United States
Environmental Protection
Agency
Office of Air Quality
Planning and Standards
Research Triangle Park NC 27711
EMB Report 84-TRB-7
September 198^'
Air
Stationary
Gas Turbine
Emission Test Report
Crown Zellerbach
Antioch Mill
Antioch, California
Volume I
-------
GCA-TR-84-27-G
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Air Quality Planning and Standards
Emissions Measurement Branch
Research Triangle Park, NC
Contract No. 68-02-3851
Work Assignment No. 6
George Walsh - Project Officer
Terry Harrison - Task Manager
EMISSION TEST REPORT
CROWN ZELLERBACH
ANTIOCH MILL
ANTIOCH, CALIFORNIA
VOLUME I
Final Report
September 1984
Prepared by
John W. Podlenski
Donald Neal
Michael 0. White
John Foley
GCA CORPORATION
GCA/TECHNOLOGY DIVISION
Bedford, Massachusetts 01730
-------
DISCLAIMER
This Final Report was furnished to the Environmental Protection Agency by
the GCA Corporation, GCA/Technology Division, Bedford, Massachusetts 01730, in
fulfillment of Contract No. 68-02-3851, Work Assignment No. 6. The opinions,
findings, and conclusions expressed are those of the authors and not
necessarily those of the Environmental Protection Agency or the cooperating
agencies. Mention of company or product names is not to be considered as an
endorsement by the Environmental Protection Agency.
-------
CONTENTS
VOLUME I
Figures v
Tables vi
1. Introduction 1
2. Summary and Discussion of Results 2
3. Process and Control Equipment Description and Operating
Conditions 25
Process Description 25
Operating Conditions 25
4. Sampling Locations 29
Duct Burner Inlet 29
Duct Burner Outlet 29
5. Sampling and Analytical Procedures 35
Overview 35
Measurement of Flue Gas Emissions 35
Velocity and Moisture Measurements 50
Measurement of Gas Turbine and Duct Burner Parameters ... 50
Fuel Sampling and Analysis 52
6. Program Quality Assurance 53
Introduction 53
Precision, Accuracy and Completeness 53
Data Validation 59
Deviations from the Quality Assurance Plan 60
References 61
Appendix
A. Results and Calculations A-l
111
-------
CONTENTS (continued)
VOLUME II
Appendices
B. Velocity Traverse Field Data B-l
C. Moisture Determination Field Data C-l
D. Duct Burner Process Data D-l
E. Response Time and Stratification E-l
F. Drift and Precision Limit Calculations F-l
G. Relative Accuracy Field and Reduced Data G-l
H. Fuel Analysis Data H-l
I. Calibration Gas Certification 1-1
J. F Trend Data J-l
VOLUME III
Appendices
K. Daily Calibration Data K.-1
L. 15-Minute Average Data Summary L-l
M. Raw Voltages M-l
IV
-------
FIGURES
Number Page
1 General layout of Crown Zellerbach cogeneration power plant . . 26
2 Crown Zellerbach cogeneration facility schematic 30
3 Duct burner inlet sampling location 31
4 Duct burner inlet sampling port and point locations 32
5 Duct burner outlet (stack) sampling location 33
6 Duct burner outlet (stack) sample point locations 34
7 Schematic of gas turbine/duct burner sample locations 36
8 Data acquisition system schematic 40
.9 Mobile laboratory flow schematic 41
10 Valve switching box configuration 42
11 Wet sample conditioning system 43
12 Dry sample conditioning system 44
13 Sample distribution system 45
14 CEM sample probe 46
15 Schematic of RAC Staksamplr^M in particulate sampling
configuration 49
16 Schematic of RAC Staksamplr in particulate sampling
configuration 51
-------
TABLES
Number
1
2
3
4
5
6
7
8
y
10
11
12
13
14
15
16
Duct Burner
Duct Burner
1600 - 22(
Duct Burner
1130 - 16:
Duct Burner
1615 - 201
Duct Burner
1015 - 16]
Duct Burner
1000 - 16:
Duct Burner
0900 - 15(
Duct Burner
1000 - 17(
Duct Burner
1830 - 23:
Duct Burner
Duct Burner
Duct
Duct
Duct
Duct
Duct
Burner
Burner
Burner
Burner
Burner
Test
Test
)0 . ,
Test
JO . ,
Test
L5 . .
Test
L5 . ,
Test
JO . ,
Test
)0 . ,
Test
)0 . ,
Test
JO . ,
Test
Test
Test
Test
Test
Test
Test
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Data:
Test
Test
Test
Test
Test
Test
Test
Test
Test
GEM
GEM
GEM
GEM
GEM
GEM
GEM
Condition
Condition
Condition
Condition
Condition
Condition
Condition
Condition
Condition
Summary
1, Day
2,
3,
4,
5,
6,
7,
8,
Test Periods
Test Periods.
Test Periods.
Test Periods.
Test Periods.
Test Periods.
Test Periods.
Day
Day
Day
Day
Day
Day
Day
Test
Test
Test
Test
Test
Test
23,
18,
16,
24,
19,
23,
20,
15,
Time
Time
Time
Time
Time
Time
Time
Time
Condition 2 . .
Condition 3 . .
Condition 8 . .
Condition 9 . .
Condition 10 . .
Condition 11 . .
Page
3
4
5
6
7
8
9
10
11
14
15
16
17
18
19
20
VI
-------
TABLES (continued)
Number Page
17 Duct Burner Test Data: CEM Test Periods. Test Condition 12 .. 21
18 Duct Burner Test Data: CEM Test Periods. Test Condition 13 .. 23
19 Duct Burner Test Data: CEM Test Periods. Test Condition 14 .. 24
20 Test Conditions for Characterizing Duct Burner Emissions ... 27
21 Operating Conditions Used to Categorize CEM Data 28
22 Duct Burner Test Program Measurement Parameter Summary .... 37
23 Sampling Parameters and Methodology for CEMS 39
24 Calibration Gas Concentrations 50
25 QA Results for Measurements Taken at the Duct Burner Inlet . . 54
26 QA Results for Measurements Taken at the Duct Burner Outlet . . 55
27 Monitor Drift Check During Test Periods 57
Vll
-------
SECTION 1
INTRODUCTION
The objective of this test program was to investigate the effect of a
duct burner on emissions in a typical industrial gas turbine cogeneration
system. The test program was conducted on a cogeneration power plant located
at Crown Zellerbach's recycle paperboard plant in Antioch, California. The
cogeneration power plant consists of a 36 MWe gas turbine which is exhausted
through a duct burner and waste heat boiler. The unit supplies the total
facility's steam and electrical needs, and excess electricity is sold to the
local utility. Steam injection is used to control NOX in the gas turbine.
The duct burner uses a rich-lean staged design to limit NOX.
Emissions were characterized from the duct burner as a function of gas
turbine and duct burner operating parameters. Measurements were conducted
using an EPA IERL/RTP Mobile Continuous Emissions Monitoring System. NOX,
CO, 02, and C02 were monitored concurrently at the duct burner inlet
location and the waste heat boiler stack. Flue gas velocity was continuously
monitored at the waste heat boiler stack. In addition, flue gas moisture was
measured at the inlet and outlet sampling location and flue gas velocity was
measured at the outlet using manual test methods.
This report summarizes emissions testing conducted by GCA/Technology
Division on the cogeneration facility from January 15-24, 1984. Included in
this report is a summary of test results and procedures with associated
documentation of field test data, reduced test data, and test conditions.
Applicable pretest data, field data, and reduced data are presented in the
appendices.
-------
SECTION 2
SUMMARY AND DISCUSSION OF RESULTS
Emission testing was conducted at eight gas turbine and duct burner
operating conditions defined to characterize the effect of the duct burner on
NOX emissions. For these eight test conditions, plant operators deviated
from their normal operation and maintained the duct burner fuel consumption at
relatively constant firing rates to facilitate the test program.
In addition to these eight test periods, data were gathered for other
operational periods where duct burner fuel consumption rate was controlled by
the facility's steam demand. These data were divided into nine test
conditions based on gas turbine and duct burner firing rates. Results from
the eight duct burner test conditions and the nine additional operational
periods are presented and discussed in this section.
An overall summary of NOX emission data from the eight test conditions
is shown in Table 1. Included in the table are gas turbine, duct burner, and
waste heat boiler operational parameters, as well as measured emission rates
from the gas turbine (duct burner inlet), waste heat boiler (duct burner
outlet), and the change in NOX emissions across the duct burner calculated
by difference. The data presented in Table 1 are mean.operational and
emission values averaged over the test intervals based on hourly means for
each test.
Tables 2 through 9 present summaries of hourly emission data for tests 1
through 8. The tables list hourly averages of process and emission values
with the mean and standard deviation of each parameter for each test.
Process measurement data were obtained from gas turbine and duct burner
control room logs. Fuel flow rates are reported at 60°F and 14.7 psi. Duct
burner load percent is based on a full load heat input of 163 MBtu/hr.
Reported moisture values for inlet and outlet locations are calculated
from combustion moisture based on the fuel analysis, measured steam injection
rates to the gas turbine, and local ambient humidity. Comparison of
calculated moisture to moisture measured by Reference Method 4 procedures
indicated consistency to within 1 percent by volume or less.
Volumetric flow rate was determined from measured velocity and calculated
flow rate based on transducer readings and duct burner fuel flow. Outlet flow
rates were determined based on velocity and temperature measurements made at
the waste heat boiler stack location. Inlet flow rates were calculated from
-------
TABLE 1. DUCT BURNER TEST DATA: TEST CONDITION SUMMARY
Gas turbine
operating parameters
Test
condition
1
2
3
4
5
6
7
8
Load
(MW)
31.8
35.0
34.5
32.0
32.8
31.5
33.0
11.1
Fuel
flow
(scim)
7,323
7,470
7,416
7,065
7,235
7,062
7,284
3,402
Steam
inj. ratio
(Ib/lb)
0.94
0.97
0.95
0.50
0.46
0.00
0.00
0.00
Duct burner
operating parameters
Fuel
flow
(scfm)
2,149
1,500
656
2,210
703
2,197
675
2,265
Heat
input
(10& Btu/hr)
133.8
93.3
40.8
137.5
43.8
136.7
42.0
140.9
Load
(percent)
82.1
57.3
25.0
84.4
26.8
83.9
25.8
86.5
Boiler
operating parameters
Total steam
flow
(Ib/hr)
263,000
265,500
224,300
174,800
212,300
278,300
201,300
189,900
Steam
press
(psig)
584
589
588
589
581
594
591
589
Ambient conditions
Temp
(°F)
59
53
58
62
57
59
47
50
Pressure
(in hg)
30.3
30.2
30.2
30.3
30.3
30.3
30.3
30.3
Relative
humidity
48.0
69.5
59.5
25.0
39.0
54.0
72.5
88.5
Duct burner inlet
Test
condition
1
2
3
4
5
6
7
8
H20
(X)
9.2
9.5
9.5
8.0
7.8
6.5
6.8
4.8
QS
(dscfm
x 103)
199.1
191.8
198.8
198.9
200.9
204.9
209.4
143.5
°2
(*
dry)
15.0
14.7
14.9
15.0
15.0
15.2
15.0
17.2
CO,
(*
dry)
3.6
3.4
3.4
3.5
3.4
3.4
3.3
1.97
CO
(ppm
dry)
5
3
1
7
1
4
1
23
NOX
(ppm
dry)
43
43
40
60
66
109
111
29
NOX
(ppm
iso)
42
40
39
56
63
107
110
46
NOX
(Ib/MBtu)
0.149
0.142
0.134
0.207
0.22B
0.392
0.384
0.157
NOX
(Ib/hr)
61.4
58.8
57.5
85.8
95.2
159.7
166.7
29.1
H20
(*)
11.5
11.2
10.6
9.9
8.9
8.8
7.7
7.4
QS
(dscfm
x ID3)
196.9
190.3
198.1
196.7
200.2
202.7
208.8
141.3
Duct burner outlet
02
(%
dry)
12.6
13.1
13.7
12.8
13.9
12.7
14.0
14.5
C02
(%
dry)
4.75
4.28
3.91
4.73
3.83
4.66
3.80
3.45
CO
(ppm
dry)
24
16
15
16
8
12
8
25
NOX
(ppm
dry)
40
43
41
60
65
108
105
41
NOX
(Ib/hBtu)
0.097
0.113
0.118
0.151
0.192
0.270
0.313
0.132
NOX
(Ib/hr)
55.7
58.9
58.7
83.9
94.0
156.2
156.7
42.1
Change
across
DB
NOX
(lb/:.r)
-5.7
0.1
1.2
-1.9
-0.0
-3.3
-10.0
1*.7
-------
TABLE 2. DUCT BURNER TEST DATA: TEST CONDITION 1, DAY 23, TIME 1600 - 2200
Gas turbine
operating parameters
Time
period
1600 - 1700
1700 - 1800
1800 - 1900
1900 - 2000
2000 - 2100
2100 - 2200
Avg
S.D.
Load
(MW)
32.9
32.9
33.9
34.2
34.3
34.5
33.8
0.7
Fuel
flow
(scim)
7,142
7,206
7,351
7,39b
7,446
7,455
7,333
143
Steam
inj. ratio
Ub/lb)
0.946
0.950
0.961
0.915
0.920
0.932
0.937
.028
Fuel
flow
(scfm)
2,198
2,202
2,190
2,189
2,187
1,932
2,149
210
Duct burner
operating parameters
Heat
input
(106 Btu/hr)
136.7
137.0
136.3
136.2
136.1
120.2
133.8
13.1
Load
(percent)
84
84
84
84
83
74
82
8.0
Boiler
operating parameters
Total steam
flow
(Ib/hr)
301,700
303,100
304,900
302,400
186 ,500
177,600
263,000
58,407
Steam
press
(psig)
590
585
578
585
583
585
584
6.6
Time
period
1600 - 1700
1700 - 1800
1800 - 1900
1900 - 2000
2000 - 2100
2100 - 2200
Avg
S.D.
Note: Means
H20
(%)
8.9
9.2
9.3
9.2
9.2
9.3
9.2
0.16
and Sti
QS
(asctm
x 103)
201.2
200.3
198.9
198.4
198.1
197.6
199.1
1.5
andard
°2
i (X
ary)
15.00
14.97
14.97
14.94
14.92
14.93
14. 9b
0.03
Duct
CO 2
a
dry)
3.60
3.56
3.54
3.55
3.64
3.64
3.59
0.05
burner
CO
(ppm
dry)
5
6
6
6
5
4
5
0.8
calcula
inlet
NOX
(ppm
dry)
44
43
41
43
44
44
43
1.2
Duct burner outlet
NOX
(ppm
iso)
41
41
40
43
43
43
42
1.3
NOX
(Ib/MBtu)
0.154
0.148
0.142
0.149
0.150
0.149
0.149
0.004
ninute averai
NOX
(Ib/hr)
63.8
61.6
58.4
61.4
62.0
61.5
61. 4
1.6
zes .
H20
W
11.3
11.5
11.7
11.5
11.5
11.7
11.5
0.17
QS
(ascfm
x 103)
199.0
198.1
196.7
196.2
195.9
195.6
196.9
1.5
%
dry)
12.56
12.56
12.58
12.60
12.60
12.59
12.58
0.019
«>2
(%
dry)
4.78
4.77
4.73
4.74
4.74
4.74
4.75
0.50
CO
(ppm
dry)
21
21
26
25
25
26
24
2.4
NOX
(ppm
dry)
42
41
38
39
39
39
40
1.5
NOX
(Ib/MBtu)
0.103
0.100
0.093
0.096
0.096
0.097
0.097
0.003
NOX
(Ib/hr)
59.5
57.5
53.1
54.8
54.5
55.2
55.7
2.3
Change
across
DB
NOX
(lb/r.r)
-4.3
-4.i
-5.3
-6.7
-7 .5
-6.4
-5 .7
i.o
-------
TABLE 3. DUCT BURNER TEST DATA: TEST CONDITION 2, DAY 18, TIME 1130 - 1630
Gas turbine
operating parameters
Time
period
1130 - 1230
1230 - 1330
1330 - 1430
1430 - 1530
1530 - 1630
Avg
S.D.
Load
(MW)
35.6
35.4
34.8
34.6
34.6
35.0
0.5
Fuel
flow
(scfm)
7,580
7,514
7,446
7,410
7,400
7,470
74
Steam
inj. ratio
(Ib/lb)
0.967
0.977
0.946
0.963
0.987
0.966
0.029
Duct burner
operating parameters
Fuel
flow
(SCFM)
1,497
1,498
1,501
1,502
1,501
1,500
2.5
Heat
input
(106 Btu/hr)
93.2
93.2
93.4
93.4
93.4
93.3
0.16
Load
(percent)
57.2
57.2
57.3
57.3
57.3
57.3
0.1
Boiler
operating parameters
Total steam
tlow
(Ib/hr)
222,200
309,200
267,100
263,800
264,800
265,500
58,360
Steam
press
(psig)
593
598
576
587
590
589
12
Duct burner inlet
Time
period
1130 - 1230
1230 - 1330
1330 - 1430
1430 - 1530
1530 - 1630
Avg
S.D.
