling in the tower. (Difference between
Inlet & Outlet Temp.)
Drift Loss
Drift loss is the loss of Water in the Cooling Tower by
entertainment of Water particles
along with the Water vapour. Drift eliminators are installed in
the Cooling Tower to
minimise the Drift loss. Normally Drift loss is in the range of
0.1% to 0.2% of System
flowrate.
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FORM T10 REV - A
Blowdown loss
The Water which is evaporated does not carry any dissolved
solids with it. The
dissolved solids are getting concentrated in the Bulk Water.
Over a period of time, the
Concentration levels reaches a limit above which the solids tend
to precipitate and
form scales on the pipes and heat transfer surfaces. The process
of removing
calculated quantity of Water and adding fresh Water in order to
maintain the
concentration levels of dissolved solids below prescribed limits
to avoid Scaling is
called as Blowdown. Blowdown is calculated as
B = [E/(C-1)] - D
Where B - Blowdown loss %
D - Drift loss %
C - Cycle of concentration
Cycle of concentration (COC) is determined based on the
Scaling/Corrosion
behaviour of circulating water. Refer Document No.108/2 for
calculation of Scaling
Index and Cycle Of Concentration.
Make up of Losses
The losses in the Cooling Water System due to Evaporation, Drift
and Blowdown has
to be made up using fresh Water. The quantity of fresh Water
make up is addition of
all the losses put together.
M = E + B + D
= E + {[E/(C-1)] - D} + D
= E + E/(C-1)
M = EC/(C-1)
M - Makeup quantity % of total flow
E - Evaporation loss % of total flow
C - Cycle of concentration.
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DIFFERENCE BETWEEN HORIZONTAL PUMPS & VERTICAL PUMPS
Introduction A pump is defined as a device which raises or
transfers fluids. Pumps may be classified on the basis of the
applications they serve, the materials from
which they are constructed, the liquid they handle, and even
their orientation in space. All such classifications, however, are
limited in scope and tend to substantially overlap each offer.
All pumps may be divided into two major categories. 1. Dynamic.
2. Displacement. Dynamic : In which energy is continuously added to
increase the fluid velocities within the
machine to values in excess of those occurring at the discharge
such that subsequent velocity reduction within or beyond the pump
produces a pressure increase.
Displacement : In which energy is periodically added by
application of force to one or more
movable boundaries of any desired number of enclosed, fluid-
containing volumes, resulting in direct increase in pressure upto
the value required to move the fluid through valves or parts into
the discharge line.
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PUMPS
DISPLACEMENT DYNAMIC
CENTRIFUGAL
AXIAL FLOW
SINGLE FLOW
MULTISTAGE
CLOSED IMPELLER
OPEN IMPELLER
MIXED FLOW RADIAL FLOW
SINGLE SUCTION
DOUBLE SUCTION
SELF PRIMING
NON PRIMING
SINGLE STAGE
MULTI STAGE
OPEN IMPELLER
SEMI-OPEN IMPELLER
CLOSED IMPELLER
PERIPHERAL
SINGLE STAGE
MULTI STAGE
SELF - PRIMING
NON - PRIMING
SPECIAL TYPE
JET REDUCTOR
GAS LIFT
HYDRAULIC RAM
ELECTROMAGNETIC
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PUMPS PUMPS
DYNAMIC DISPLACEMENT DISPLACEMENT
RECIPROCATING RECIPROCATING
PISTON PLUNGER PISTON PLUNGER
STEAM-DOUBLE ACTING SIMPLEX
DUPLEX
POWER SINGLE ACTING DOUBLE ACTING
SIMPLEX DUPLEX
TRIPLEX MULTIPLEX DIAPHRAGM
SIMPLEX
MULTIPLE
FLUID OPERATED
MECHANICALLY OPERATED
ROTARY
SINGLE ROTOR
VANE
PISTON
FLEXIBLE MEMBER
SCREW
PERISTALTIC
MULTIPLE ROTOR
GEAR
LOBE
CIRCUMFERENTIAL PISTON
SCREW
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Some of the factors that influence the selection of a pump
follow. 1. Liquid to be handled. a. Quantity and pressure. b.
