closed feed water heaters
TRANSCRIPT
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A Train of Closed Feed Water Heaters
A Trade off between Irreversibility and Reliability !!!
P M V SubbaraoProfessor
Mechanical Engineering Department
I I T Delhi
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Diagram of Large Power Plant Turbine
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Typical Modern Power Plant Turbine
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HP Turbine Rotor
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LP Turbine Rotor
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LP Turbine Rotor
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Condenser
Block Diagram of A Large Steam Turbine
Reheat Steam
HP
Main Steam
Steam for
Reheating
IPIP
LPLP
CFWH 6 CFWH 5
OFWH 4
CFWH 2
CFWH 1
CFWH 3
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Thermodynamic Analysis of A Power Plant
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34.520
0.057
M
7.135
KCAL/KG
34.700
735.8
683.2
15.87
61.067 424.534.700 3
09.4
200.0
639.314
HEAT RATE=1985.05 K CAL/KW
Radiation losses are Ignored
210.3
206.0
639.314
61.067
256.21
0.000M
247.0
6.0
K
0.0K
D
38.54
205.5
170.0
172.0
509.026
124.0
6.414
639.31495.766
T/HR CEL
162.1
160.7
205.5
639.314
6.0
K
0.0K
168.3
164.1
12
0.8
12
1.3
34.520
6.564
26.299
2.269
2.8K
195.5
740.70352.2
2.154
M
0.024
M
0.935
M
2.186
M
740.70
352.2
61.067
40.57
740.70
350.4
40.57
572.218
14.970 M
639.314
816.06
537.0
ABC
150.0
A
1.251
M
0.701
M
0.018
M
0.043
M
0.946
M
537.0
843.89
789.916.70789.9
423.0
572.156
36.52
CB C B
4.352 M
777.2 H
B
A
0.4361 619.864.846 M
D
C
123.8
95.0
95.0
76.2
76.3
58.8
509.026
92.4
509.026 92.2
26.299
43.183
72.7
72.6
63.693
63.693
58.8
3.7K
0.5616
16.883
2.8K
106.8
642.9
0.4143
20.510
619.8
76.
5
509.028
509.028
D
77.96
49.2
49.0
20.510
47.0
0.299M
46.8
99.9
99.9
0.299
46.3
46.7
46.446.1
509.028
D12.0
K
509.0280.1033
19.38748.8H
0382M
0.078
M
16.833
0.9069
26.299
2.389 683.2
195.8
310.0
735.8
642.9
107.1
310.0
735.8
506.53
7.135
C B C
0.382
0.078
577.3
P=210.061 MW
46.45441.114
0.1033
3.068 M
B
0.854 MD
G
B C
2
kg
cm
LAYOUT OF MODERN 210 MW COAL FIRED POWER PLANT
THERMODYNAMIC CYCLE OPTIMIZATION
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THERMODYNAMIC CYCLE OPTIMIZATION
Effect of Higher Steam Conditions on Unit Performance
As the first step in the optimization of cycle steam conditions, thepotential cycle efficiency gain from elevating steam pressures andtemperatures needs to be considered.
Starting with the traditional 165 bar/5380C single-reheat cycle,
dramatic improvements in power plant performance can be achievedby raising inlet steam conditions to levels up to 310 bar andtemperatures to levels in excess of 600 C.
It has become industry practice to refer to such steam conditions, and
in fact any supercritical conditions where the reheat steam temperaturesexceed 566 C, as ultrasupercritical.
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Heater Selection and Final Feedwater Temperature
In order to maximize the heat rate gain possible with ultrasupercritical
steam conditions, the feedwater heater arrangement also needs to be
optimized.
In general, the selection of higher steam conditions will result in additional
feedwater heaters and a economically optimal higher final feedwater
temperature.
In many cases the selection of a heater above the reheat point (HARP) willalso be warranted.
The use of a separate desuperheater ahead of the top heater for units with a
HARP can result in additional gains in unit performance.
Other cycle parameters such as reheater pressure drop, heater terminal
temperature differences, line pressure drops and drain cooler temperature
differences have a lesser impact on turbine design, but should also be
optimized as part of the overall power plant cost/performance trade-off
activity.
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Analysis of Regeneration through CFWH
81 hhmQ SGin
Definey as fraction of mass extraction:
SC
extraction
m
my
SGm
SGmy
SGm
ymSG 1
47431 hhyhhymQ SGout
3221
1 hhyhhmW SGturbine
45 hhmWpump
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Energy Balance for CFWH
5SG&hm
2&hymSG
8&hmSG
6258hhymhmhm SGSGSG
5862hhyhh
62
58
hh
hhy
7&hymSG
6&hymSG
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HP Closed Feed Water Heater
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DS
TTD
Feedwater heater with Drain cooler and Desuperheater
-TTD=Terminal
temperature difference
C=Condenser
DC=Drain cooler
DS=Desuperheater
Bled steam
T
L
DCC
Condensate
CDC
Feed Water in
DS
Bleed Steam
Feed Water out
5SG &hm
2&hymSG
8&hmSG
6&hymSG
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Desuperheating Zone - The integral desuperheating zone
envelopes the final or hotest feed water pass and is thermally
engineered to assure dry wall tube conditions with a minimum
zone pressure loss.
Dry wall conditions in this zone provide maximum heat recovery
per square foot of transfer surface by taking full advantage of
the available temperature differential between the superheated
steam and the feedwater.
Dry wall conditions also prevent flashing, which is detrimental to
proper desuperheating zone operation.
All desuperheating zones are analyzed to make sure they are
free of destructive vibration.