H20
(X)
9.6
9.5
9.4
9.5
9.5
9.5
0.1
QS
(dscfm
ic 103)
204.7
207.4
201.5
187.9
157.8
191.8
23.2
°2
(X
dry)
14.72
14.73
14.73
14.74
14.75
14.73
0.01
C02
dry)
3.41
3.39
3.41
3.41
3.36
3.4
0.02
CO
(ppm
ory)
3
2
2
3
3
3
0.5
NOX
(ppm
dry)
42
43
43
43
43
43
0.4
(ppm
iso)
41
40
40
40
40
40
0.5
NO*
(Ib/Mbtu)
0.140
0.142
0.144
0.142
0.144
0.142
0.001
NOX
(Ib/hr)
62.0
63.4
62.3
57.5
48.7
58.8
6.9
H20
(X)
11.2
11.2
11.0
11.2
11.2
11.2
0.1
QS
(dscfm
203.1
205.9
200.0
186.4
156.3
190.3
23.2
Duct burner outlet
02
(X
dry)
13.11
13.08
13.04
13.02
13.02
13.05
0.04
C02
(X
dry)
4.28
4.29
4.29
4.28
4.29
4.28
0.008
CO
(ppm
dry)
16
15
16
ib
16
16
O.i
(ppm
dry)
44
44
42
43
44
43
0.9
(ib/MBtu)
0.116
0.114
0.109
0.113
0.114
0.113
0.004
(Ib/hr)
64.1
64.1
59.6
57.8
49.0
58.9
7.4
Change
across
DB
(ib/nr)
2.1
0.7
-2.7
0.2
0.3
U.I
2.5
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 4. DUCT BURNER TEST-DATA: TEST CONDITION 3, DAY 16, TIME 1615 - 2015
Gas turbine
operating parameters
Time
period
1615 - 1715
1715 - 1815
1815 - 1915
1915 - 2015
Avg
S.D.
Load
(MW)
34.0
34.5
34.7
34.7
34.5
0.4
Fuel
flow
(scfm)
7,378
7,415
7,421
7,449
7,416
37
Steam
inj. ratio
(Ib/lb)
0.953
0.952
0.953
0.956
0.954
0.008
Fuel
flow
(scfm)
662
651
655
655
656
6
Duct burner
operating parameters
Heat
input
(106 Btu/hr)
41.2
40.5
40.7
40.7
40.8
0.4
Load
(percent)
25.3
24.8
25.0
25.0
25.0
.2
Boiler
operating parameters
Total steam
flow
(Ib/hr)
223,900
224,200
223,800
225,400
224,300
2,427
Steam
press
(psig)
593
580
595
585
588
14
Duct burner inlet
Time
period
1615 - 1715
1715 - 1815
1815 - 1915
1915 - 2015
Avg
S.D.
H20
(*)
9.4
9.5
9.6
9.4
9.5
0.1
QS
(dscfm
x 103)
207.1
188.1
204.7
195.2
198.8
4.3
°2
(Z
dry)
14.73
14.70
14.69
14.81
14.73
0.05
C02
(%
dry)
3.35
3.35
3.38
3.40
3.37
0.02
CO
(ppm
dry)
2
1
1
1
1
0.5
NOX
(ppm
dry)
43
41
39
39
41
1.7
NOX
(ppm
iso)
39
38
37
37
38
1.0
NOX
(Ib/MBtu)
0.142
0.135
0.130
0.130
0.134
0.002
NOX
(Ib/hr)
63.2
55.0
57.9
54.0
57.5
1.3
H20
(X)
10.5
10.6
10.7
10.7
10.7
0.1
QS
(dscfm
x 103)
206.4
187.5
204.0
194.5
198.1
4.3
Duct burner outlet
°2
(%
dry)
13.72
13.73
13.71
13.72
13.72
0.01
CO 2
(%
dry)
3.90
3.90
3.91
3.92
3.91
0.01
CO
(ppm
dry)
15
15
16
15
15
0.5
NOX
(ppm
dry)
42
42
41
42
42
0.5
NOX
(Ib/MBtu)
0.118
0.119
0.116
0.119
0.118
0.001
NOX
(Ib/hr)
61.3
55.9
59.9
57.8
58.7
1.4
Change
across
OB
NOX
(Ib/hr)
-i.9
0.9
2.0
j.7
1.2
2.4
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 5. DUCT BURNER TEST DATA: TEST CONDITION 4, DAY 24, TIME 1015 - 1615
Gas turbine
operating parameters
Time
period
1015 - 1115
1115. - 1215
1215 - 1315
1315 - 1415
1415 - 1515
1515 - 1615
Avg
S.D.
Load
(MW)
33.0
32.2
31.6
31.8
31.7
31.4
32.0
.6
Fuel
flow
(scfm)
7,228
7,194
7,040
6,909
7,012
7,004
7,065
136
Steam
inj. ratio
(Ib/lb)
0.486
0.485
0.508
0.5U8
0.499
0.497
0.497
.02
Fuel
flow
(scfm)
2,188
2,226
2,255
2,211
2,196
2,190
2,210
35
Duct burner
operating parameters
Heat
input
(106 Btu/hr)
136.1
138.5
140.3
137.8
136.6
136.3
137.5
2.2
Load
(percent)
83.5
85.0
86.1
84.4
83.8
83.6
84.4
1.3
Boiler
operating parameters
Total steam
flow
(Ib/hr)
182,900
175,700
178,800
167,800
169,400
174,800
6,911
Steam
press
(psig)
590
590
593
583
587
589
7
Duct burner inlet
Time
period
1015 - 1115
1115 - 1215
1215 - 1315
1315 - 1415
1415 - 1515
1515 - 1615
Avb
S.D.
H20
(*)
7.8
7.8
7.9
7.9
7.9
8.4
8.0
6.3
QS
(dscfm
x 103)
203.7
203.2
197.7
196.7
195.7
196.2
198.9
3.6
02
(*
dry)
15.07
15.07
15.03
15.01
15.02
14.56
14.96
0.2
C02
(X
dry)
3.51
3.52
3.50
3.54
3.47
3.42
3.49
0.04
CO
(ppm
dry)
6
6
5
5
5
10
7
1.9
NO*
(ppm
dry)
62
62
60
60
60
59
60
1.2
NOX
(ppm
iso)
59
59
57
56
57
51
56
3.2
NOX
(Ib/MBtu)
0.217
0.216
0.210
0.208
0.209
0.191
0.207
0.011
NOX
(Ib/hr)
89.8
89.6
85.3
84.0
83.9
83.1
85.8
3.2
H20
(Z)
9.9
10.0
10.1
10.2
10.1
9.9
9.9
.5
QS
(dscfm
x ID3)
201.5
201.0
195.4
194.5
193.5
194.0
196.7
3.6
Duct burner outlet
02
u
dry)
12.81
12.75
12.68
12.64
12.68
12.88
12.74
0.09
C02
U
dry)
4.72
4.75
4.78
4.76
4.76
4.63
4.73
0.05
CO
(ppm
dry)
17
16
16
18
16
13
16
1.7
NOX
(ppm
dry)
62
60
58
58
59
64
60
2.4
NOX
(Ib/MBtu)
0.156
0.150
0.146
0.144
0.147
0.163
0.151
.007
NOX
(Ib/hr)
88.8
85.6
81.7
80.9
B1.8
88.7
83.9
5.1
Change
across
Db
NOX
(Ib/nr)
-0.9
-4.0
-3.6
-3.0
-2.2
5.6
-1.9
4.t>
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 6. DUCT BURNER TEST DATA: TEST CONDITION 5, DAY 19, TIME 1000 - 1630
Gas turbine
operating parameters
Time
period
1000 - 1100
1100 - 1200
1200 - 1300
1300 - 1AOO
1400 - 1500
1500 - 1600
1600 - 1630
Avg
S.D.
Load
(MW)
33.5
32.2
32.7
32.4
32.5
32.7
32.6
32.8
0.4
Fuel
flow
(scim)
7,279
7,267
7,229
7,204
7,198
7,203
7,267
7,235
35
Steam
Inj. ratio
(Ib/lb)
0.468
0.468
0.457
0.456
0.450
0.454
0.435
0.455
0.014
Fuel
flow
(scfm)
661
677
685
727
650
815
747
703
73
Duct burner
operating parameters
Heat
input
(10& Btu/hr)
41.1
42.1
42.6
45.2
40.4
50.7
46.5
43.8
4.6
Load
(percent)
25.2
25.8
26.1
27.7
24.8
31.1
28.5
26.8
2.8
Boiler
operating parameters
Total steam
flow
(Ib/hr)
213,600
206,900
210,800
219,000
212,100
208,600
225,900
212,300
40,878
Steam
press
(psig)
593
580
563
583
580
587
580
581
14.9
oo
Duct burner inlet
Time
period
1000 - 1100
1100 - 1200
1200 - 1300
1300 - 1400
1400 - 1500
1500 - 1600
1600 - 1630
Avg
S.D. '
Note: Means
H20
7.8
7.8
7.9
7.8
7.8
7.8
7.9
7.8
0.06
and
QS
(dscfm
x 103)
194.0
198.0
193.4
203.8
208.8
203.6
207.4
200.9
7.7
Standard
°A
dry)
14.94
14.96
14.97
14.96
14.96
14.96
14.95
14.96
0.01
C02
(X
dry)
3.40
3.42
3.40
3.35
3.35
3.38
3.33
3.38
0.04
CO
(ppm
dry)
2
1
1
2
2
1
1
1
0.5
NOX
(ppm
dry)
63
64
66
69
68
67
67
66
2.6
(ppm
iso)
59
60
63
65
63
63
64
63
2.4
(Ib/Mbtu)
0.215
0.220
0.229
0.238
0.234
0.232
0.232
0.228
0.009
NOX
(Ib/hr)
86.9
90.6
91.7
100.7
100.7
97.9
10U.O
95.2
5.9
H20
(X)
8.8
8.9
8.9
8.9
8.9
8.9
9.0
8.9
0.1
QS
(dscfm
x 103)
193.4
197.3
192.8
203.1
207.3
202.8
206.7
200.2
7.7
Duct burner outlet
°2
dry)
13.96
13.94
13.93
13.90
13.90
13.89
13.83
13.91
0.04
C02
(X
dry)
3.82
3.82
3.81
3.82
3.82
3.83
3.86
3.83
0.02
CO
(ppm
dry)
8
8
8
8
7
7
7
8
0.5
NOX
(ppm
dry)
68
64
65
66
65
64
65
65
1.8
NOX
(Ib/MBtu)
0.202
0.188
0.192
0.194
0.191
0.188
0.189
0.192
0.006
NOX
(Ib/hr)
94.7
89.9
90.2
97.7
96.8
93.5
96.4
94.0
4.4
Change
across
Db
NOX
(Ib/hr)
7.9
-0.6
-0.9
-2.4
-2.9
-4.3
-3.6
-0.6
4.5
15 minute averages.
-------
TABLE 7. DUCT BURNER TEST DATA: TEST CONDITION 6, DAY 23, TIME 0900 - 1500
Gas turbine
operating parameters
Til
Be
period
0900 -
1000 -
1100 -
1200 -
1300 -
1400 -
Avg
S.D.
1000
1100
1200
1300
1400
1500
Load
(MW)
32.8
32.4
31.2
30.8
30.9
30.8
31.5
0.8
Fuel
flow
(ecfm)
7,254
7,216
7,017
6,958
6,943
6,983
7,062
129
Steam
inj. ratio
(Ib/lb)
0
0
0
0
0
0
0
0
Fuel
flow
(scfm)
2,229
2,110
2,221
2,198
2,220
2,206
2 i-.-
Duct burner
operating parameters
Heat
input
(106 Btu/hr)
138.7
131.3
138.2
136.8
138.1
137.3
136.7
2.9
Load
(percent)
85.1
80.5
84.8
83.9
84.7
84.2
83.9
1.8
Boiler
operating parameters
Total steam
flow
(Ib/hr)
284,600
276,200
278,700
276,600
276,800
276,900
278,300
4,009
Steam
press
(psig)
588
593
595
595
600
593
594
9
_
Duct burner inlet
Time
period
0900 - 1000
1000 - 1100
1100 - 1200
1300 - 1400
1400 - 1500
1500 - 1600
Avg
S.D.
H20
W
6.7
6.6
6.5
6.2
6.5
6.4
6.5
0.2
QS
(dscf m
* 103)
202.1
208.4
209.8
205.5
202.3
201.2
204.9
4.0
02
(X
dry)
15.15
15.21
15.21
15.20
15.19
15.22
15.2
0.03
C02
(X
dry)
3.49
3.41
3.41
3.43
3.40
3.38
3.42
0.04
CO
(ppm
dry)
4
4
4
4
4
4
4
0
NOX
(ppm
dry)
103
107
110
111
111
112
109
4.6
NOX
(ppm
iso)
106
108
107
105
107
109
107
4.0
NOX
(Ib/MBtu)
0.368
0.365
0.395
0.399
0.398
0.403
0.409
0.014
NO,,
(Ib/hr)
149.5
160.7
164.4
163.2
160.8
160.8
159.7
7.4
H20
(X)
9.0
8.9
8.8
8.6
0.8
8.8
8.8
0.2
QS
(dscfm
x 103)
199.8
206.3
207.5
203.3
200.0
199.0
202.7
4.1
Duct burner outlet
02
(X
dry)
12.72
12.81
12.76
12.72
12.71
12.71
12.74
0.04
C02
(X
dry)
4.68
4.62
4.65
4.67
4.67
4.66
4.66
0.03
CO
(ppm
dry)
15
14
12
11
11
11
12
2.0
NOX
(ppm
dry)
104
105
107
109
109
111
108
2.8
NOX
(Ib/MBtu)
0.261
0.267
0.270
0.273
0.273
0.278
0.270
0.008
NOX
(Ib/hr)
148.9
155.4
159.3
158.4
156.4
158.5
156.2
5.0
Change
across
DB
NOX
(Ib/nr)
-0.6
-4.J
-4.1
-4.5
-4.4
-2.3
-3.3
3.0
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 8. DUCT BURNER TEST DATA: TEST CONDITION 7, DAY 20, TIME 1000 - 1700
Gas turbine
operating parameters
Time
period
1000 - 1100
1100 - 1200
1200 - 1300
1300 - 1400
1400 - 1500
1500 - 1600
1600 - 1700
Avg
S.D.
Load
(MVO
33.7
33.1
33.2
32.9
32.8
32.6
32.7
33
0.4
Fuel
flow
(sclm)
7,440
7,316
7,293
7,229
7,194
7,157
7,359
7,284
97
Steam
Inj . ratio
(Ib/lb)
0
0
0
0
0
0
0
0
0
Fuel
flow
(SCFM)
663
668
669
669
668
660
731
675
53
Duct burner
operating parameters
Heat
Input
(106 Btu/hr)
41.2
41.5
41.6
41.6
41.6
41.1
45.5
42.0
3.3
Load
(percent)
25.3
25.5
25.5
25.5
25.2
25.2
27.9
25.8
2.0
Boiler
operating parameters
Total steam
rlow
(Ib/hr)
201,000
201,900
199,500
201,400
202,100
199,000
204,100
201,300
6,169
Steam
press
(pslg)
590
595
593
595
593
590
583
591
13
Time
period
1000 - 1100
1100 - 1200
1200 - 1300
1300 - 1400
1400 - 1500
1500 - 1600
1600 - 1700
Avg
S.lJ.
Note: Means
H20
(*)
6.7
6.7
6.8
6.9
6.8
6.8
6.7
6.8
0.09
and Sti
OS
(dscfm
x 103)
205.4
203.6
204.2
201.6
210.6
224.2
216.5
209.4
10.3
andard
02
i (%
dry)
14.98
14.99
14.98
14.97
14.96
14.94
14.96
14.97
0.02
Deviations
Duct
C02
(%
dry)
3.37
3.36
3.34
3.35
3.32
3.31
3.36
3.34
0.04
are
burner Inlet
CO
(ppm
dry)
1
1
1
1
1
1
1
1
0
calculated
NOX
(ppm
dry)
109
110
111
112
113
113
109
111
2.6
using
NOX
(ppm
iso)
109
110
111
112
111
110
106
110
3.0
NOX
(Ib/HBtu)
0.378
0.385
0.385
0.388
0.389
0.389
0.375
0.384
0.008
NOX
(Ib/hr)
160.6
161.6
162.4
162.2
170.0
181.4
168.7
166.7
9.5
H20
(%)
7.6
7.7
7.7
7.8
7.8
7.7
7.6
7.7
0.1
QS
(dscfm
x 103)
204.8
202.9
203.6
200.9
209.9
223.6
215.8
208.8
10.3
Duct burner outlet
02
U
dry)
14.05
14.05
14.03
14.02
14.01
14.00
14.03
14.03
0.03
C02
(%
dry)
3.81
3.81
3.81
3.81
3.81
3.80
3.77
3.80
0.02
CO
(ppm
dry)
8
8
8
7
7
8
8
8
0
NO*
(ppm
dry)
106
105
105
105
105
104
105
105
3.9
NOX
(Ib/MBtu)
0.317
0.315
0.313
0.313
0.311
0.308
0.314
0.313
0.011
NOX
(Ib/hr)
155.0
152.7
152.8
150.9
157.2
165.9
162.5
156.7
9.6
Change
across
DB
NOX
(Ib/hr)
-5.6
-8.9
-9.7
-11.3
-12.8
-15.5
-6.2
-10.0
4.5
15 minute averages.
-------
TABLE 9. DUCT BURNER TEST DATA: TEST CONDITION 8, DAY 15, TIME 1830 - 2330
operating parameters
Time
period
1830 - 1930
1900 - 203U
2030 - -2130
2130 - 2230
2230 - 2330
Avg
S.D.