Viscosity of the liquid at the pumping temperature. c. Relation of
the suction pressure at the pumping temperature to the
vapour pressure. d. Is the liquid corrosive. e. Is the liquid
abrasive (does it contain solids). f. Are undissolved gases
present. 2. Requirements. a. Must the pump meter as well as raise
or transfer. b. Must the pump supply a variable quantity in
response to process needs. c. Will there always be liquid for the
pump to handle. d. Is filterability a problem. 3. Sealing a.
Solvents (leaching of lubricant). b. Solids (abrasion of packing or
seals . c. Toxicity. d. Flammable vapors. e. In compatibility with
ambient condition. f. Loss of expensive fluids. 4. Safety a.
Material of construction to avoid fire hazard. b. Pressure
protection (particularly solids) 5. Size and position. a. How much
space is available. b. Where must the pump be located. 6. Scale -
up problems. 7. Standardisation (with other types and makes already
installed) GENERAL FEATURES OF CENTRIFUGAL PUMPS Centrifugal pumps
accomplish the generation of pressure by the conversion of
velocity
head in to static head. The rotary motion of impellers adds
energy to the service fluid in the form of a velocity increase.
This velocity increase is converted into static head in the volute
diffusing section of the casing. A pump operating at a fixed speed
will develop the same theoretical head in metre of flowing fluid,
regardless of density. However, the pressure corresponding to the
developed head (in bar) depends on the fluid density.
The parameters that establish the maximum head (in metre of
fluid) that a centrifugal
pump can develop are the pump speed (rpm), impeller diameter,
and the number of
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impellers in series combination. Impeller design and blade angle
mainly affect the slope and shape of the head - capacity curve and
normally have no or little effects on the developed head.
Normal and maximum viscosity ranges are a major consideration in
pump selection
because of possible deterioration in performance with increasing
viscosity. Deterioration can be both continuous and gradual. The
table can serve as a guide in selecting the proper centrifugal pump
type for an application.
VISCOSITY SENSITIVITY OF DIFFERENT PUMP TYPES
KINEMATIC VISCOSITY GUIDELINES TYPE PUMP U = /P (mm2/sec) Rotary
7 Nominal minimum viscosity for rotory
pumps. Efficiency begins to decrease as viscosity increases
viscosity should be specified for services when it exceeds this
level.
Centrifugal
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Specially designed centrifugal pumps are self-priming. One type
accomplishes evacuation of the suction line vapour by entertainment
of vapour bubbles from the suction side of the impeller in a charge
of liquid held in the pump casing. The liquid charge in
recirculated to the suction side after separating the entrained
vapour.
Most centrifugal pumps have a self-venting feature small amounts
of vapour trapped
within the casing at start-up (after suction, priming in
complete) are swept out into the discharge line when the pump is
started. Horizontally split casings are not arranged to be
self-venting, however, and are equipped with specially designed
valved vent connections requiring manual operation. single-stage
centrifugal pumps with top discharge connections have good
self-venting performance eventhough the casing shape places a small
high - point vapour pocket in the top of the discharge volute.
CONSTRUCTION FEATURES OF CENTRIFUGAL PUMPS There are a variety
of design features applied to the different construction styles
of
centrifugal pumps. A summary of the main features follows.
Volutes and Diffusers Pump have diverging channels called volutes
which are cast into the discharge zone of
the casing. This casing section collects the liquid discharged
by the impeller and converts velocity energy into the pressure
energy. A centrifugal pump volute increases in area from its
initial point until it encompasses the full 360 around the impeller
and then flares out to the final discharge opening. Single-valves
passages are simple type of design causes an unbalanced load on the
impeller because of the variation in pressure around the periphery
when the pump is operated at capacities other than design
condition. Double - volute configurations are employed when the
unbalanced force level threaten to cause significant shaft
deflection. Twin/Double Volute design consists of two 180 volutes a
passage external to the second joins the two into a common
discharge.
Vaned diffusers for pressure conversion offer the advantages of
balanced radial force,
compact size, and peak efficiency at high head and low flow. But
they are more difficult to fabricate and repair than volute
pumps.
