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Unburned Carbon Versus CO2 Emission
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Unburned Carbon In the fly ash
UBC versus COUBC versus CO22 Emission Emission
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Coal bin
Mill
Precipitator
Air preheaterBurner
Air fan
Intermediate
storage tank
Pul
veriz
ed f
uel
-
Air
Flue gas
Fly ash
Sec
onda
ry a
ir
Prim
ary
air
Coal
UBC
AirSteam Generator
Heat Input: •CoalLosses: •Flue gas heat loss•Gaseous LOI (CO)•Unburned Carbon•Radiation•Ash Heat Loss
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Combustion Heat Loss
Boiler radiationheat loss
Unburned carbonin ash
Sensible ashheat loss
Power Station Basis Data (example):
Mean continuous load (Basis: steam production) 100 %
Full-load (100% MCR) operating hours per year 6 000 [hrs]
Coal mass flow (100% load) 300 [shtn/h]
Excess air ratio (100% load) 1.25 –
Gross heat input (calculated for 100 % load) 7 109 [BTU/hr · 106]
Gross electric power output (100% load) 750 [MWel]
Net power efficiency 36 [%]
5.5%1.11%
CO
Flue gas heat loss Otherlosses
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Sources of Improvement
CO
Carbonin ash
Flue gas heat loss improvement(0.43 % absolute)
Other improvements(0.13 % absolute)
Goals of good combustion practice:
Reduction of excess air 5 [%-points]
Reduction of fly ash carbon content 1 [%-points]
Reduction of CO 80 [ppmdv]
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Total boiler losses6 % (absolute)
reduction in flue gas heat loss
reduction in solid LOI (carbon in ash)
reduction in gaseous LOI (CO)
total fuel heatsavings = 0.57 %
Savings in CO2 emissions: 26 493 shtn/a CO2 emission credit
Assumed market price within intern. CO2 emission trading system: 5 $ per ton 132 000 $ per year
0.43%
0.04%
0.10%
reduced CO2 emission
Fuel savings: 10,000 shtn/yr at 30 US$ per shtn:300 000 US$ per year
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Coal bin
Mill
Precipitator
Air preheaterBurner
Air fan
Intermediate
storage tank
Pul
veriz
ed f
uel
-
Air
Flue gas
Fly ash
Sec
onda
ry a
ir
Prim
ary
air
Coal
UBC
AirSteam Generator
Heat Input: •Coal mass flow & CVLosses: •Flue gas temperature & O2
•CO•Unburned Carbon in Fly AshCoal analysis (Ash Content)•Ash Temperature
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MECONTROL UBC Sensor
Screw Measuring Chamber
DriveShaft
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Dielectric constant of fly ash is a function of the carbon content. Measuring the shift of frequency in a resonator ( f) the carbon content can be calculated.
MECONTROL UBC Measurement Principle
UBC = A + B f
A and B are the calibration coefficients
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we focus on your process
Measurement Data of MECONTROL UBC
Wedel
0
100
200
300
400
500
600
700
800
900
1000
18.07.200100:00
20.07.200100:00
22.07.200100:00
24.07.200100:00
26.07.200100:00
28.07.200100:00
Re
st-
C [
0,0
1%
]
0
100
200
300
400
500
600
700
800
900
1000
Kanal 2
Kanal 3
Temperatur Kanal 2
Temperatur Kanal 3
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we focus on your process
Trial run at BEWAG "Reuter West" power plant
170
165
160
155
150
145
140
135
130
125
06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00 16:00 17:00 18:00
Time
Sec
on
dar
y A
ir x
100
0 (i
nve
rted
) [m
³/h
] S
TP
1
2
3
4
5
6
7
8
9
10
UB
C [
%]
Secondary Air (MECONTROL Air)
UBC ETG 17 (MECONTROL UBC)
UBC ETG 18 (MECONTROL UBC)
Remark: Listed values of secondary air amount are only for one burner plane.
1 % O2
Result of SA Reduction Trial Run
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Result of SA Reduction Trial Run
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Boiler Optimization Program
0
2
4
6
8
10
12
14
16
18
7:00 7:30 8:00 8:30 9:00 9:30 10:00 10:30 11:00 11:30 12:00 12:30 13:00 13:30 14:00 14:30 15:00 15:30 16:00 16:30 17:00
Time
UB
C [
%];
CO
x10
[m
g/m
³] S
TP
0
0,5
1
1.5
2
2.5
3
3.5
4
4.5
O2
[%]
UBC Fly ash (MECONTROL UBC)UBC Fly ash (Lab analysis)
CO StackO2 Boiler / DeNOx outlet
Trial run at BEWAG "Reuter West" power plant
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Parameters for Efficiency Improvement
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Boiler Optimization Program
UBC
at 7.2 % A
General calculation example with parameter variationBasis: 5 % UBC in fly ash; 4.3 % O2 in flue gas
0.00%
0.05%
0.10%
0.15%
0.20%
0.25%
0.30%
0.35%
0.40%
0.45%
0% 1% 2% 3% 4% 5% 6%
UBC in fly ash
Incr
ease
in e
ffic
ien
cy*
*) Without power savings of fans
at 3.6 % A
UBC
O2
Excess air reduction most efficient !
O2-content of flue gas; UBC in fly ash
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Boiler / Mill Optimization by UBC Monitoring
Excess air: nabs= 7.6 %-pts
= 0.5 %-pts
2
3
4
5
6
7
8
Time
UB
C
[wt.
-%];
O2 [
vol.
-%]
200
220
240
260
280
300
320
340
360
380
400
Sec
on
dar
y ai
r x
1000
[m
³/h
r] S
TP
O2 right duct
UBC Basis: ash = 3.6 %
Secondary air Basis: n = 1.259
O2 left duct
Trial run at “Wedel” power plant
UBC: Cabs = -2 %-pts
= -0.08 %-pts
Resulting efficiency increase: 0.42 %-pts !
Excess Air Reduction
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Boiler / Mill Optimization by UBC Monitoring
Datteln
02468
101214161820
09.08.00:00
11.08.00:00
13.08.00:00
15.08.00:00
17.08.00:00
19.08.00:00
21.08.00:00
23.08.00:00
25.08.00:00
27.08.00:00
29.08.00:00
Re
st-
C [
%]
Kanal 0 geglättet
Mittelwert Kanal 0
Coal type change
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2
2,5
3
3,5
4
4,5
5
10:00 11:12 12:24 13:36 14:48 16:00 17:12
O 2
[V
ol.
-%]
500
520
540
560
580
600
620
NO
x [m
g/m
³]
O2 boiler out NOx before Kat.
SA2 TA SA1+CA
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Boiler Optimization Program
750 MW units Germany
Amonia savings15%
Fuel Savings36%CO2 sales
27%
Ash benefication ?
22%
savings potential
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savings potential
Boiler Optimization Program
750 MW units USA
NOx credits55%
Fuel Savings22%
CO2 sales17%
Ash benefication ?
6%
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savings potential
Boiler Optimization Program
$0,000$50,000
$100,000$150,000$200,000$250,000$300,000$350,000$400,000$450,000$500,000
Nox credits/Amonia Fuel Savings CO2 sales Ash benefication ?
Savings pa 750 MW unit
US
Germany
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Determine the O2/UBC, O2/CO and O2/NOx impact due to different air admission (Secondary air, Tertiary air, Overfire air, etc.)
Change overall O2-level on the back pass with favorable excess air supply
Run boiler with optimized O2-settings
Action Items for UBC Control
Boiler Optimization Program