Load
(MW)
10.8
10.9
11.1
11.4
11.5
11.1
0.3
Fuel
flow
(scr'm)
3,356
3,367
3,405
3,432
3,464
3,402
42
Steam
inj. ratio
(Ib/lb)
0
0
0
0
0
0
0
Fuel
flow
(scfm)
2,305
2,270
2,283
2,294
2,143
2,265
63
operating parameters
Heat
input
(106 Btu/hr)
143.4
141.2
142.0
142.7
133.3
140.9
3.9
Load
(percent)
88.0
86.6
87.1
87.5
81.8
86.5
2.4
operating parameters
Total steam
flow
(Ib/hr)
186,300
188,300
192,300
192,900
187,300
189,900
3,304
Steam
press
(psig)
586
587
590
590
590
589
3
Duct burner inlet
Time
period
1830 - 1930
1930 - 2030
2030 - 2130
2130 - 2230
2230 - 2330
Avg
S.D.
H20
W
4.7
4.8
4.8
4.8
4.8
4.8
0.04
QS
(dscfm
x 103)
186.7
163.3
126.5
105.0
133.8
143.5
35.0
02
U
dry)
17.24
17.21
17.17
17.11
17.15
17.18
0.05
C02
(%
dry)
1.93
1.96
1.93
1.99
2.02
1.97
0.04
CO
(ppm
dry)
26
25
23
20
20
23
3
NOX
(ppm
dry)
28
28
28
30
29
29
1.1
NOj;
(ppm
iso)
45
45
46
47
47
46
1.1
NOX
(Ib/MBtu)
0.154
0.154
0.157
0.160
0.160
0.157
O.OU4
NO*
(Ib/hr)
36.9
32.4
25.7
22.3
28.3
29.1
6.7
H20
W
7.4
7.4
7.4
7.4
7.4
7.4
0.05
QS
(dscfm
x 103)
184.4
161.0
124.2
102.7
131.6
141.3
35.0
Duct burner outlet
°2
U
dry)
14.53
14.55
14.49
14.44
14.47
14.5
0.06
C02
(%
dry)
3.43
3.42
3.45
3.50
3.44
3.45
0.04
CO
(ppm
dry)
26
26
25
24
25
25
0.9
NOj,
(ppm
dry)
41
40
42
41
42
41
1.5
NOX
(Ib/MBtu)
0.133
0.129
0.134
0.130
0.136
0.132
0.004
NOX
(Ib/nr)
54.4
46.2
38.0
30.2
40.5
42.1
10.5
Change
across
DB
NOX
(Ib/nr)
17.5
13.8
11.6
7.9
12.2
12.7
3.9
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
outlet flow rate data and a volumetric calculation based on combustion
stoiciometry in the duct burner and fuel flow. Corrections to a dry basis for
outlet flow rates were made from calculated moisture values.
For the primary purpose of determining the contribution of NOX due to
the duct burner, no significant error is introduced by uncertainty in the true
duct burner outlet dry standard volumetric flow rate. This is because the
inlet dry standard volumetric flow rate was calculated from the outlet flow
rate and the stoichiometry of the fuel combusted in the duct burner.
Therefore, any error associated with the measurement of the outlet volumetric
flow rate for any time period was also in the calculated duct burner inlet
volumetric flow rate and was subtracted in the calculation of the duct burner
Ib NOX per hour data calculation. Velocity traverses were performed during
the duct burner test periods and for some of these periods significant
differences exist between the system Ib NOX per hour values obtained using
velocity traverse data and continuous transducer data.
Any error on the calculated dry duct burner inlet volumetric flow rate
introduced by measurement of the duct burner fuel consumption was minimal
since the entire effect of the duct burner fuel consumption was 3 percent or
less of the total flow rate.
Emission measurements were made in central points in the inlet and outlet
ducts. Based on initial stratification test data, this deviation in Method 20
procedures for 62 and NOX measurements was supported by the uniform
concentrations observed at both sampling locations.
Reported CO concentrations were corrected from measured CO concentrations
for C02 interference with an interference curve generated after the test
program. This correction was necessary because no ascarite was used prior to
the CO instrument to remove C02 from the sample gas stream. Corrections to
measured CO concentrations due to C02 interference averaged approximately
10 ppm CO on a dry basis.
NOX concentration was measured on a wet basis and was converted to a
dry basis with the moisture values calculated from stoichiometric combustion
moisture, measured steam injection flow rates, and local ambient humidity.
NOX emission rates (Ibs/hr) were calculated with corrected NOX
concentrations using outlet flow rates measured with a pressure transducer
positioned in the outlet stack and inlet flow rates determined from fuel flow
and outlet flow rate data. These calculation procedures were chosen to
minimize the impact of measurement errors on calculated duct burner emission
rates (Ibs/hr) and to maintain consistency throughout the test program.
In addition, NOX emissions are reported on a Ib/MBtu basis utilizing
the F factor method. Values reported are calculated with the dry oxygen based
F factor.
A summary of data reduction techniques and a detailed documentation of
data reduction programs is included in Appendix A. Also included in
Appendix A is a summary table of emission data from the entire GEM test period
calculated by F^ and FC factors, transducer readings, and velocity
traverses.
12
-------
Tables 1U through 19 present hourly averages of process and emission data
for tesC periods defined over continuous monitoring of the duct burner. The
tables summarize gas turbine and duct burner fuel flow, steam injection and
emission rates. Calculation procedures for continuous monitoring data were
the same as those used for test condition data.
13
-------
TABLE 10. DUCT BURNER TEST DATA: GEM TEST PERIODS
Gas turbine
operating parameters
Test
condition
1
2
3
9
10
11
12
13
14
Load
CMW)
13.8
34.6
35.0
12.8
12.6-
28.5
12.9
12.8
14.4
Fuel
flow
(sctm)
3,752
7,288
7,534
3,803
3,591
6,370
3,686
3,750
3,756
Steam
in j . ratio
(Ib/lb)
0.74
0.9b
0.97
0.93
0.77
0.72
0.76
0.71
0.71
Duct burner
operating parameters
Fuel
flow
(scfm)
2,312
1,372
1,030
1,811
897
879
2,149
1,891
1,136
Heat
input
(106 Btu/hr)
143.8
85.4
64.1
112.7
55.8
54.7
133.7
117.6
70.7
Load
(percent)
88
52
39
69
34
34
82
72
43
Ambient conditions
Temp
(°F)
55
54
51
50
50
52
52
54
51
Pressure
(in hg)
30.1
30.3
30.2
30.2
30.2
30.2
30.3
30.2
30.3
Relative
humidity
«)
92.0
77.6
83.3
85.0
66.0
58.5
83.7
77.1
93.9
Duct burner inlet
Test
condition
1
2
3
9
10
11
12
13
14
H20
W
6.3
9.5
9.6
6.8
5.6
7.2
6.3
6.6
6.4
QS
(dscfm
x 103)
107.1
201.3
212.2
191.0
174.9
208.9
174.1
172.4
170.9
02
U
dry)
16.9
14.8
14.7
16.8
17.3
15.9
17.0
16.8
16.9
C02
U
dry)
2.16
3.56
3.58
2.19
2.17
2.95
2.17
2.20
2.38
CO
(ppm
dry)
52
4
4
14
86
7
74
71
41
NOX
(ppm
dry)
20
40
39
35
15
35
19
20
19
NOX
(ppm
iso)
30
39
37
52
24
40
29
28
28
NOX
(Ib/MBtu)
0.104
0.136
0.128
0.178
0.085
0.143
0.100
0.097
0.095
NOX
(Ib/hr)
15.4
57.9
58.8
48.3
18.9
57.8
23.1
24.2
22.6
H20
(%)
9.3
11.1
10.8
9.0
7.3
8.6
8.8
8.7
8.3
QS
(dscfm
a 103)
104.8
200.0
211.1
189.2
174.0
208.0
172.0
170.5
169.7
Duct burner outlet
02
(X
dry)
13.8
13.2
13.5
14.6
15.7
14.7
14.4
14.5
15.1
C02
U
dry)
3.79
4.23
4.11
3.37
2.58
3.34
3.5
3.41
2.97
CO
(ppm
dry)
34
14
18
24
81
16
46
48
43
NOX
(ppm
dry)
25
44
39
45
10
30
20
17
13
NOX
(Ib/MBtu)
0.072
0.116
0.107
0.147
0.041
0.098
0.062
0.056
0.046
NOX
(Ib/hr)
18.4
60.1
58.8
61.3
13.1
44.6
22.0
21.2
15.8
Change
across
Db
NOX
(Ib/nr)
3.0
2.2
0.0
13.0
-5.8
-7.2
-1.1
-3.0
-b.y
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 11. DUCT BURNER TEST DATA: CEM TEST PERIODS, TEST CONDITION 1
Gas turbine
operating parameters
Day/hour
16 23
17 2
17 3
17 4
Avg
S.D.
Load
(MV)
12.3
14.4
14.3
14.2
13.8
1.0
Fuel
flow
(sctm)
3,506
3,821
3,808
3,875
3,752
167
Steam
Inj. ratio
(Ib/lb)
0.80
0.70
0.71
0.73
0.74
0.05
Duct burner
operating parameters
Fuel
flow
(scfm)
2,333
2,286
2,315
2,314
2,312
19
Heat
Input
(106 Btu/hr)
145.2
142.2
144.0
144.0
143.8
i.2
Load
(percent)
89
87
88
88
88
1
Ambient conditions
Temp
54
57
55
53
55
2
Pressure
(in hg)
30.1
30.1
30.1
30.1
30.1
0
Relative
humidity
(Z)
92.0
92.0
92.0
92.0
92.0
0
Ln
Duct burner Inlet
Day/hour
16 23
17 2
17 3
17 4
Avg
S.D.
H20
6.2
6.4
6.4
6.4
6.3
0.1
QS
(dscfm
x 103)
137.3
111.6
69.7
110.6
107.1
27.9
02
(X
dry)
17.1
16.8
16.8
16.9
16.9
0.1
C02
(X
dry)
2.02
2.21
2.21
2.20
2.16
0.09
CO
(ppm
dry)
81
40
42
45
52
19
NOX
(ppm
dry)
17
22
21
21
20
2
NOX
(ppm
Iso)
27
31
31
30
30
1.8
(Ib/MBtu)
0.094
0.108
0.108
0.105
0.104
0.007
(Ib/hr)
17.1
17.3
10.7
16.3
15.4
3.1
H20
9.2
9.4
9.4
9.4
9.3
0.1
QS
(dscfm
x 103)
134.9
109.3
67.3
107.7
104.8
27.9
Duct burner outlet
°2
(X
dry)
14.0
13.8
13.8
13.8
13.8
0.1
C02
U
dry)
3.66
3.83
3.84
3.83
3.79
0.08
CO
(ppm
dry)
49
28
29
30
34
10
NOX
(ppm
dry)
22
27
25
25
25
2
NOX
(Ib/MBtu)
0.065
0.077
0.071
0.074
0.072
0.005
NOX
Ub/nr)
21.2
21.0
11.8
19.0
18.4
4.4
Change
across
DB
(iwilr)
4.1
3.7
1.1
3.3
3.0
1.3
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 12. DUCT BURNER TEST DATA: CEM TEST PERIODS, TEST CONDITION 2
Gas
operati
turbine
ng parameters
Fuel
Steam
Day/hour (««) (sclm) (Ib/lb)
16 21
18 17
18 18
18 19
18 20
18 21
19 7
19 20
19 21
20 7
21 13
21 14
21 15
21 16
21 17
21 18
21 19
21 21
21 22
23 22
Hvg.
S.D.
34.7 7,326
35.3 7,514
35.3 7,532
35.1 7,561
35.1 7,490
34.9 7,337
35.4 7,711
34.6 8,054
34.8 6,767
36.4 7,669
33.9 7,226
33.6 7,254
33.4 7,166
33.4 7,160
33.8 7,283
34.1 7,270
34.1 7,304
34.4 7,343
34.5 6,466
34.7 0,331
34.6 7,288
0.8 400
0.93
1.00
1.00
0.98
0.97
0.98
0.99
0.95
0.99
1.00
0.94
0.93
0.94
0.94
0.96
0.99
0.94
0.95
0.97
0.94
0.96
0.02
Duct burner
operating parameters
Fuel
(scfm)
1,476
1,464
1,397
1,505
1,503
1,521
1,340
1,324
1,265
1,106
1,305
1,340
1,324
1,316
1,333
1,322
1,278
1,367
1,528
1,427
1,372
106
Heat
(106 Btu/nr)
91.8
91.1
86.9
93.7
93.5
94.6
83.3
82.4
78.7
68.9
81.2
83.4
82.4
82.0
82.9
82.2
79.5
85.0
95.1
88.8
85.4
6.6
Ambient conditions
(percent) CF) (in h8)
56
56
53
57
57
58
51
51
48
42
50
51
51
50
51
50
49
52
58
54
52
4
Day/nour
16 21
18 17
IS 18
18 20
16 21
19 7
19 20
19 21
20 7
21 3
21 14
21 15
21 16
21 17
21 16
21 19
21 21
21 22
23 22
Avg
S.b.
H20
(*>
9.5
9.6
9.6
9.6
9.6
10.0
9.5
9.5
9.4
9.3
9.3
9.4
9.5
9.6
9.7
9.6
9.6
9.6
9.4
9.5
0.2
U.S
(dscta
x 103)
193.0
200.5
a
a
a
a
202.0
201.0
205.0
204.1
202.9
202.6
198.3
198.4
202.3
202.4
203.1
204.7
200.0
201.3
3.0
02
(I
dry)
14.8
14.8
14.7
14.7
14.7
14.5
14.8
14.8
14.8
14.9
14.9
14.8
14.8
14.8
14.8
14.8
14.8
14.8
14.9
14.8
0.1
C02 CO
U (ppm
dry) dry)
3.38 0
3.36 3
3.49 3
3.50 2
3.50 3
3.51 11
3.53 2
3.55 2
3.60 2
3.58 6
3.62 6
3.63 6
3.63 6
3.63 6
3.62 6
3.63 6
3.62 5
3.66 5
3.68 4
3.56 4
0.09 2
NO,
(ppm
dry)
40
41
42
42
42
39
31
39
38
41
41
41
41
40
39
40
39
39
43
40
1
NO,
(ppn
ISO)
38
39
40
40
40
36
38
38
38
39
39
39
31
39
39
38
38
38
42
39
1.2
NO,
(Ib/MBtu)
0.134
0.137
0.138
0.139
0.138
0.124
0.133
0.134
0.130
0.140
0.140
0.140
0.139
0.135
0.131
0.133
0.132
0.131
0.146
0.136
0.005
NO,
(Ib/nr)
55.5
56.7
a
a
a
a
56.7
56.9
56.3
60.1
60.0
60.0
58.3
57.1
56.7
57.3
56.8
57.0
61.1
57.9
1.7
H20
(S)
11.3
11.3
11.2
11.3
11.3
11.5
11.0
11.0
10.8
10.9
11.0
11.1
11.2
11.3
11.4
11.2
11.1
10.9
10.6
11.1
0.2
o>
(dscfm
x 10J)
191.3
199.0
a
a
a
a
200.7
199.7
203.8
202.8
201.5
201.3
197.0
197.1
200.9
201.1
201.8
203.2
198.5
200.0
3.1
55 30.1
51 30.3
51 30.3
52 30.3
51 30.3
52 30.3
50 30.3
55 30.3
54 30.3
43 30.3
58 30.3
59 30.3
60 30.2
61 30.2
57 30.2
53 30.2
57 30.3
55 30.2
55 30.2
53 30.3
54 3U.3
4 0.1
Relative
U)
92.0
01.5
69.0
78.0
79.8
85.0
82.5
92.0
92.0
89.0
51.3
50.0
56.8
69.5
77.0
86.0
80.0
93.0
93.0
73.0
77.8
14.1
Oj
U
dry)
13.0
13.1
13.1
13.0
13.0
13.0
13.3
13.3
13.5
13.3
13.2
13.1
13.2
13.2
13.1
13.2
13.2
13.3
13.5
13.2
0.2
CO 2
U
dry)
4.34
4.24
4.20
4.28
4.29
4.18
4.22
4.23
4.17
4.22
4.23
4.21
4.15
4.18
4.20
4.22
4.30
4.27
4.20
4.23
0.05
CO
(ppm
dry)
18
17
16
16
16
27
10
10
11
10
11
12
12
12
13
12
9
9
14
14
4
NO,
(ppm
dry)
44
56
52
49
49
46
47
47
44
39
39
41
41
39
38
37
40
37
39
44
6
NO,
(Ib/MBtu)
0.114
0.146
0.138
0.128
0.129
0.116
0.126
0.126
0.122
0.106
0.104
0.108
0.108
0.104
0.101
0.099
0.106
0.099
0.106
0.116
0.015
NO,
(ib/nr)
60.5
62.6
a
a
a
a
06.4
67.3
64. J
57.2
50.4
58.9
57.6
55.6
55.2
53.6
57.2
53.4
54.8
60.1
7.6
Change
across
DB
NO,
Ub/nr)
5.0
24.1
10.2
10.5
8.1
-3.0
-3.0
-1.1
-O.o
-1.5
-1.5
-3.0
0.4
-3.5
-6.3
2.2
8.0
Represents missing data.
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 13. DUCT BURNER TEST DATA: GEM TEST PERIODS, TEST CONDITION 3
Gas turbine
operating parameters
Day/nour
16 7
16 8
17 7
16 7
' 20 21
21 7
21 8
Avg
S.D.