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HP Closed Feed Water Heater
Desuperheater
Condensing Shell Drain Cooler
HP Turbine
TRAP
Tbi, pbi, Tbsi
Tfi+1Tfi
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Desuperheater
Condensing Shell Drain Cooler
TRAP
Tbi, pbi, Tbsi
Tfi+1Tfi
Tube length
Tf
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LP Closed Feed Water Heater
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LP Closed Feed Water Heater
Condensing Shell Drain Cooler
LP Turbine
TRAP
Tbi, pbi, Tbsi
Tfi+1Tfi
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Drain Subcooling Zone - When the heater drains temperature
is required to be lower than the heater saturation temperature, a
drain subcooling zone is employed.
The drain subcooling zone may be either integral or external,
and as a general rule, it is integral.
The integral drain subcooling zone perates as a heat exchanger
within a heat exchanger, since it is isolated from the condensing
zone by the drain subcooling zone end plate, shrouding, and
sealing plate.
This zone is designed with generous free area for condensate
entrance through the drains inlet to minimize friction losses
which would be detrimental to proper operation.
The condensate is subcooled in this zone, flowing up and overhorizontally cut baffles.
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Condensing Shell
Drain Cooler
TRAP
Tbi, pbi, Tbsi
Tfin
Tfout
Tube length
Tf
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Work done by Bleed Steam
1h
2h
5h
8h
Work done by bleed (extracted) steam: 21hhywbleed
216258 hhhh
hhwbleed
6h
Closed Feed Water Heaters (Throttled
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Closed Feed Water Heaters (ThrottledCondensate) 1
2
3 4
56
78
9
10
11
12
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Analysis of Regeneration through Two CFWH
T
s
1
2
3
45
67
8
9
10
11
12
121hhmQ SGin
Definey as fraction of mass extraction:
SG
b
SG
b
m
my
m
my
2,
2
1,
1&
54215821 1 hhyyhhyymSGout
432132121
11 hhyyhhyhhmSGturbine
56 hhmWpump
E B l f LP CFWH
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Energy Balance for LP-CFWH
3211168219 hymhymhmhyymhm
6&hm
32&hym
9
&hm
821
&hyym
721
&hyym
111&hym
83
1181
83
692
hhhhy
hhhhy
E B l f HP CFWH
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Energy Balance for HP-CFWH
9&hm
21&hym
12& hm
111&hym
101&hym
1021912hhymhmhm
9121102hhyhh
102
912
1hh
hhy
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Work done by Bleed Steam
21102912
2111, hhhh
hh
hhymwbleed
31
83
118
1
83
69
3122,hh
hh
hhy
hh
hhhhymwbleed
31
83
118
102
912
83
69
3122,hh
hh
hh
hh
hh
hh
hhhhymwbleed
31
83
118
102
912
83
69
21
102
912
,hh
hh
hh
hh
hh
hh
hhhh
hh
hhw totbleed
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31
83
118
102
912
83
69
21
102
912
,hh
hh
hh
hh
hh
hh
hhhh
hh
hhw totbleed
T
s
1
2
3
45
67
8
9
10
11
12
21, unitext
HPbleed
wastebleed
HPbleed
HPfeed
LPbleed
LPfeed
unitext
HPbleed
HPfeed
totbleed wh
h
h
h
h
hw
h
hw
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Thermodynamic Analysis of A Power Plant
Train of Shell & Tube HXs
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Train of Shell & Tube HXs.
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0.0
K
D0.0
K
6.0
K
6.0
K
C
Variation of Feedwater Temperature and Enthalpy along the
FeedWater Heater
0
50
100
150
200
250
300
Temperature(C)
0
200
400
600
800
1000
1200
Enthalpy(kJ/kg)
Temperature
Enthalpy 6
5
4
3
21
DCGSC
6 5 43 2 1
DC
GSC
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The Mechanical Deaerator
The removal of dissolved gases from boiler feedwater is an
essential process in a steam system.
Carbon dioxide will dissolve in water, resulting in low pH
levels and the production of corrosive carbonic acid.
Low pH levels in feedwater causes severe acid attack
throughout the boiler system.
While dissolved gases and low pH levels in the feedwater
can be controlled or removed by the addition of chemicals.
It is more economical and thermally efficient to remove
these gases mechanically.
This mechanical process is known as deaeration and will
increase the life of a steam system dramatically.
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Deaeration is based on two scientific principles.
The first principle can be described by Henry's Law.
Henry's Law asserts that gas solubility in a solution decreases as
the gas partial pressure above the solution decreases. The second scientific principle that governs deaeration is the
relationship between gas solubility and temperature.
Easily explained, gas solubility in a solution decreases as thetemperature of the solution rises and approaches saturationtemperature.
A deaerator utilizes both of these natural processes to removedissolved oxygen, carbon dioxide, and other non-condensablegases from boiler feedwater.
The feedwater is sprayed in thin films into a steam atmosphereallowing it to become quickly heated to saturation.
Spraying feedwater in thin films increases the surface area of theliquid in contact with the steam, which, in turn, provides morerapid oxygen removal and lower gas concentrations.
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This process reduces the solubility of all dissolved gases and
removes it from the feedwater.
The liberated gases are then vented from the deaerator.
Correct deaerator operation requires a vessel pressure of about
2030 kPa above atmospheric, and
a water temperature measured at the storage section of 50C
above the boiling point of water at the altitude of the
installation.
There should be an 4560 cm steam plume from the deaerator
vent, this contains the unwanted oxygen and carbon dioxide.
The following parameters should be continuously monitored to
ensure the correct operation of the deaerator.
Deaerator operating pressure.
Water temperature in the storage section.
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Principle of Operation of A Dearator