IMPELLER Common impellers are enclosed with full discs and
shrouds Semi open impellers have a full back disc but no front
shrouds Fully open impellers have vanes but little or no disc
material. They are employed
accordingly in low - head, solids - handling service. Impeller
can be clasified by the shape, and form of their vanes. 1. Straight
vane impeller : The vane surfaces are generated by straight lines
parallel to the axis of rotation.
These are also called single curvature vane. 2. Francis - vane
impeller : The vane surfaces of francis - vane impeller have double
curvature lower
specific speeds less than 4200 are called francis vane
impeller.
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3. Mixed flow impeller : An impeller design that has both a
radial and axial flow components is called a
mixed-flow impeller. It is generally resticated to single -
suction design with a specific speed above 4200.
4. Propeller or axial flow impeller : Mixed flow impellers with
a very small radial flow components are usually
referred to as propellers. In a true propeller or axial-flow
impeller the flow strictly parallels to the axis of rotation.
Further the impeller can be clasified into (a) Single - suction
impeller (b) Double suction
impeller In a single-suction impeller, the liquid enters the
suction eye on one side only. As a
double-suction impeller, the liquid enters the impeller
simultaneously from both sides. Wearing Rings Wearings are
generally fitted at the close - clearance position in the pump
casing and at
an apposing position on the impeller, which allows easy
restoration of the design clearnace to separate the discharge
pressure zone of the pump from the suction pressure areas and to
minimise back leakage. Many high - pressure centrifugal pumps are
fitted with wearing rings at the back sides (disc) of the impeller.
This reduces the thrust force on the impeller, at the same time
minimizing the stiffing box pressure.
Nozzles Many horizantal pumps all provided with suction and
discharge nozzles on the top of the
casings. In some horizontal pumps, suction nozzles are located
at the end of the pump co-axial with the shaft centre line. In
horizontally split pumps positioning of the nozzles in the bottom
half of the casing so that the bottom half does not have to be
disturbed during maintenance.
Stuffing boxes Stuffing boxes have the primary function of
protecting the pump against leakage at the
point where the shaft passes out through the pump casing. If the
pump handles a suction lift and the pressure at the interior
stuffing box end is below atmospheric, the stuffing box function is
to prevent air leakage in to the pump. If this pressure above
atmospheric, the function is to prevent liquid leakage out of the
pump. Conventional stuffing boxes are filled with either packing
material, such as braided rope or with a mechanical shaft seal.
Bearings The function of bearings in the centrifugal pumps is to
keep the shaft or rotor in correct
alignment with the stationary parts under the action of radial
and transverse loads. Those that give radial positioning to the
rotor are known as line bearings, where as those that locate the
rotor axially are called thrust bearings. All types of bearings
have been used in centrifugal pumps.
DIFFERENCE BETWEEN HORIZONTAL PUMPS & VERTICAL PUMPS
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HORIZONTAL VERTICAL
1 Shaft orientation is horizontal (ex.) End suction, Horizontal
split
Shaft orientation is vertical (ex.) vertical turbine pump,
vertical condensate pump etc.
2 Pump supported by casing & foot support
Pump supported by suspended column
3 Location of suction nozzle can be end, side, bottom or top
suction
Only bottom suction is possible.
4 Occupies more floor space
Less floor space is requried
5 Mechanical cost :
Cost of pump-motor set is low Cost of pump-motor set is high (2
to 3 times)
Installation cost is low Installation cost is high
cost of piping & valves is higher for all application due to
additional shut off valve and expansion bellow in the suction
line.
The same is not required.
6 Civil cost : (2 to 6 times more)
For all application horizontal pumps have to be located below
the minimum water level of respective reservoir to facilitate
flooded suction of pump and this requires excavation (Dry pit) of
soil adjacent to respective reservoir sump.
Vertical pumps can be directly located inside the respective
reservoir sumps and requires excavation (sum pit) for submergence
of pump below minimum water level within the reservoir sump, which
is nominal compared to excavation required for horizontal pump dry
pit.
Cost of substruction like dry pit for horizontal pump is
high
Cost of substruction like pump resting slab and sump pit is
low.