Load
(MW)
34.8
34.9
34.8
36.5
34.9
34.7
34.7
35.0
0.6
Fuel
flow
(scfm)
7,530
7,484
7,600
7,824
7,408
7,448
7,443
7,534
143
Steam
inj. ratio
(lb/lb;
0.94
0.95
0.96
0.99
0.99
0.96
0.96
0.97
0.02
Duct burner
operating parameters
Fuel
tlow
(scfm)
959
996
1,090
988
982
1,029
1,167
1,030
74
Heat
input
CIO6 Btu/hr)
59.7
62.0
67.8
61.4
61.1
64.0
72.6
64.1
4.6
Load
(percent)
37
38
42
38
37
39
45
39
3
Ambient conditions
Temp
rn
52
52
53
43
51
53
52
51
4
Pressure
(in hg)
30.2
30.2
30.1
30.2
30.3
30.3
30.3
30.2
0.1
Relative
humidity
(*)
90.3
83.3
86.0
100.0
73.0
58.3
59.3
78.6
15.7
Duct burner inlet
Day/hour
16 7
16 8
17 7
18 7
20 21
21 7
21 8
Avg
S.U.
H20
(X)
9.8
9.8
9.5
9.3
9.8
9.7
9.6
9.6
0.2
QS
(dscfm
x 103)
245.6
228.7
187.7
209.3
203.0
204.7
206.1
212.2
19.0
02
(X
dry)
14.6
14.6
14.8
14.9
14.7
14.5
14.6
14.7
0.1
C02
(X
ary)
3.60
3.59
3.44
3.61
3.58
3.60
3.62
3.58
0.06
CO
(ppm
dry)
2
2
1
5
1
10
10
4
4
NOX
(ppm
dry)
40
39
40
33
39
40
39
39
3
NO*
(ppm
iso)
38
37
38
33
38
37
36
37
1.8
NOX
(Ib/MBtu)
0.131
0.127
0.133
0.113
0.130
0.130
0.129
0.128
0.007
NOX
(Ib/hr)
70.9
64.2
53.3
49.3
57.1
59.1
57.9
58.8
7.1
H20
(X)
10.9
10.8
11.1
10.5
10.9
10.8
10.8
10.8
0.2
QS
(dscfm
x 103)
244.6
227.7
186.6
208.3
202.0
203.7
204.9
211.1
19.1
Duct burner outlet
02
(%
dry)
13.5
13.5
13.3
13.7
13.5
13.4
13.4
13.5
0.1
C02
(X
dry)
4.11
4.10
4.17
4.02
4.11
4.11
4.17
4.11
0.05
CO
(ppm
dry)
22
22
15
17
11
21
21
18
4
NOX
(ppm
dry)
45
42
42
32
36
37
37
39
4
NOX
(Ib/MBtu)
0.125
0.118
0.112
0.092
0.101
0.102
0.101
0.107
0.012
NOX
(Ib/nr)
78.8
69.3
55.6
47.6
52.3
54.2
54.1
58.8
10.9
Cnaage
across
D5
NOX
Ub/.-ir)
7.9
3.J.
J.3
-1.7
-4.8
-4.9
-3.8
U.O
5.2
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 14. DUCT BURNER TEST DATA: CEM TEST PERIODS, TEST CONDITION 9
Gas turbine
operating parameters
Day/hour
16 0
16 1
16 2
16 3
16 4
16- 5
Avg
S.b.
Load
(MW)
12.8
12.8
12.8
12.8
12.8
12.9
12.8
0.1
Fuel
flow
(scfm)
3,675
3,607
3,667
3,564
3,545
4,75y
3,803
471
Steam
inj. ratio
Ub/lb)
0.93
0.93
0.93
0.94
0.94
0.93
0.93
0.0
Duct burner
operating parameters
Fuel
flow
(scfm)
1,915
1,813
1,783
1.8U6
1,809
1,738
1,811
58
Heat
input
(106 Btu/hr)
119.2
112.8
110.9
112.4
112.5
108.1
112.7
3.6
Load
(percent)
73
69
68
69
69
66
69
2
Ambient conditions
Temp
(°F)
50
50
50
49
50
49
50
1
Pressure
(in hg)
30.2
30.2
30.2
30.2
30.2
30.2
30.2
0
Relative
humidity
(*)
85.0
85.0
85.0
85.0
85.0
85.0
85.0
0
co
Duct burner inlet
Day/hour
16 0
16 1
16 2
16 3
16 4
16 5
Avg
S.D.
H20
U)
6.8
6.8
6.8
6.7
6.7
6.7
6.8
0.0
QS
(dsctm
x 103)
170.4
201.8
170.5
186.6
205.8
210.9
191.0
17.9
02
U
dry)
16.8
16.8
16.8
16.9
16.9
16.9
16.8
0.0
C02
(%
dry)
2.17
2.19
2.21
2.19
2.20
2.21
2.19
0.01
CO
(ppm
dry)
14
14
13
14
14
14
14
0
NOX
(ppm
dry)
35
35
36
35
35
35
35
0
NOX
(ppm
iso)
52
51
52
52
52
52
52
0.4
NOX
(Ib/Mhtu)
0.177
0.177
0.179
0.178
0.180
0.179
0.178
0.001
NOX
(Ib/hr)
42.9
50.8
43.8
46.7
52.1
53.2
48.3
4.4
H20
(X)
9.0
9.0
8.9
9.0
9.0
9.2
9.0
0.1
QS
(dscfm
x 103)
168.5
200.0
168.7
184.8
204.0
209.2
189.2
17.9
Duct burner outlet
02
(%
dry)
14.5
14.6
14.6
14.6
14.5
14.6
14.6
0.0
C02
U
dry)
3.42
3.38
3.34
3.37
3.39
3.37
3.37
0.03
CO
(ppm
dry)
24
24
24
24
24
24
24
0
NOX
(ppm
dry)
46
45
46
45
44
45
45
1
NOX
(Ib/MBtu)
0.148
0.147
0.150
0.146
0.144
0.145
0.147
0.002
NOX
(Ib/hr)
55.6
64.7
55.4
59.7
65.0
67.3
61.3
5.1
Change
across
DB
NOX
(Ib/hr)
12.6
13.9
11.6
13.0
12.9
14.1
13.0
0.9
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 15. DUCT BURNER TEST DATA: CEM TEST PERIODS, TEST CONDITION 10
Gas turbine
operating parameters
Duct burner
operating parameters
Ambient conditions
Fuel Steam Fuel Heat Relative
Load flow inj. ratio flow input Load Temp Pressure ' humidity
Day/hour (MW) (scrm) (Ib/lb) (scfm) (106 Btu/hr) (percent) (°F) (in hg) (X)
17 23
12.6 3,591
0.77
897
55.8
50
30.2
66.0
Avg
S.D
NA
NA
NA
NA
NA
NA
NA
NA
NA
VC
Day/hour
QS 02
H20 (dscfm (%
Duct burner inlet
Duct burner outlet
CO 2
(X
CO NOj; NO,
(ppm (ppm (ppm
NOv
NO,
H20
QS 02 C02
(dscfm (X (X
CO
(ppm (ppm
NO*
Change
across
DB
SOV
NOV
(X) x 103) dry) dry) dry) dry) iso) (Ib/MBtu) (Ib/hr) (X) x 103) dry) dry) dry) dry) (Ib/Mbtu) (Ib/hr) Ub/nr)
17 23
5.6 174.9 17.3 2.17 86
15
0.085 18.9
7.3 174.0 15.7 2.58 el
10
0.041
13.1
-5.b
Avg
S.U.
NA
NA NA
NA NA
NA
NA
NA
NA
NA NA
NA
NA
NA - Not applicable.
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 16. DUCT BURNER TEST DATA: GEM TEST PERIODS, TEST CONDITION 11
Gas turbine
operating parameters
Duct burner
operating parameters
Ambient conditions
Day/hour
17 19
17 21
Avg
S.D.
Load
(MW)
28.5
28.6
28.5
0.1
Fuel
flow
(scfm)
6,442
6,29b
6,370
102
Steam
Inj. ratio
(Ib/lb)
0.77
0.66
0.72
0.08
Fuel
flow
(scfm)
977
782
879
138
Heat
Input
(106 Btu/hr)
60.8
48.7
54.7
8.6
Load
(percent)
37
30
34
5
Temp
CF)
53
51
52
1
Pressure
(in hg)
30.2
30.2
30.2
0
Relative
humidity
(X)
51.0
66.0
58.5
10.6
to
c
Duct burner Inlet
Day/hour
17 19
17 21
Avg
S.D.
H20
(X)
7.3
7.1
7.2
0.2
QS
(dscfm
x 103)
20y.3
20B. 4
208.9
0.6
°2
(X
dry)
15.9
15.9
15.9
0.0
C02
(X
dry)
2.96
2.94
2.95
0.01
CO
(ppm
dry)
6
7
7
1
NOX
(ppm
dry)
34
36
35
1
NOX
(ppm
iso)
38
41
40
2.3
NOX
(Ib/MBtu)
0.138
0.148
0.143
0.007
NOX
(Ib/hr)
50.4
53.2
51.8
2.0
H20
(X)
8.8
8.4
8.6
0.3
QS
(dscfm
x 103)
208.3
207.6
208.0
0.5
Duct burner outlet
02
(X
dry)
14.5
14.8
14.7
0.2
C02
(X
dry)
3.40
3.27
3.34
0.09
CO
(ppm
dry)
15
16
16
1
NOX
(ppm
dry)
35
25
30
7
NOX
(Ib/MBtu)
0.113
0.083
0.098
0.021
NOX
Ub/hr)
52.2
37.0
44.6
10.7
Change
across
DB
-NOX
Ub/hr)
1.8
-16.2
-7.2
12.70
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 17. DUCT BURNER TEST DATA: CEM TEST PERIODS, TEST CONDITION 12
Gas turbine
operating parameters
Day/hour
0.8 4
19 0
19 1
. 19 2
19 3
19 4
19 5
19 23
20 0
20 1
20 3
20 4
20 5
22 0
22 1
22 2
22 11
22 12
22 17
22 18
22 19
22 20
22 21
22 22
22 23
23 0
24 0
24 1
24 2
24 3
24 4
Avg
S.D.
Load
(MW)
11.6
13.0
13.7
14.5
13.7
13.7
14.0
12.4
12.6
12.7
11.7
12.4
12.5
12.2
12.2
12.7
13.0
13.1
12.3
12.3
12.4
12.5
12.5
12.5
12.7
12.5
12.6
12.7
13.6
14.1
14.0
12.9
0.7
Fuel
flow
(scfm)
3,784
3,663
3,782
3,736
3,796
3,960
4,532
3,395
3,610
3,558
3,696
3,400
4,475
3,509
3,536
3,591
3,613
3,610
3,552
3,515
3,502
3,580
3,537
3,540
3,576
3,565
3,539
3,670
3,886
3.81B
3,742
3,686
255
Steam
Inj. ratio
(Ib/lb)
0.78
U.76
0.72
0.7U
0.72
0.73
0.72
0.79
0.77
0.7B
0.7B
0.76
0.77
0.79
0.79
0.77
0.77
0.76
0.78
0.79
0.79
0.77
0.76
(J.7b
0.7b
0.75
0.76
0.78
0.74
0.72
0.73
0.76
0.03
Duct burner
operating parameters
Fuel
flow
(scfm)
2,132
2,371
2,322
2,363
2,416
2,341
2,182
2,063
2,086
2,040
2,081
2,085
1,821
2,110
2,113
2,117
2,070
2,071
2,096
2,103
2,096
2,144
2,111
2,0i5
2,068
2,105
2,142
2,207
2,256
2,233
2,211
2,149
121
Heat
input
(106 Btu/hr)
132.7
147.5
144.5
147.0
150.3
145.7
135.7
128.4
129.8
126.9
129.5
129.7
113.3
131.3
131.5
131.7
128.8
128.8
130.4
130.9
130.4
133.4
131.4
127.9
128.7
130.9
133.3
137.3
140.3
13B.9
137.6
133.7
7.6
Load
(percent)
81
90
89
90
92
89
83
79
80
78
79
80
70
81
81
81
79
79
80
80
80
82
81
78
79
80
82
84
86
85
84
82
5
Ambient conditions
Temp
(°F)
40
52
51
50
52
50
51
49
49
49
47
47
47
55
54
54
51
54
59
60
59
58
57
56
57
56
50
50
49
50
48
52
4
Pressure
(in hg)
30.2
30.3
30.3
30.3
30.3
30.3
30.3
30.3
30.3
30.3
30.3
30.3
30.3
30.2
30.2
30.2
30.2
30.2
30.3
30.3
30.3
30.2
30.2
30.2
30.2
30.2
30.3
30.3
30.3
30.3
30.3
30.3
0.1
Relative
humidity
(*)
66.0
85.0
85.0
85.0
85.0
85.0
85.0
92.0
92.0
92.0
92.0
92.0
92.0
93.0
93.0
93.0
65.8
50.3
76.5
82.5
86.8
87.4
93.0
93.0
93.0
93.0
73.0
73.0
73.0
73.0
73.0
83.7
10.7
(continued)
-------
TABLE 17 (continued)
to
Duct burner Inlet
Day/hour
18 4
19 0
19 1
19 2
19 3
19 4
19 5
19 23
20 0
20 1
20 3
20 4
20 5
22 0
22 1
22 2
22 11
22 12
22 17
22 16
22 19
22 20
22 21
22 22
22 23
23 0
24 0
24 1
24 2
24 3
24 4
Avg
S.D.
H20
U)
5.4
6.2
6.3
6.2
6.3
6.3
6.4
6.0
6.0
6.0
6.0
5.9
5.9
6.2
6.3
6.3
7.0
7.0
7.1
7.1
7.1
7.1
7.1
7.1
7.1
7.1
5.5
5.6
5.8
5.7
5.7
b.3
0.6
QS
(dscfm
x 103)
168.0
a
a
a
a
a
a
167.4
163.5
162.5
16B. 1
169.2
168.4
169.4
170.8
171.6
168.6
168.4
173.7
169.8
170.1
170.1
170.4
170.3
171.1
172.2
193.2
192.4
194.1
195.4
195.1
171.1
10.4
°2
(X
dry)
17.5
17.0
16.9
16.9
16.9
.16.8
16.8
17.2
17.2
17.2
17.2
17.2
17.2
17.1
17.1
17.1
16.5
16.4
16.5
16.5
16.5
16.5
16.6
16.5
16.5
16.6
17.6
17.6
17.3
17.4
17.4
17.0
0.4
C02
U
dry)
2.08
2.16
2.24
2.24
2.23
2.24
2.24
2.14
2.16
2.16
2.17
2.15
2.15
2.22
2.23
2.24
2.21
2.22
2.19
2.17
2.18
2.19
2.17
2.20
2.21
2.20
1.98
1.98
2.14
2.10
2.09
2.17
0.07
CO
(ppm
dry)
58
73
57
57
58
60
60
83
83
88
20
88
92
61
58
62
89
86
92
b
b
95
b
95
89
94
66
68
46
49
53
74
20
NOX
(ppm
dry)
23
19
21
21
21
21
20
17
18
17
35
IS
16
17
17
16
16
17
17
17
16
17
16
16
17
16
19
19
23
21
21
19
4
NO*
(ppm
Iso)
39
29
31
31
31
30
30
2B
28
28
57
29
27
26
27
25
22
22
23
23
22
23
22
22
23
23
34
34
38
36
36
29
7.3
NOX
(Ib/MBtu)
0.137
0.102
0.108
0.107
0.108
0.104
0.103
0.098
0.097
0.095
0.195
0.098
0.092
0.090
0.094
0.087
0.076
0.077
0.080
0.078
(T.077
0.076
0.077
0.076
0.078
0.077
0.115
0.118
0.130
0.125
0.123
0.100
0.026
NOX
(Ib/hr)
27.5
a
a
a
a
a
a
21.0
20.6
20.0
42.1
21.3
19.7
20.1
21.3
19.9
19.7
21.3
20.3
20.3
20.1
20.2
19.8
19.7
20.3
20.1
25.6
26.2
31.6
29.8
29.3
23.1
5.4
H20
(%)
8.3
9.1
9.1
9.1
9.2
9.3
9.6
8.7
8.8
8.7
8.8
8.7
8.9
9.0
9.0
8.8
8.8
9.0
9.0
9.0
9.0
8.9
8.9
8.9
8.9
8.9
8.2
8.2
8.5
8.4
8.4
8.8
0.3
QS
(dscfm
x 103)
165.9
a
a
a
a
a
a
165.4
161.4
160.4
166.0
167.1
166.6
167.3
168.7
169.5
166.5
166.4
171.6
167.7
168.0
167.9
168.3
168.3
169.0
170.1
191.0
190.2
191.8
193.1
192.8
172.0
10.4
Duct burner outlet
02
(%
dry)
14.7
14.0
14.0
13.9
13.9
13.8
13.7
14.5
14.4
14.5
14.5
14.5
14.5
14.4
14.4
14.4
14.4
14.3
14.3
14.3
14.4
14.4
14.4
14.4
14.4
14.4
15.0
15.0
14.7
14.7
14.8
14.4
0.3
C02
U
dry)
3.41
3.67
3.67
3.73
3.73
3.72
3.70
3.47
3.49
3.47
3.48
3.46
3.45
3.51
3.53
3.52
3.53
3.54
3.52
3.52
3.53
3.52
3.51
3.52
3.54
3.55
3.12
3.12
3.34
3.29
3.26
3.50
0.15
CO
(ppm
dry)
38
41
35
34
34
38
44
50
50
54
13
53
57
46
44
47
51
50
53
57
57
55
57
55
51
53
47
48
32
34
37
46
10
NOX
(ppm
dry)
26
27
29
29
27
28
29
21
20
19
50
20
18
15
16
14
13
14
14
13
13
13
13
13
14
13
16
16
22
20
19
20
8
NOX
(Ib/MBtu)
0.086
0.080
0.086
0.086
0.079
0.081
0.081
0.068
0.065
0.061
0.161
0.064
0.057
0.047
0.050
0.044
0.042
0.043
0.044
0.042
0.042
0.042
0.041
0.041
0.043
0.042
0.055
0.054
0.071
O.U67
0.064
0.062
0.024
NOX
(Ib/hr)
30.9
a
a
a
a
a
a
25.2
23.6
21.9
59.9
24.0
21.2
17.8
19.2
17.1
15.8
16.5
17.4
16.1
16.0
16.1
15.7
15.7
16.4
16.2
21.8
21.1
29.5
27.9
26.5
22.0
9.2
Change
across
DB
NOjj
(Ib/hr)
3.4
a
a
a
a
a
a
4.2
3.0
1.8
17.8
2.7
1.4
-2.4
-2.1
-2.8
-3.9
-3.6
-4.0
-4.1
-4.0
-4.1
-4.0
-4.0
-3.9
-3.9
-3.8
-5.1
-2.1
-1.9
-2.8
-1.1
4.9
Represents missing data.
bfO concentration 100 ppm.
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 18. DUCT BURNER TEST DATA: GEM TEST PERIODS, TEST CONDITION 13
NJ
Us
Gas turbine
operating parameters
Fuel Steam Fuel
Day/hour (MW) (scfm) Ub/lb) (scfm)
20 2
21 0
21 1
21 2
21 3
21 4
21 5
22 3
22 10
22 13
22 14
22 15
22 16
23 2
23 2
23 5
24 5
Avg
S.b.
Day/hour
20 2
21 0
21 1
21 2
21 3
21 4
21 5
22 3
22 10
22 13
22 14
22 13
22 16
23 2
23 3
23 5
24 5
Avg
S.U.
H20
(X)
5.9
6.3
6.3
6.3
6.6
6.6
6.5
6.2
7.0
7.1-
7.1
7.1
7.2
6.7
5.8
7.0
5.6
6.6
0.5
«b
(dsclm
x 103)
167.6
166.6
176.5
174.3
170.3
172.1
173.1
170.4
167.7
169.0
167.8
171.4
174.0
170.7
172.9
171.7
194.3
172.4
6.3
02
(X
dry)
17.3
17.0
17.0
17.0
16.8
16.8
16.8
17.1
16.5
16.4
16.4
16.4
16.4
16.6
16.6
16.5
17.5
16.8
0.3
11.9 3,536
12.7 3,523
12.7 3,646
12.8 3,551
12.6 3,572
12.6 3,580
12.7 4,405
12.6 3,462
13.0 3,553
13.0 3,572
13.0 3,623
12.9 3,618
12.7 3,536
13.5 3,556
12.2 3,591
12.6 4,394
13.6 5,034
12..
0.
C02
(X
dry)
2.11
2.19
2.20
2.20
2.19
2.19
2.20
2.24
2.20
2.24
2.24
2.25
2.23
2.20
2.20
2.19
2.06
2.20
0.05
8 3,750
4 433
CO
(ppm
dry)
89
78
77
76
84
86
84
63
90
78
75
71
79
18
19
88
60
71
22
NO,
(ppn
dry)
19
16
17
17
17
17
17
16
16
18
18
18
18
35
35
17
20
20
6
0.79
0.77
0.77
0.75
0.76
0.77
0.77
0.77
0.76
0.77
0.77
0.76
0.77
0.54
0.07
0.73
0.74
0.71
0.17
NO,,
(ppm
iso)
31
27
26
26
25
23
25
25
23
23
23
24
24
49
49
2i
35
28
8.3
2,010
1,804
1,804
1,804
1,834
1,850
1,606
1,985
1,934
2,015
2,013
1,998
2,024
1,894
1,905
1,739
1,918
1,891
117
NOX
(Ib/MBtu)
0.108
0.092
0.091
0.091
0.085
0.085
0.086
0.086
0.077
0.080
0.082
0.083
0.083
0.164
0.163
0.079
0.119
0.097
0.027
Duct
operating
burner
parameters
Heat
(106 Btu/tir)
125.1
112.3
112.3
112.3
114.1
115.1
99.9
123.5
120.3
125.4
125.3
124.3
125.9
117.8
118.5
108.2
119.4
117.6
7.2
NOX
Ub/hr)
22.8
21.0
22.1
21.7
20.8
21.0
21.2
19.5
19.7
21.3
21.5
22.4
22.4
42.5
42.8
20.6
27.9
24.2
7.2
H20
(X)
8.6
8.6
8.7
8.6
8.6
8.8
9.0
8.9
8.7
8.9
8.9
8.9
9.0
8.3
7.3
8.9
8.7
8.7
0.4
(percent) (*
77
69
69
69
70
71
61
76
74
77
77
76
77
72
73
66
73
72
4
QS
(Qsctm
* 103) '
165.6
164.8
174.6
172.5
168.4
170.2
171.5
168.4
165.4
166.9
165.8
169.4
171.9
168.7
171.0
170.0
192.4
170.5
6.3
Ambient conditions
Relative
F) (in hg)
49 30.3
53 30.3
53 30.3
51 30.3
52 30.3
51 30.3
51 30.3
54 30.2
50 30.2
59 30.2
62 30.2
63 30.2
62 30.2
54 30.2
52 30.2
51 30.2
47 30.3
54 30.2
5 0.1
°2
(X
dry)
14.6
14.6
14.6
14.6
14.6
14.4
14.4
14.4
14.5
14.3
14.3
14.3
14.3
14.6
14.6
14.5
14.8
14.5
0.2
CO;,
(X
dry)
3.37
3.33
3.35
3.34
3.34
3.34
3.32
3.50
3.43
3.55
3.54
3.53
3.53
3.38
3.3B
3.45
3.25
3.41
0.09
CO
(ppm
dry)
58
56
55
54
36
64
65
48
35
45
43
42
46
16
16
52
40
48
14
(X)
92.0
73.0
73.0
73.0
73.0
73.0
73.0
93.0
69.5
69.5
56.3
62.5
71.3
93.0
93.0
94.8
77.8
77.1
11.7
NO*
(ppm
dry)
21
13
13
13
13
13
13
14
12
15
16
16
15
39
38
13
18
17
8
NOX
(ib/MBtu)
0.069
0.043
0.042
0.043
0.042
0.041
0.041
0.043
O.U40
0.047
0.048
0.050
0.048
0.127
0.123
0.042
0.060
0.056
0.028
NOX
(Ib/hr)
25.0
15.6
16.3
16.4
15.5
13.8
16.0
16.5
14.7
18. u
18.5
19.6
19.0
46.6
46.0
16.0
24.4
21.2
9.9
Change
across
NOX
Ub/nr)
2.1
-3.4
-3.8
-5.3
-5.3
-5.3
-5.2
-3.0
-3.0
-3.3
-3.0
-2.8
-3.4
4.1
3./
-4.6
-3.3
-3.0
3.1
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
TABLE 19. DUCT BURNER TEST DATA: GEM TEST PERIODS, TEST CONDITION 14
ro
Gas turbine
operating parameters
Day/hour
22 5
22 6
Avg
S.D.
Load
(MW)
14.5
14.3
14.4
0.1
Fuel
flow
(scim)
3,791
3,722
3,756
48
Steam
Inj. ratio
(Ib/lb)
0.71
0.72
0.71
0
Duct burner
operating parameters
Fuel
flow
(scfnO
1,127
1,146
1,136
13
Heat
input
(106 Btu/hr)
70.1
71.3
70.7
0.8
Load
(percent)
43
44
43
1
Duct burner inlet
QS 02
H20 (dscfm (Z
Day/hour (Z) x 103) dry)
22 5 6.4 169.7 16.9
22 6 6.4 172.0 16.9
Avg 6.4 170.9 16.9
S.D. 0 1.6 0.0
CO 2
(Z
dry)
2.38
2.38
2.38
0.00
CO NOX
(ppm (ppm
dry) dry)
41 19
41 18
41 19
0 0
(ppm
iso)
28
27
28
0.5
NOX
(Ib/MBtu)
0.096
0.094
0.095
0.002
NOX H20
(Ib/hr) (Z)
22.8 8.3
22.5 8.3
22.6 8.3
0.2 0
QS
(dscfm
x 103)
168.6
170.8
169.7
1.6
Ambient conditions
Temp Pressure
(°F) (in hg)
50 30.3
52 30.2
51 30.3
1 0.1
Duct burner outlet
02 O>2 CO
(Z (Z (ppm
dry) dry) dry)
15.1 2.97 43
15.2 2.97 44
15.1 2.97 43
0.0 0.00 0
Relative
humidity
(Z)
93.0
94.8
93.9
1.3
NOX
(ppm NOX
dry) (Ib/MBtu)
13 0.047
13 0.046
13 0.046
0 0.001
Change
across
Db
NOX NOX
(Ib/hr) (Ib/hr)
15.9 -6.9
15.7 -6.8
15.8 -6.9
0.2 0.1
Represents missing data.
Note: Means and Standard Deviations are calculated using 15 minute averages.
-------
SECTION 3
PROCESS AND CONTROL EQUIPMENT DESCRIPTION
AND OPERATING CONDITIONS
PROCESS DESCRIPTION
The cogeneration system at Crown Zellerbach's Antioch Mill consists of a
gas turbine which is exhausted through a duct burner and a waste heat boiler.
The gas turbine is a General Electric Model MS60013 which fires natural gas as
the primary fuel and No. 2 fuel oil as a backup source. The turbine design is
unique in that it has air-cooled expander buckets which allow power output
from the unit to be increased from 30 MWe to 36 MWe. The duct burner is a
Coen low NOX design which normally fires natural gas. No. 6 fuel oil can
also be used as an emergency backup fuel source. Under normal operation, the
duct burner increases turbine exhaust gas temperatures from 1000°F to between
1200 and 1400°F. The exhaust from the duct burner flows through a Vogt waste
heat boiler. The boiler is capable qf producing 140,000 Ib/hr steam with gas
turbine exhaust only, and 260,000 Ib/hr steam at the maximum burner firing
rate of 140 MBtu/hr. A schematic of the cogeneration system is shown in
Figure 1.
The system typically operates 24 hours a day with the gas turbine base
loaded at 32 to 35 MWe. During the sampling program, Crown Zellerbach was
curtailed to a nominal generation load of 12 MWe by the local utility between
the hours of 11:00 P.M. and 6:00 A.M. The waste heat boiler supplies between
180,000 and 250,000 Ib/hr of high pressure steam for paper drying and
20,000 Ib/hr of low pressure steam for feed water deaeration. The amount of
high pressure steam required depends on the grade (thickness) of paper being
produced. In addition, an extraction steam turbine coupled to a generator
supplies 12.5 MWe. Normal variations in steam demand are typically met by
varying the duct burner firing rate between 40 and 140 MBtu/hr.
OPERATING CONDITIONS
Table 20 summarizes gas turbine and duct burner operating conditions for
the eight test periods and the purpose of each test condition. Operating
conditions used to divide the GEM data into test conditions are summarized in
Table 21. Included in both tables are mean values and ranges of turbine
generator loads, duct burner firing rates and steam injection ratios. Actual
operating conditions during each test period are documented in Tables 1
through 19 in Section 2.
25
-------
CONVENTIONAL
GAS-FIRED BOILER
(STAND BY ONLY)
NO. 1
(300,000 #/hr)
WASTE HEAT BOILER
(260,000 #/hr)
T
1000°F
EXHAUST
250,000 #/hr
600 psig
12.5 MW TURBINE
GENERATOR W/
CONDENSER
DUCT BURNER
NATURAL GAS/#6 P.O.
180,000 #/hr
I
.. ^
E
150 psig
\
19 q MU
X
\
,, C MU PULP S PAPER
J6.5 MW __ uAi/iwn
J
-\
(b
^S TURBINE
tfURAL GAS
36 MW
PROCESS
^ MW
32 MW
TO PG£E
ELECTRICAL
POWER
Figure 1. General layout of Crown Zellerbach cogeneration power plant.
-------
TABLE 20. TEST CONDITIONS FOR CHARACTERIZING DUCT BURNER EMISSIONS
Turbine
load
(MLO)
Test number
1
2
3
4
5
6
7
8
Avg
34
35
35
32
33
32
33
11
Range
33-35
35-36
34-35
31-33
32-34
31-33
33-34
11-12
Duct
burner
load
(MBtu/hr)
&vg
134
93
41
138
44
137
42
141
Range
120-137
a
a
136-140
40-51
131-139
41-46
133-143
Steam
Injection
ratio
(Ib/lb)
Avg
0.94
0.97
0.95
0.50
0.46
0.00
0.00
0.00
Range
0.92-0.95
0.95-0.99
0.95-0.96
0.49-0.51
0.44-0.47
a
a
a
Purpose of test
Quantify duct burner NOX
emissions as a function of
burner load for low inlet NOX
levels
Determine effects of changing
NOX levels at burner inlet
Determine effects of changing
inlet NOX levels at burner
inlet
Determine effects of changing
02 levels at the burner
inlet
aParameter held constant over test period.
-------
TABLE 21. RANGE OF OPERATING CONDITIONS FOR CATEGORIZING CEM DATA
Test
condition
1
2
3
9
10
11
12
13
14
Turbine
load
(MW)
avg
13.8
34.6
35.0
12.8
12.6
28.5
12.9
12.8
14.4
range
12.3
33.4
34.7
12.8
28.5
11.6
11.9
14.3
- 14.5
- 36.4
- 36.5
- 12.9
a
- 28.6
-14.5
- 13.6
- 14.5
Duct
burner load
(MBtu/hr)
avg
144
85
64
113
56
55
134
118
70.7
range
142 -
69 -
60 -
108 -
a
49 -
113 -
100 -
70.1 -
145
95
73
119
61
150
126
71.3
Steam
injection
ratio
(Ib/lb)
avg
0.74
0.96
0.97
0.93
0.77
0.72
0.76
0.71
0.71
range
0.70
0.93
0.94
0.93
0.66
0.70
0.07
0.71
- 0.80
- 1.00
- 0.99
- 0.94
a
- 0.77
- 0.79
- 0.79
- 0.72
aOne test point for this test condition; range not applicable.
28
-------
SECTION 4
SAMPLING LOCATIONS
Emission measurements were conducted at the inlet and outlet of the duct
burner at the sample locations shown in Figure 2. The mobile laboratory was
located near the base of the stack with one heated sample line running up to
the stack test platform and another running along the waste heat boiler to the
inlet transition duct. Reference method sample trains were positioned at both
inlet and outlet sampling locations.
DUCT BURNER INLET
Figure 3 shows a side view of the inlet sample location. The sampling
plane is located two feet downstream of an expansion joint and approximately
5 ft downstream from the 90° turn in the gas turbine outlet duct. This
location is approximately 15 ft upstream of the duct burners. Two sample
ports were originally located in an access door in the transition duct. Two
additional sample ports were installed to provide more representative sampling
of the duct for preliminary stratification testing. Location of the sample
ports are shown in Figure 4. Also shown in Figure 4 are the inside and
outside duct dimensions, locations of stratification sample points, and the
location of the GEM inlet sample probe.
DUCT BURNER OUTLET
A schematic of the outlet test site is shown in Figure 5. The sample
ports are located at the 64 ft level of the 100 foot stack. The sample plane
is 1.74 stack diameters downstream and 3.13 stack diameters upstream of the
nearest flow disturbances. This sampling location does not meet the Reference
Method 1 criteria of 2 stack diameters downstream of the nearest flow
disturbance. Velocity traverses in the stack were conducted using 24 sampling
points instead of the maximum 16 points specified in Method 1. Sample point
locations for velocity traverses and the location of the CEM outlet sample
probe are shown in Figure 6.
29
-------
GEN
u>
o
GAS
TURBINE
DUCT BURNER
WASTE
HEAT BOILER
INLET
SAMPLING
LOCATION
OUTLET
SAMPLING
LOCATION
(60 ft LEVEL)
SOOT BLOWERS
MOBILE
LABORATORY.
Figure 2. Crown Zellerbach cogeneration facility schematic.
-------
TURBINE
OUTLET
12'
SAMPLE
PLANE
INSTALLED
SAMPLE PORTS
20
14 XI8 ACCESS DOOR
( Right side only)
EXISTING SAMPLE PORTS
14' 9"
Figure 3. Duct burner inlet sampling location.
-------
-*
l'l/8" 2' 3/8" 2' 3/8" - l'l/8"
1
1
1
(INSTALLED
.PORTS
L v -
\
I "
OEM INLET SAMPLE POINT
1
1
1
1
1 EXISTING
1 PORTS
1 _ \
* 1 *
1
1
1
< r1 i" »
~-
1
2'
4'
3'
I1
1
6'
,
1/2"
12'
7 1/2"
1
2'6"
ll
6
/4"
3"
1/4"
t
61/4
Figure 4. Duct burner inlet sampling port and point locations.
32
-------
SAMPLE
PLANE
WASTE HEAT
BOILER
OUTLET
n'6"
16
37'
40'
100
60
Figure 5. Duct burner outlet (stack) sampling location.
33
-------
LEAR SIEGLER
SITU NO /02
11 ft 6 in.
I.D.
POINT
DISTANCE FROM WALL (inches)
1
2
3
4
5
6
7
8
9
10
11
12
2 7/8
9 1/4
16 15/16
24 7/16
34 1/2
49 1/8
88 7/8
103 1/2
113 9/16
121 11/16
128 3/4
135 1/8
Figure 6. Duct burner outlet (stack) sample point locations,
34
-------
SECTION 5
SAMPLING AND ANALYTICAL PROCEDURES
OVERVIEW
The test program to characterize the effects on emissions of a duct
burner in an industrial gas turbine cogeneration facility was conducted
utilizing both continuous and manual reference method procedures. During the
test effort, the duct burner was continuously monitored for 02, C02,
NOX> and CO, as well as stack velocity and temperature.