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HORIZONTAL VERTICAL
Horizantal pumps will have to be
located indoor due to the requirement of a dry pit and so cost
of super structure is an additional cost. For fire water pumps cost
of super structure is higher in case of horizantal pumps due to
higher floor space requirements.
Cost of super structure is low since vertical pump can be
located in outdoor.
7 Other cost : Other cost like crane rails, electrical cables,
lighting, ventilation etc. will be higher with horizantal type pump
because of greater length of pump house.
8 maintenance cost is low Maintenance cost is very high
9 Efficiency is high Efficiency is low due to transmission
loss.
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FORM T10 REV - A
MERITS/DEMERITS OF PLATE TYPE HEAT EXCHANGERS BLOW DOWN,
General :-
The plate type heat exchanger is an assembly of corrugated
plates held between the stationary and follower plate with the help
of long tie bolds.
Classifications of plate heat exchanger
a. Gasketted plate heat exchanger
b. Semi-welded plate heat exchanger
c. Double wall plate heat exchanger
d. Wide gap plate heat exchanger
e. Flow flex, the tubular plate heat exchanger
f. Graphite, plate heat exchanger
g. Plate evaporator
h Brazed plate heat exchanger
i. Fully - welded plate heat exchanger
Merits of plate heat exchanger
Low investment cost : High efficiency and their sheet Materials
result in economical units, practically when expensive Materials
are required.
Easy Maintenance : A PHE can generally be cleaned by operating
the unit
with chemical detergents for a short period. Should a heat
exchanger need to be opened for inspection or cleaning, the heating
surface is 100% accessible simply by removing the tightening
bolts.
Small space requirement : The PHE is extremely compact in
design, relation to
its capacity and it does not require any extra space for service
or Maintenance.
Great Thermal Efficiency /close : Plate pattern are designed to
induce a high degree of
Temperature Approach turbulence which reduces fouling and
improves heat transfer. This high turbulence in full counter
current flow makes it economically feasible to use temperature
approaches down to 1C
Flexibility : With in a couple of hours, the PHE can be
redesigned simply by adding, removing or rearranging plates
within the length of the frame. Extended frame capacity can be
supplied if the original capacity is expected to increase
radically.
Lower Cooling Water
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FORM T10 REV - A
Flow Rate : Owing to identical channel geomentries as well as
high thermal efficiency for both fluids, the PHE greatly reduces
the cooling water flow rate. This in turn means lower installation
costs for piping, valves and pumps.
Low hold up volume : The thin channels mean that the liquid
volume is low
in comparison to other types of heat exchangers. This ensure
quick process control and reduces total installation weight.
Low weight : The compact design and their plate materials
contribute to a low weight heat exchanger. A higher weight heat
Exchanger in turn requires smaller foundations.
No vibrations : The Metal to Metal contact between plates means
a
rigid plate free from vibrations. No welds : The absence of
welds considerably reduces
expensive non-destructive test procedures. Demerits of Plate
heat Exchangers Pressure drop : Pressure drop across the fluid is
high when
compared to shell & tube type. Cost : Slightly higher when
lower grade material are used
(such as carbon steel). Pressure : Not suitable for high
pressure service Application : PHE is not used in condensing plant,
vapourising,
super heating system. : Gaseous fluids not recommend to use in
PHE
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FORM T10 REV - A
Gasket Material Selection with respect to Temperature &
Application :-
Gasket Material Max. Temp. C Application
Nitrite rubber 135 Fatty Materials Butyl rubber 150 Aldehydes,
Ketones &
esters. Ethylene propylene
rubber 150 High temp resistance
to a variety of chemicals
Viton 175 Minerals, vegetable & animal oils, fuels
Compressed asbestos 260 Organic solvents eg. chlorinated
hydrocarbons.
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WATER COOLED SURFACE CONDENSER SIZING
Introduction Power plant condenser receives exhaust steam from
the low pressure turbine and
condenses it to liquid for reuse. The surface condenser serves
three important functions :
# Provides a low back pressure at the turbine exhaust to
maximise plant
thermal efficiency and reduce the heat rate. # Conserves the
high purity water for reuse in the boiler-turbine system to