Continuous monitoring data consisted of 15-minute averages for measured
inlet and outlet 02, C02, NOX, and CO concentrations. NOX emission
rates on a Ib/hr basis were calculated using measured outlet flow rate data
and a derived inlet flow rate based on duct burner fuel flow. In addition,
NOX emission rates were calculated based on the F factor method, using gas
turbine and duct burner fuel flows with 02 and C02 as measured diluents.
Moisture content of the flue gas was determined based on calculated combustion
moisture, measured steam injection rates, and local ambient humidity.
For emission measurements conducted during the eight duct burner test
conditions, inlet and outlet emission values were calculated with both mass
flow rate data and with the F-factor method. Calculated moisture values were
verified with Method 4 moisture test data. Transducer readings in the outlet
stack were verified with 24 point velocity traverses.
A schematic diagram of the measurement sites at Crown Zellerbach's
cogeneration system is shown in Figure 7. Table 22 presents a summary of
measured parameters obtained during the test program from each sampling site
and from the cogeneration unit control room. Procedures for measuring flue
gas emissions, velocity and moisture content, gas turbine and duct burner
operating conditions, and fuel sampling and analysis procedures are outlined
in the following sections.
MEASUREMENT OF FLUE GAS EMISSIONS
Flue gas parameters were measured at the inlet and outlet of the duct
burner with an EPA IERL/RTP Mobile CEM system. The EPA IERL/RTP Mobile
GEM system is housed in a 40 foot environmentally controlled bus. Installed
in the bus are all the instrumentation and sample conditioning equipment
utilized to continuously monitor the cogeneration system emissions.
35
-------
u>
STATIONARY
GAS
TURBINE
COMBUSTION
AIR
WASTE
HEAT
BOILER
<*>
SAMPLE POINT KEY:
SAMPLE POINT
A
B
C
DESCRIPTION
TURBINE EXHAUST (DUCT BURNER INLET)
WASTE HEAT BOILER STACK (DUCT BURNER OUTLET)
FUEL INPUT
Figure 7. Schematic of gas turbine/duct burner sample locations.
-------
TABLE 22. DUCT BURNER TEST PROGRAM MEASUREMENT PARAMETER SUMMARY
Measurement
category
Turbine operating
parameters
Measurement site
1.
2.
3.
4.
5.
6.
Specific measurement
Load
Fuel flow rate
Exhaust temperature
Combustor inlet pressure
Ambient temperature
Steam flow rate for
(see Figure 7)
1.
2.
3.
4.
5.
6.
Steam
Steam
Steam
Steam
Steam
Steam
plant
plant
plant
plant
plant
plant
control
control
control
control
control
control
room
room
room
room
room
room
1.
2.
3.
4.
5.
6.
Measurement method
MWe indicator
Orifice meter
Thermocouple
Pressure transducer
Thermocouple
Orifice meter
NOX control
Duct burner opera- 7. Fuel flow rate
ting parameters
Steam plant control room
Orifice meter
to
VJ
Boiler operating
parameters
Turbine exhaust
measurements
Fuel analysis
8.
9.
10.
11.
12.
13.
14.
13.
16.
17.
18.
19.
20.
Steam flow rate
Steam temperature
Steam pressure
Flow rate
Moisture content
Oxygen content
NO content
NOX content
CO content
Temperature
Continuous NOX
analyzer readings
Ultimate analysis
Heating value
8.
9.
10.
11.
12.
13.
14.
15.
16.
17.
18.
19.
20.
Steam
Steam
Steam
Points
Points
Points
Points
Points
Points
Points
Steam
Point
Point
plant
plant
plant
A
A
A
A
A
A
A
and
and
and
and
and
and
and
plant
C
C
control room
control room
control room
B
B
B
B
B
B
B
control room
8.
9.
10.
11.
12.
13.
14.
15.
16.
17.
18.
19.
20.
Orifice meter
Thermocouple
Pressure transducer
EPA Method 2/calculateda
EPA Method 4/ calculated15
EPA Method 20/Method 3
EPA Method 20
EPA Method 20/Method 7
EPA Method 10 c
Thermocouple
Lear Siegler in-situ
continuous NOX/02 monitor
ASTM D1945-81
ASTM D3588-81
alnlet flow rates (Point A) are determined from measured outlet flow rate and the change in flow rate across duct
burner based on fuel flow and combustion stoiciometry.
"Calculated moisture content is determined from calculated combustion moisture, measured steam injection rate, ana
ambient humidity.
cNo ascarite used, C0£ interference corrected with interference curve.
-------
The measurement sensors utilized are listed in Table 23. A schematic of
the total data generation/acquisition system is shown in Figure 8. This
schematic depicts the interconnection of the sensors contained in the mobile
laboratory. The data were acquired on a continuous basis by an onboard data
logger. Measured parameters were averaged on a 15 minute basis during
continuous monitoring and during test periods described in Section 3.
A schematic of the flow system is shown in Figure 9. Figures 10, 11, 12,
13, and 14 contain schematics of the valve switching box, the wet and dry
sample conditioning systems, the sample distribution assemblies, and the GEM
probe assembly. Calibrations were conducted directly to the instruments and
through the sample line. Sample line calibrations were conducted by closing
the sampling valve and opening the calibration valve in the valve box,
allowing calibration gases to pass from the sampling probes, through the
sample lines, and to the conditioning systems and analyzers. The extracted
flue gas was routed to the mobile GEM via multitube heated sample lines
consisting of 3/8 inch OD thick-walled teflon tubing.
The sample conditioning system was configured to provide a wet gas stream
for the NOX analyzers and a dry gas stream for the C-2, C02 and CO
analyzers. Particulate matter was removed in the heated valve switching box
using a low pressure drop glass fiber filter. The particulate free stream was
transported through heat-traced teflon tubing to the conditioning systems.
The wet particulate free sample gas was split into a wet gas stream and a
dry gas stream in a temperature controlled hot box (wet sample conditioning
system). A flow schematic of the wet sample conditioning system is shown in
Figure 10. The wet gas stream is pumped through a heated sample pump to feed
the NOX instrument flow capillaries. The dry gas stream was directed to the
dry gas conditioning system for moisture removal.
Moisture removal was accomplished by passing the sample through a dual
pass condenser as shown in Figure 12. The first pass occurs under reduced
pressure in which the pump draws the sample through the coil, followed by a
second pass under pressure in which final moisture removal is accomplished.
At this point, the dry sample gas is passed through the valve distribution
system shown in Figure 13, which supplies a flow regulated sample stream to
the 02, CO, and C02 instruments as shown in Figure 9.
The CEM probe assembly is shown in Figure 14. The probe is composed of a
Carpenter 20 liner within a 316 SS sheath for support. Inlet and outlet
probes were positioned in areas of average 02 and NOX concentrations (see
Section 4.0) based on results of preliminary stratification checks.
A pitot tube assembly was attached to the outlet CEM probe to determine
flow rate from the duct burner. Pitot tube positioning in the outlet stack
was based on an initial velocity traverse. A complete velocity traverse was
conducted during each test period to validate transducer readings at this
location. Velocity traverses were conducted using EPA Method 2. A type K
thermocouple was attached to the probe even with the tip of the pitot tube.
38
-------
TABLE 23. SAMPLING PARAMETERS AND METHODOLOGY FOR CEMS
Parameter
Model/measurement
Data recording
NOX
CO
02
C02
Volumetric gas
flow rate
Thermo electron
Model 10A
(chemiluminescence)
Horiba PIR 2000
(NDIR)
MSA 802
(paramagnetic)
Horiba PIR 2000
Beckman 864 (NDIR)
Pitot tube flow
sensor; pressure
transducer
Stack temperature K-type thermocouple
Kaye Digistrip III Process Monitor,
strip chart
Kaye Digistrip III Process Monitor,
strip chart
Kaye Digistrip III Process Monitor,
strip chart
Kaye Digistrip III Process Monitor,
strip chart
Kaye Digistrip III Process Monitor,
strip chart
Kaye Digistrip III Process Monitor,
strip chart
39
-------
MSA 802 0,
BECKMAN 86*t CO,
TECO IDA NO,
HORIBA PIR 2000 CO
PI TOT TUBE
AP TRANSDUCER
GAS FLOW RATE
MSA 802 0,
TYPE K THERMOCOUPLES
HORIBA PIR 2000 CO,
TECO 10A NO,
HORIBA PIR 2000 CO
CONDENSER DRAIN
TIMER
SAMPLING CYCLE
TIMER
©
See Figure 9
KAYE
DIGISTRIP I I I
PROCESS
MONITOR
KEYBOARD
PRINTER
STRIPCHART
RECORDER
Figure 8. Data acquisition system schematic.
-------
INSTACK
FILTER
GAS TURBINE
OUTLET
A - SIDE
STACK
B - SIDE
INSTACK
FILTER
SAMPLE IN
COMPRESSED AIR
IN
COMPRESSED
AIR IN
CAL GAS TO PROBE
CALIBRATION
GASES
(02, CO, C02,
AIR)
ZERO
LOW SPAN
MID SPAN
HIGH SPAN
PUMPING
SYSTEM
TECO
880
CONDITIONER
CONDENSATION
SYSTEM
SAMPLE DISTRIBUTION
SYSTEM: SAMPLE,
LOCAL CALIBRATIONS,
PROBE CALIBRATIONS
TECO IDA NO,,
MSA 802 0,
BECKMAN 864 CO.
HORIBA PIR 2000 CO
MSA 802 0,
HORIBA PIR 2000 CO,,
HORIBA PIR 2000 CO
TECO 10A NO
-EXHAUST
Figure 9. Mobile laboratory flow schematic.
-------
CONTROL
AIR IN
ro
PURGE GAS IN>
SAMPLE IN
VENT
CONTROL
AIR IN
VENT
r-unwt VMkVb
**
\
E
-< r
IACKUP
FIBER
FILTER
CALIBRATION
VALVE
c
VENT
ISOLATION
VALVE
< =SAMPLE GAS TEMP
SAMPLE OUT
CAL GAS IN
AIR IN
Figure 10. Valve switching box configuration.
-------
/
A HOT
SAMPLE PUMP
B HOT
SAMPLE PUMP
A B
TO DRY SAMPLE
CONDITIONING SYSTEM
-»~TO A
NOx INST
-^- A NOx
BY PASS
-»- B NOX
BYPASS
-»~ TO B
NOX INST
INSULATED
HOT BOX
Figure 11. Wet sample conditioning system.
43
-------
COMPRESSED AIR
IN
sv
FROM HEAT TRACE LINE
(.SAMPLE GAS)
sv
CONDENSER
RESERVOIR
PG
REFRIGERATION CONDENSER
-» TO
DISTRIBUTION
rBP) PANEL
CONDENSER
RESERVOIR
DRAIN
DRAIN
LEGEND
SV; SOuENOlO VALVE
SP: SAMPLE PUMP
PG= PRESSURE GAUGE
VG' VACUUM GAUGE
CS: MOISTURE SENSOR
BP:BACK PRESSURE REGULATOR
Figure 12. Dry sample conditioning system.
-------
CO
TO
ANALYZERS
SAMPLE
OR
SPAN GAS
FROM PROBE
Figure 13. Sample distribution system.
-------
PI TOT TUBE (OUTLET PROBE
ONLY)
r^ J
^-
QUICK CONNECT
TO TRANSDUCER
(OUTLET PROBE ONLY)
TYPE K THERMOCOUPLE
*316SS PROBE LINER
Figure 14. GEM sample probe.
-------
Data acquisition was accomplished with a Kaye Digistrip III Process
Monitor. This unit is capable of accepting 48 analog signals at a scan rate
of 10 seconds. The microprocessor acquires and processes the data, printing
out interval reports and providing instantaneous responses.
Response Time
Response time of the NOX and 02 instruments were measured prior to
commencement of the test program. Monitor response time is reported as the
slower of the average of three sets of upscale and downscale determinations.
The upscale determination was based on the time required for the monitor to
respond from a zero calibration gas reading to a stable stack effluent
reading. The downscale determination was based on the time required for the
monitor to respond from a high-level calibration gas concentration to a stable
stack effluent reading. Response times for the NOX instruments were
239 seconds for the inlet analyzer and 216 seconds for the outlet analyzer.
02 response times for inlet and outlet analyzers were 234 and 199 seconds
respectively. Response time data sheets are included in Appendix E.
Stratification Check
A stratification test was conducted at each sample location to determine
representative sample points for velocity and gaseous sampling. The
stratification test consisted of measuring velocity, pollutant, and diluent
concentrations at each traverse point for a sampling time of 1 minute plus the
determined response time of the measurement system. Between each port, the
monitoring system was switched to a reference traverse point to correct for
temporal process variations during the test run. Data collected at each
traverse point were utilized to locate continuous monitoring and reference
method sample points.
Stratification data indicated that duct burner inlet concentrations of
02 and NOX were uniform across the sampling plane. Mean inlet 02
concentration during the stratification check was 15.7 percent with a standard
deviation of 0.02 percent. Maximum and minimum values were 15.7 and
15.6 percent. Mean NOX concentration was 91 ppm with a standard deviation
of 1 ppm and minimum and maximum values of 89 and 92 ppm respectively.
Velocity measurements were not made at this location and no stratification
check was conducted. Based on these results, the duct burner inlet GEM probe
was placed in the center of the duct as illustrated in Figure 4.
Stratification data from the duct burner outlet test location (waste heat
boiler stack) indicated that uniform 02 and NOX concentrations exist
across both dicameters of the stack. Outlet 02 concentrations averaged
13.8 percent with a standard deviation of less than 0.01 percent. NOX
outlet concentrations averaged 36 ppm with a standard deviation of less than
1 ppm and a range of 35 to 38 ppm.
47
-------
Velocity stratification across the waste heat boiler stack was
significant. A summary of velocity data is presented in Figure 15. included
in the figure is a diagram of the stack cross section and a tabulation of
velocities at each traverse point location within the duct. Mean velocity for
the stack based on the initial velocity traverse was 63.6 ft/sec. Based on
these results, and the results of the gaseous traverse, the GEM was positioned
at the point of average velocity, point 7 of Port A, as shown in Figure 15.
Test points for the inlet and outlet sample locations are shown in
Section 4.0. Results from the stratification check are presented in
Appendix E.
Instrument Drift
Instrument drift was determined during the eight duct burner test
conditions according to procedures outlined in the reference methods. To
validate the continuous emission data collected between these periods,
instrument drift was determined based on calibration checks conducted at
24 hour intervals. Instrument drift data are included in Tables 25 and 26 of
Section 6.0 and in Appendix F.
Calibration Error
The calibration error test is based on the response of the monitors to
zero, low level, mid level, and high level calibration gases. For each test
period, the instruments were zeroed with N£ and calibrated with the
mid-range calibration gas. The response of the low and high range calibration
gases were then determined and compared with the applicable reference method
or CEM calibration error specification. Daily calibration curves were
prepared for each instrument to facilitate final data reduction. Daily
summaries of slope and intercept data are included in Appendix K for each
instrument.
Calibration Gas Traceability
All calibration gases utilized during the test program were obtained from
Airco Industrial Gases with an analytical certification of concentration (NBS
traceable). NOX and CO calibration gases were analyzed by the manufacturer
according to the procedures outlined in EPA Traceability Protocol No. 1.
Certification from the manufacturer was obtained stating that the protocol was
followed and the supporting data are presented in Appendix I.
02 and C02 calibration gas mixtures were analyzed by GCA. Each gas
mixture was analyzed in triplicate using EPA Reference Method 3. The average
concentrations from the tests were within 0.5 percent of the stated
concentrations, and the gas manufacturers' analytical certifications were used.
48
-------
WASTE
HEAT
RO 1 1 FR F
DU 1 LL r\ 1
OUTLET
DUCT
" 23456
i
CEM OUTLET
SAMPLE POINT
LEAR SIEGLER
IN SITU NO /02
B
VELOCITY (fe/sec)
DISTANCE FROM
POINT PORT A PORT B WALL (INCHES)
1
2
3
4
5
6
7
8
9
10
1:1
12
AVG
S.D.
30. 4
36.5
37.7
37.1
37.1
39.4
69.6
81.2
86.5
86.5
89.0
72.4
58.6
22.9
65. A
72.9
72.9
72.8
65.5
58.3
52.8
64.8
72.1
73.0
76.0
76.0
68.6
7.02
2 7/8
9 1/4
16 15/16
2k 7/16
34 1/2
49 1/8
88 7/8
103 1/2
113 9/16
121 11/16
128 3/4
135 1/8
Figure 15. Velocity traverse data.
49
-------
Three span concentrations were used for calibrating the NOX, CO, CC>2
and 02 instruments. Span concentrations are presented in Table 24. Pure
nitrogen was used as a zero gas for all instruments.
TABLE 24. CALIBRATION GAS CONCENTRATIONS
02/C02 (%) NOX (ppm) CO (ppm)
Zero
Low
Mid
High
N2
3.18/4.10
8.01/8.05
12.6/19.0
N2
52.1 ppm
125 ppm
214 ppm
N2
30.1 ppm
58.0 ppm
941 ppm
Sequence of Events
The CEM was placed onsite in the area designated by plant personnel.
The sample transport lines were deployed between the sampling locations and
the bus. The filter-valve boxes and reference method instrumentation were
installed at the sampling sites.
Following completion of the installation, the instrumentation was
activated and allowed to come to equilibrium. The instruments were calibrated
and the response time for each monitor was determined, followed by a
stratification check at the duct burner inlet and stack monitoring locations.
A velocity profile of the outlet sampling location was then obtained using
EPA M-2. The placement of the tip of the CEM probe and reference method probe
assembly was based on the results of the stratification check and velocity
profile determination described previously.
VELOCITY AND MOISTURE MEASUREMENTS
Flue gas volumetric flowrate determinations were conducted during each of
the eight duct burner operating conditions at the duct burner outlet (stack).
Velocity traverses were conducted using EPA Reference Methods 1 and 2 and flue
gas molecular weight was determined using 02 and C02 instrument data
during each test. Moisture was determined using EPA Reference Method 4.
Moisture measurements were conducted at both the inlet and outlet sampling
locations using a RAG Staksamplr^M sample train. A diagram of the sampling
train is shown in Figure 16. Velocity and moisture determination data are
presented in Appendices B and C, respectively.
MEASUREMENT OF GAS TURBINE AND DUCT BURNER PARAMETERS
Gas turbine and duct burner operational parameters were recorded during
the test program and are summarized in Table 22. Measurements from the gas
turbine, duct burner, and waste heat boiler were obtained from control room
operating logs and printed output from the control display. During the duct
burner test periods, control room readings were obtained at 15 minute
50
-------
25
1. PROBE
2. CYCLONE BYPASS
3. IMPINGERS, STANDARD AND MODIFIED
4. THERMOMETER
5. CHECK VALVE
6. UMBILICAL CORD
7. VACUUM GAUGE
8. COARSE FLOW ADJUST VALVE
9. FINE FLOW ADJUST VALVE
10. OILER
11. VACUUM PUMP
12. FILTER
13. DRY GAS METER
14. ORIFICE TUBE
15. INCLINE MANOMETER
16. SOLENOID VALVES
17. PITOT
18. THERMOCOUPLE
19. PYROMETER 23.
20. ICE BATH 24.
21. DISTILLED DEIONIZED WATER 25.
22. SILICA GEL DESICCANT 26.
ORSAT PROBE 27.
TEFLON ORSAT LINE 28.
CONDENSER 29.
LEAKPROOF DIAPHRAGM PUMP 30.
PULSATION DAMPER
FLOW METER
TEDLAR BAG
HOT BOX
TM
Figure 16. Schematic of RAC Staksamplr in participate sampling configuration
-------
intervals to characterize operating conditions during each period. During
continuous monitoring of the process, gas turbine and duct burner fuel flow
integrator readings were recorded at one hour intervals. Printouts from the
gas turbine process monitor were also obtained at 1 hour intervals. Process
data taken during test periods and continuous emission monitoring are included
in Appendix D.
FUEL SAMPLING AND ANALYSIS
Fuel samples were collected from the duct burner gas feed lines using the
sampling procedures outlined in ASTM D1145-80. A gas sample was taken during
each test condition and subjected to higher heating value, specific gravity,
and an ultimate analyses. The following ASTM sampling and analytical
procedures were used:
Sampling D1145-80
Natural gas analysis D1945-81
Higher heating value D3588-81
and specific gravity
Results from the fuel analysis show no significant variation in heating
value, specific gravity, or component (ultimate) analysis. An average of
these parameters for the eight natural gas samples was used to derive
F factors, heat input and stoichiometric relationships. The fuel analysis
sample log and analytical results, and averaging calculations are included in
Appendix H.
-------
SECTION 6
PROGRAM QUALITY ASSURANCE
INTRODUCTION
A detailed Test and Quality Assurance Plan was written, submitted and
approved for use under this project. This document was intended to serve as a
guide for use during the field, lab and data handling segments of the
project. The following subsections document the results of the various QA/QC
procedures implemented during this project.
PRECISION, ACCURACY AND COMPLETENESS
Several QC measures were taken to assure the collection of quality data.
A summary of these procedures and their calculated results are presented in
the following subsections.
Continuous Emission Monitors
GCA followed the recommended procedures outlined in 40 CFR 60
Appendices A, B and F (proposed) to assess the precision and accuracy of the
continuous emission monitors used during this program. These checks include
determinations of: relative accuracy, precision estimates, and tests for
instrument drift and response time. Tables 25 and 26 summarize the results
from the Quality Assurance checks.
Relative Accuracy Tests
Relative accuracy tests were performed to assess the precision and
accuracy of the continuous monitors. Reference method tests were performed to
generate information to compare to the monitoring data. Results of reference
method tests and RA calculations are presented in Appendix G.
Calibration Drift
Instrument drift was determined according to procedures outlined in
Reference Methods 10 and 20 during each duct burner test condition. To
validate continuous emission data collected for the overall test program,
instrument drift was determined based on calibration checks conducted at
24 hour intervals. Monitor drift data for the overall program (24 hour drift)
are presented in Tables 25 and 26.
Results from the 24 hour drift checks indicate that the outlet NOV
A
instrument exceeded the 2.5 percent of span criterion, the inlet CO instrument
exceeded the zero drift criterion, and the outlet CO instrument exceeded the
span drift criterion.
53
-------
TABLE 25. QA RESULTS FOR MEASUREMENTS TAKEN AT THE DUCT BURNER INLET
Probability limits
Zero
Parameter
NOX
Oxygen
Carbon dioxide
Carbon monoxide
Flow rate
Moisture
Pol a 1~*f -\Tt*
accuracy
11.86
0.68a'b
O.lbb
NA
6.9C
10. 2d
upper
+0.02
0
0
+19.3
NA
NA
lower
-0.02
0
0
-14.7
NA
NA
Span
upper
+2.3
+2.3
+1.8
+9.9
NA
NA
lower
-1.4
+0.4
-1.4
-4.2
NA
NA
Response
4- 4 mn
seconds
239
234
<239
<239
NA
NA
24-hour
drifta
zero
0.02
0
0.03
3.28a
NA
NA
span
1.58
0.35
0.47
0.77
NA
NA
aExceeded expected performance criterion.
^Results in terms of percent 02 (C02) instead of percent of full scale.
cRelative accuracy of flow rate derived gas flow rate and Reference
Method 2 derived flow rate.
^Relative accuracy of calculated moisture and Reference Method 4 measured
moisture.
54
-------
TABLE 26. QA RESULTS FOR MEASUREMENTS TAKEN AT THE DUCT BURNER OUTLET
Probability limits
Relative
Parameter accuracy
NOX
Oxygen
Carbon dioxide
Carbon monoxide
Flow rate
Moisture
12.72
0.24b
0.14b
NA
11. 6C
15. 6d
Zero
upper
+0.09
+0.42
+1.92
+3.91
NA
NA
lower
-0.08
-0.12
-1.34
-6.56
NA
NA
Span
upper
+2.3
+3.2
+1.2
+4.2
NA
NA
lower
-1.1
-0.1
-1.8
-5.6
NA
NA
Response
time
seconds
216
199
<216
<2i6
NA
NA
24-hour
drift
zero
0.11
0
0.07
0.19
NA
NA
span
6.2a
0.18
0.21
3.07a
NA
NA
aExceeded expected performance criterion.
^Results in terms of percent 02 (C02) instead of percent of full scale.
cRelative accuracy of transducer readings and Reference Method 2 derived
flow rates.
^Relative accuracy of calculated moisture and Reference Method 4 measured
moisture.
55
-------
Monitor drift measured during each test period is summarized in
Table 27. Results from drift checks indicated that the NOX instruments
exceeded the expected performance criteria during five test periods. However,
during the span checks calibration gas was delivered directly to the NOX
instruments bypassing the sample probe and line. This caused calibration gas
to be delivered to the instrument at a higher pressure than during sampling
and 24 hour drift checks causing a higher response from the instrument.
Therefore, drift determination based on test span periods are not considered
valid. Results from 24 hour drift checks indicate that with the exception of
the outlet NOX instrument all analyzers conformed to the stated criteria.
Response Time
Monitor response time was reported as the slower of the average of three
sets of upscale and downscale determinations. The upscale determination is
the time it takes the monitor to respond from a zero calibration gas reading
to a stable stack effluent reading. Conversely, the downscale determination
is the time it takes the monitor to respond from a high-level calibration gas
concentration to a stable stack effluent reading. The upscale and downscale
response time means are determined, with the slower value reported.
Further documentation on the response time tests is provided in
Appendix E.
Precision Limits
Precision limit calculations were performed using data generated from
daily precision checks of the monitors. These estimates were determined using
the protocol delineated in 40 CFR Part 60 Draft Appendix F Quality Assurance
Procedures dated November 19, 1981.
Using the data generated during the daily zero span checks as the basic
data inputs, the upper and lower probability estimates for the zero and high
span levels were calculated according to the following equations:
Y. - X.
d. =
i
where
d. = - x 100
1 A .
Y. = Monitor indicated concentration from the i-th precision check
X. = The precision check reference concentration used for the i-th
precision check.
Periodic average percent difference, d., is calculated as follows:
.-
j n 1=1
56
-------
TABLE 27. MONITOR DRIFT CHECK DURING TEST PERIODS
Duct burner inlet Duct burner outlet
NOX 02 C02 NOX 02 C02
Test zero, span zero, span zero, span zero, span zero, span zero, span
condition %%%%%%
1
2
3
3
4
5
0.6,
2.0,
0.2,
1.2,
1.0,
0.8,
0.2
2.0
0.4
13. 4a
4.2
0.2
0.3,
o,
0,
0,
0.3,
o,
0.6
0
0.3
0
0.9
0
0.2,
0.2,
0.5,
0,
0.2,
0,
3.5
2.7
4.5
1.5
1.9
1.2
2.2,
5.2,
0.2,
1.0,
2.6,
2.8,
3.0
28. 2a
a
15.8
5.8s
24. 2S
o,
o,
0.3,
o,
0.3,
0.3,
0.3
0.6a
0.3
0
0.6
0
0.3,
0.3,
o,
o,
o,
o,
0.6
0.9
0.9
0.3
0.9
0.6
aExceeded expected performance criterion.
57
-------
where
n = number of valid precision checks made during the period j.
The standard deviation of the percent difference (S;) is calculated as
follows:
/ n
.'-i Ed.
i n \i = l i
Upper and lower probability limits (UPL and LPL) at the 95 percent
confidence limit were calculated according to the following equations:
UPL = d. + 1.96 S.
J J
LPL = d. - 1.96 S.
J J
Precision limits for the daily zero check were calculated using the same
equations, except that X£ in the denominator of the first equation is
assigned the value of the instrument full scale operating range.
Calibration Gas Traceability
All calibration gases utilized during this test program were obtained
from Airco Industrial Gases with an analytical certification of concentration
(NBS traceable). Analytical reports provided by the manufacturer are given in
Appendix I.
Reference Methods
During the program measurements were conducted utilizing EPA Reference
Methods 1, 2, 3, 4 and 7. These manual sampling methods were used to generate
data to validate the precision and accuracy of the data from the continuous
monitors. These measurements were conducted in accordance to the procedures
outlined in the reference methods.
EPA Methods 1 and 2
A traverse was conducted at the outlet sampling location to provide data
for a temperature and velocity profile. Based on velocity traverse data, the
GEM probe was positioned at a point of average velocity. A traverse at the
inlet location was not conducted because of the high temperature and
turbulence of this sampling location.
Tables 24 and 25 report the relative accuracy of calculated theoretical
flow rates and measured flow rates.
58
-------
EPA Method 3
Sampling and analyses for carbon dioxide and oxygen was conducted in
accordance to the procedures outlined in the reference method. Quality
control checks performed for this method include the following:
use of fresh Ursat reagents
analyses of ambient air
leak checks of the sampling system and Orsat analyzers
recording data on standardized forms.
EPA Method 4
Moisture determinations utilizing Method 4 were conducted during each
test condition at both sampling locations. Calibrations for the dry gas meter
are presented in Appendix C.
Tables 25 and 26 include the relative accuracy of calculated theoretical
moisture and measured moisture.
EPA Method 7
Sampling for NOX was performed according to EPA Method 7. Calibrations
of the flasks used are provided in Appendix G. All samples collected were
labeled and accounted for on a sample packing list. This list accompanied the
samples submitted to the GCA sample bank prior to analysis. Proper sample
chain of custody was maintained.
Method 7 analysis was performed in the GCA laboratory. After analysis
it was found that 6 of 54 NOX samples provided questionable values. It is
suspected that the sample flask may have leaked or the sample may not have
been collected properly and these values were deleted from the Relative
Accuracy calculations. Field data, laboratory results, reduced results, and
relative accuracy calculations are included in Appendix G.
DATA VALIDATION
Sample data validation was accomplished according to procedures outlined
in the reference methods and through independent calculations of emission
rates.
Calculated NOX emission rates on a Ib/hr basis derived from flow rate
measurements were validated with emission rates determined by F-factor
calculations and measured fuel input. The dilution factors used in the
F-factor calculation were verified using measured 02 and C02 values.
-------
Measured C>2 and CC>2 were verified utilizing the fuel factor, Fo.
FO values determined from measured 02 and GU^ values were compared to
FQ values calculated from fuel analyses. F0 values were derived from the
average fuel analysis with the equation:
0.209 F,
where
3.64UH) + 1.53UO + 0.57US) + 0.14(%N) - 0.46(%0 )
Fd = - - X 10
Fo values were determined from measured 02 and C02 concentrations
with the equation:
20.9 - % 0 dry
F =
o % C02 dry
Trend plots of calculated FQ values are included in Appendix J.
DEVIATIONS FROM THE QUALITY ASSURANCE PLAN
The following deviations from the original quality assurance test plan
occurred.
Method 25A was deleted as a requirement at the beginning of the test
program.
Eight turbine test conditions were tested instead of the originally
scheduled ten conditions. The 110 percent of full load and
oil-fired conditions were deleted.
Ambient air was used in place of a standard gas cylinder for
verifying Orsat performance.
60
-------
REFERENCES
1. Federal Register, October 6, 1983, Standards of Performance for New
Stationary Sources; Stationary Gas Turbines, Advance Notice of Proposed
Rulemaking, 40 CFR Part 60.
2. Emission Test Request to Support Standards of Performance for Stationary
Gas Turbines, Radian Corporation, Durham, North Carolina, September 28,
1983.
3. Test Plan and Quality Assurance Plan for Gas Turbine Method Development
and Testing: Crown Zellerbach Turbine/Duct Burner Testing,
GCA/Technology Division, Bedford, Massachusetts.
61
-------
APPENDIX A
RESULTS AND CALCULATION PROCEDURES
INTRODUCTION
Emission test results are presented and calculation procedures are
outlined in this appendix. Included in the appendix is a discussion of data
reduction, a summary of test data based on hourly averages, a hand validation
of the data reduction program and a summary of NOX emissions calculated
using FQ, FC and mass flow techniques. Calculations for process and
emission calculations are presented in the following section. Summaries of
the emission data and data reduction validation are shown in the tables and
the included calculation sheets.
DATA REDUCTION
The data reduction methods are based on the requirements of the test
program and calculations contained in 40 CFR 60, Appendix A Methods. All
monitoring data, process data and calibrations were stored on computer, and
catalogued according to date and time for each parameter.
Data were reduced and validated using the appropriate calibrations and
the emission calculation procedures outlined below. Measured and calculated
emission values were reported for both continuous monitoring and test
conditions on the duct burner.
Process and Emission Calculations
A computerized data reduction system and manual calculation techniques
were used to process the reference method and continuous monitoring test
data. Process operating data, including operating temperatures and pressures,
gas and steam injection flow rates, and steam production were keypunched onto
computer cards. Other process parameters included were natural gas heating
value and ultimate analysis, as well as ambient temperature and humidity.
Monitored emissions data input into the program included inlet and outlet
NOX, CO, C02, 02, velocity, temperature, and moisture.
To interpret the effect of the duct burner on gas turbine emissions in
the cogeneration power plant, measured gas turbine emissions were subtracted
from the total system emissions to calculate the contribution from the duct
burner. NOX emissions were calculated on a ppm dry, Ib/MBtu, and Ib/hr
basis for duct burner inlet and outlet emissions based on measured emission
concentrations, mass flow measurements, and fuel analyses. Calculation
procedures are outlined in the following paragraphs.
A-l
-------
NOX emissions were measured on a wet basis to eliminate N02
absorption in condensed moisture. Measured wet NOX was converted to a dry
basis with the following equation:
NO = NO
x ppmvd ]__Bws x ppmvw
where
NO , = measured NO corrected to a dry basis (ppm dry)
x ppmvd x i vv ]
NO = measured NO on a wet basis (ppm wet)
x ppmvw x
Bws = fraction of moisture in flue gas (percent).
NOX ppravw was continually monitored with the NOX analyzers. Bws for
the moisture correction was determined based on measured steam injection
rates, ambient humidity, and combustion chemistry. Calculated Bws was
verified with Reference Method 4 moisture determinations conducted at each
duct burner test condition. Bws was calculated based on a ratio of moles of
dry flue gas per mole of wet flue gas with the following equations:
tV, dry/lb fuel
where
theoretical !!_ wet/lb fuel
r (j
1, ,~ = moles of flue gas dry per Ib of fuel for both gas turbine
and duct burner
nFG dry = %C %H %S %°2 %N 20.9
Ib fuel 252.2 106.3 672.0 850.6 280.2 20.9-00
nFG wet
YT77- = moles of flue gas wet per Ib of fuel
For the gas turbine
n ., n_., dry n . . n . n, . ..
i?G wet _ FG steam inj. comb moist humidity
Ib fuel ~ Ib fuel + Ib fuel + Ib fuel+ Ib fuel
For the duct burner
FG wet _ FG comb moist / GT \ steam inj. humidity
Ib fuel ~ Ib fuel + Ib fuel + \ M_,r + Mni3 I Ib fuel + Ib fuel
* Oi Do/
A-2
-------
M = Gas turbine fuel flow, (scfm)
(j L
M = Duct burner fuel flow, (scfm)
For both gas turbine and duct burner
n
steam inj. _ Ib steam/sec 18 mole steam
Ib fuel Ib fuel/sec Ib steam
comb moist.
, , " _ .' "- /oil/ jL\J\J
Ib fuel
,, n , 1U 29 Ib air
n, , . grains u u , , ~,. ...HID , , ,
humidity _ ,. 2 1.429 x 10 Ib mole air
Ib fuel " Ib dry air grain
TV. ^ moles 0
Ib mole air 2
18 Ib HO
Ib mole HO
20.9
0.209 Ib mole 0,
Ib fuel
20.9-0,
NOX emission rates were converted from the measured concentration on a
dry basis to ppmvd at 15 percent 02 at ISO conditions, Ib/hr based on
measured mass flow rate, and Ib/MBtu and Ib/hr based on the F-factor method,
NOX on a dry basis at 15 percent 02 at ISO conditions is calculated for
gas turbine emissions with the following equation:
where:
NO
= NO
Pamb ' 19(Hobs-0. 00633)
ISO
Xobs \PISO/
3) [288°K\ l'
^ Tamb/
53
NO = NO corrected to ISO conditions (ppm @ ISO)
V V r r
ISO
NO = Measured NO corrected to 15% 0 (ppm day)
X , A £-
obs
^amb = observed local ambient pressure (in Hg)
PISO = standard pressure for ISO correction 29.92 in Hg
e = 2.718
A-3
-------
Hobs = observed humidity (grains/lb dry air)
Tamb = temperature of ambient air (°K)
NOX on a Ib/hr basis calculated from measured mass flow rate were derived
with the following equation:
46.0 Ib mole~1NO
ENO = NO , x r x QS dscfm x 60 min/hr
x x ppmvd 6 3 .. -\
^ 385.3 x 10 ft mole ppm
where
E = NO mass emission rate from gasturbine or system (Ib/hr)
IN \J X
X
NO , = Measured NO on a dry basis (ppmvd)
x ppmvd x J ft^
QS = Measured mass flow rate (dscfm)
QS from the duct burner is calculated from the molecular weight of the
stack gas, stack moisture, and velocity with the following equations:
T P
QS = 3600 (1-B) (A) (Vs) (!) x (-
DB W8
sta std
where
2
; = stack area (ft2)
s
= (85.49) (Cp) (Ap) avg
(Tsta) avg 1/2
Sta (ft/sec)
P MW
sta sta
Cp = Pitot correction factor (dimensionless)
/\p = Velocity Pressure (in. H20)
T = Stack temperature (°R)
S Ccl
P = Stack pressure (in. Hg)
S C3
MW = MW (1 - B ) + 18.0 (B ) (Ib/ib mole)
sta dry ws ws
MW, = 0.32 (%0_) + 0.44 (%C00) + 0.28 (%N0 + %CO) (Ib/lb mole)
dry 222
A-4
-------
Tstat = 528
QS from the gas turbine was derived from measured outlet flow rates and
duct burner fuel flow rates. Gas turbine flow rate was calculated with the
equation:
QSGT = QSDB + (QSC X V
where
QSn,r = Gas turbine exhaust flow rate (dscfm) @ 68°F and 29.92 in Hg
01
QS1NO = Duct burner (stack) flow rate (dscfm) @ 68°F and 29.92 in Hg
UD
QS , = Correction coefficient based on fuel analysis and combustion
chemis try
(dscfm exhaust gas/scfm fuel)
M,.u = Duct burner fuel flow rate (scfm) @ 60°F and 29.92 in Hg
Do
The correction coefficient above was calculated by determining the
volume of 02 consumed and C02 generated on a dry basis per standard cubic
foot of gas (scf fuel) based on the natural gas fuel analysis. Therefore:
QSC .= A02 + ACU2
where: A02 = 02 consumed across duct burner
AC02 = C02 generated across duct Burner
AU2 is determined from combustion stoiciometry and fuel analysis from
the following equations for carbon and hydrogen in the fuel:
a/ . I mole 00 DSCF 00
A f^ nt\J L Z » n e 'i ^- l-i
AO,. - 77- x -rr- x x Jo5.-) , ,. x nat 1 gas
2., 100 MW mole C mole 0 "
U \j 2
y , mole 0 DSCF 0
Aoo = T7T?T x l^T x o i u x 385'3 i n x P nat'l gas
2., 100 MW 2 mole H mole Q
rl n z Z
where:
C = weight percentage of carbon in fuel (Ib C/lb fuel)
%H = weight percentage of hydrogen in fuel (Ib H/lb fuel)
A-5
-------
MW(j = molecular weight of carbon, 12.01 Ib/lb mole
MCOj.j = molecular weight of hydrogen, 2 Ib/lb mole
385.3 = molar volume, DSCF/mole at 68°F and 29.92 in Hg
P = density of natural gas, lb/ft3 @ 60°F 14.7 psia
Because one mole of C02 is generated for each mole of oxygen and
carbon (C + 02 ACC^), ACC>2 across the duct burner is equal to
NOX emission rates on a Ib/MBtu and Ib/hr basis were calculated using
the F-factor method shown below.
-7 lb N°x 20 9
NO = 1.194 x 10 = - x NO , x F x
where
x - 3 - d - - - 20.9-0.,
ft -ppm ^r 2
NO = NO mass emission rate (Ib/MBtu)
x x
NO , = Measured NO on a dry basis (ppravd)
x ppmvd x
DSCF
F = F - factor (FD or Fc)
- Measured 0_ on a dry basis (percent)
EFNO = NO Ib/MBtu x M Ib/hr x HHV
xx lb
where
EFNO = NO mass emission rate from gas turbine system
based on F-factor calculations (Ib/hr)
NO Ib/mBtu = NO mass emission rate (Ib/mBtu)
x x
M = Fuel flow rate (Ib/hr)
HHV = Heating value of fuel (MBtu/lb)
To determine the effect of the duct burner emissions, NOX generated or
destroyed by the duct burner is determined by the difference of the inlet and
outlet mass emission rates:
ENO = ENO - ENO
XDB XSYS XGT
A-6
-------
where
ENO = NO emission rate from duct burner (Ib/hr)
XDB
ENO = NO emission rate from cogeneration system (Lb/hr)
XSYS X
ENO = NO emission rate from gas turbine (Ib/hr)
XGT
Measured carbon monoxide concentrations were corrected for C02
interference utilizing a correction factor determined by measuring CO
instrument response at known C02 concentrations. Interference was measured
at four C02 concentrations. The interference curve is shown in Figure A-l.
Because measured C02 concentrations averaged around 3.5 percent, interference
response was linearized for concentrations less than 4 percent (see
Figure A-l). Carbon monoxide concentrations were corrected with the following
equation:
CO = CO - (2.97 x C0_)
corr meas 2
where
CO = corrected carbon monoxide (ppm)
corr
CO = measured carbon monoxide (ppm)
meas
2.97 = slope of interference curve
CO = measured CO
Data Reporting
Data manipulations were performed using the GCA time-shared computer
in conjunction with the Statistical Analysis System (SAS). The total
emissions data base was keypunched verified and stored on disk for access by
the time-share computer.
The total data reduction process is shown in Figure A-2. Essentially,
all program data were sorted and merged by day and time. Steam and fuel flows
were derived from integration readings taken from the Crown Zellerbach control
room. Concentrations, flow rates, emission rates and other important
parameters were then calculated on a quarterly and hourly basis for the entire
project. Additional calculations were conducted on the test condition
intervals using data obtained from EPA Reference Methods 2 and 4. From these,
quarterly and hourly reports were generated for test conditions one through
eight. Other data manipulations included summarizing the remainder of the GEM
data into additional test conditions based on hourly average process
parameters, a quarterly NOX summary, and trend plots used to verify data
input and results.
A-7
-------
I7.5i-
>
E
CL
a.
*
c
a)
b.
o
a.
a.
o>
c
o
o
O)
CC
c
0)
10.5-
.- 3.5 -
IS.3ppmCO
8.05 %C02
% C02
Figure A-l. C02 gas concentration interference vs. CO instrument reading.
-------
5 PROCESS 1:
CAS TURBINE
DATA, CEM &
TEST PERIODS
PROCESS 3:
DUCT BURNER
DATA, TEST
PERIODS
8 PROCESS «:
CAS TURBINE
FUEL FLOW,
TEST PERIODS
OUTLET
CALIBRATION
SLOPES AND
INTERCEPTS
PROCESS 2:
CAS TURBINE &
DUCT BURNER FUEL
FLOWS, CEK PERIODS
CONCORD
AMBIENT
CONDITIONS
CALIBRATION
SLOPES AND
INTERCEPTS
* CONCORD
AMBIENT
CONDITIONS
I8CALIBRATION
SLOPES AND
INTERCEPTS
MERGE BY TIKE
AND COMPLETE
FILE
CALCULATIONS USING
TRANSDUCER READINGS
1 REFERENCE
METHOD MOISTURE
VELOCITIES
* QUARTERLY
REPORT PRINTER
FOR ALL
OBSERVATIONS
"QUARTERLY DATA
FOR ENTIRE TEST
PERIOD WITH NO,
FOR ORIGINAL TEST
COND. CALC. USING
REF. METH. DATA
29 QUARTERLY
DATA FOR
TEST
CONDITIONS
"PLOT BY TEST
CONDITION
EMISSIONS,
FUEL FLOWS,
VELOCITIES. ETC
CALCULATE
HOURLY AVERAGES
FOR ADDITIONAL
TEST PERIODS
ONLY
QUARTERLY
NOX SUMMARY
REPORT PRINTER
FOR DB INLET
6 OUTLET
Figure A-2. Crown Zellerbach data reduction.
A-9
-------
GCA/T LCMNOLOGY DIVISION
CuOt-N 7.ELLt.n[>ACn DUCI oUKMER Ct-M L/ATA
HOURLY AVERAGES
G i S
0 L C "T *
L-UCT uUrtMEh INLET
as
» DAY I-R
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^J/*tTU LS/Hri * S
f-uCT BURNER CUTi_tT
OS
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AVEKAU CoCl BURNER INLET TEMP = 10oS F
AVERAtE LUCT BURNER OUTLET TEHP=301 F
-------
GCA/TLCHNCLOGY DIVISION
CKOk'N ZELLtKbAUn CuCT uUrSNER CLM D*TA
HOURLY AVERAGES
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BURNER OUTLE
C02 CO NOX
-i PPM PPM
DRY ORY D*Y
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0. 238
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122
129
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-1.2
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9.6
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210.6
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0.2 167.0
6.5 Ib5.o
5.2 197.2
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11.3 202.5
11.1 2C5.7
11.1 157.5
11.2 172.8
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11.3
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5.6
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11.5
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14.6
14.8
14.8
15.9
15.5
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14.3
14.7
14.3
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13.0
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13.0
13.0
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14.0
13.9
13.9
13. a
13.7
13.2
12.9
3.41
3.37
3.27
3.23
2.54
2.73
2.94
3. BO
3.54
3.41
3.70
4.05
3.97
4.2b
4.2?
4.25
4.25
4.27
4.21
4.2?
4.25
4.30
3.73
3.67
3. fan
3.73
3.73
3.72
3.71
4.03
4.18
15
15
15
15
75
77
39
17
23
bi
16
16
17
15
15
16
16
16
16
16
lb
lb
35
t2
37
32
33
36
43
30
27
35
35
27
23
13
12
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30
23
20
34
3?
32
43
44
41
43
44
53
49
45
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32
27
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1'9
25
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43
45
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0.113
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0.046
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0.050
0.072
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0. 103
0.113
C. 114
0. 141
C. 127
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0. 117
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. REPRESENTS HISSING L.ATA
AVERAGE DUCT LUKMR IiJLET TEMP=10if. F
AVERAGE DUCT bURNER uUTLET TEI*P=301 F
-------
GC4/TLChKOLCbY DIVISION
ZEut-EkbACn OU CI ollFi'NER CLM u«TA
HOURLY AVERAuES
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20
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7440
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7.6
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201.7
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229.7
215.5
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209.0
200.9
203.5
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176.3
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173.7
171 .<
170.9
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14.9
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14.9
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1 3.7
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REPKtSENTS HISSIN3 OATA
AVERAtE OUCT bURNER li.LET TEMF- = 103b I-
AVERAL-E UL'CT BURNER OUTLET TEMP=3C1 c
-------
GCA/TLChNULOGY DIVISION
5 *
fa *
V
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10
11
12
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14 *
15 *
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0.77
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0.76
0.76
0.78
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2190
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6.9
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172.3
167.6
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174.5
170.3
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1 70.3
1 70.2
170.6
170.5
171 .5
171 .6
JUCT HUKMER INLET
02 C02 CO NOX KiuX
I \ PPM 'PM PFK
DRY DKY DRY OhY ISO
1 b.3
14.5
14.6
14.9
1 4.9
'4 3
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14.8
4.8
4.8
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4.8
4.9
4.8
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1 7.1
1 7.1
1 7.1
1 7.1
1 7.1
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16.5
16.5
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1 o.5
16.5
1 0.5
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1 b.6
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16.6
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3.bC
3.60
3.5?
3.62
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3.b3
3.63
3.62
3C T
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3.64
3.6l
3.65
2.64
2.2,:
2.22
2.24
2.24
2.23
^ . 3 1>
2.29
2.20
2.21
2.22
2.23
5 DC
^ £. ~
2.25
?.24
2.15
2. 1 B
2.17
2.19
2.17
2.20
i.21
2.21
2.22
32
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12
7
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6
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62
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71
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0 .131
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0.087
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0 .094
0 .087
0.077
0.0 76
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0.^79
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G .033
0.033
0 .080
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0.076
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* DUCT BURNf.R JUTLE
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OSCFM 02 C02 CO NOX
NOX * h20 3 X X PPM PPH
L3/HR * X X1G JAY DRY uRY DFY
49. P * 1^.1 192.7 13.9 3.74
59. b * 1C. 8 203.7 13.4 4.09
b" b ,i * 10.8 204. fa 13.4 4.1o
60.3 11.0 204.0 13.3 4.24
60.3 * ll.i) 202 .4 13.2 4.23
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59.0 « 11.2 19fa.5 lj.2 4.17
57.3 * 11.3 196.3 13.1 4.16
5b.7 * 11. b 200.0 13.2 4.16
57.2 * 11.3 201.3 13.1 4.23
57.2 11.0 200.3 13.2 4.25
5b.8 * il.l 201.2 13.2 4.30
5b.9 * li.l 203.4 lo.3 4.26
37. 1 * 5.7 176.9 14.0 3.75
20.3 * 5.0 167. f 14.4 3.53
21.2 * 5.3 16c.. 3 14.4 3.53
19.9 « r.9 166.7 14.4 3.5*
15.7 * 6.5 166.7 14.4 3.51
19.2 « t.9 169.6 14.4 3.47
22.3 fc.2 16c.7 15.2 2.95
22.7 e.2 170.o li.,2 2.97
20.1 * t.2 171.2 15.2 2.91
19.7 fe.7 Io5.6 14.5 3.42
19.6 H.R 166.2 14.4 3.50
2U.U * 6.7 160.1 14.4 3.53
21.0 i.9 166.= 14.3 3.55
21.7 6.9 Ib6.1 14.3 3.55
22.2 i.9 16B.3 14.3 3.54
22.5 5.0 171.4 14.3 3.53
21.5 5.0 172.4 14.4 3.52
20.5 * 5.0 166*1 14.3 3.52
20.0 9.1 167.3 14.3 3.54
20.3 .-.8 166.2 14.4 3.45
19.6 * 5.0 li.8.1 14.4 3.55
19.5 r.9 16o.3 14.4 3.51
20.2 * 6.9 168. b 14.4 3.54
20.1 6.5 Ib9.c 14.4 3.55
27.3 5.0 165.0 14.4 3.55
34
21
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61
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57
56
56
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30
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40
37
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14
14
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AVERAut UUCT LUHNER INLET
AVERAtE DUCT cURNER uUTLET TENP=301 F
-------
GCA/TLChNCLOGY DIVISION'
CKOW\ ^Ew
DUCI oUhNER CLM i, AT »
HUURLY AV£RAoES
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196
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192
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. REPRESENTS M1SSJN3 DATA
AVERAGE CUCT bURNER INLET 1EKP=1C38 r
AVERAtE LUCT bURNER OUTLET TE*P-301 F
-------
GCA CORPORATION 213 Burlington Road
_ _ Technology Division Bedford. MassachusettsOl730
C^C^ A Telephone 617-275-5444
v7V-^/-N Telex 92-3339
/-£>2? - #6 z-
JOB NO
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PROJECT,
DATE CHV
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B'K. CH'K. BY
A-15
-------
GCA
GCA CORPORA I ION /UHmlmqiunHoijd j nr
Technology Division Buciiord. Massachusetis 01730 "*'
JOB NO D»TE ->/ '/j.-
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A-16
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PROJECT
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A A A GCA CORPORATION
^F^K^k Technology Division
^,;!^/ Ce.<-£c /'n-if
213 Bi/rlngioii Road
Bedford. MassachusellsOi730
Telephone. 617-275-5444
Telex 92-3339
SHFFT _7 OF J
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A-17
-------
GCA
GCA CORPORATION 213 Burlington Road </
Technology Division Bedford. Massachusetts 01730 SMEET-t OF-
lulux 92 3339
J08NQ.
PROJECT.
SUBJECT.
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CH K. Bf_
DATE CH'K.
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A-18
-------
GCA CORPORATION 213 BiKlington Road
Technology Division Bedford. Massachusetts01730 5MtEI
Telephone 617-275-5444
Telex 92-3339 BY~
JOB NO-
PROJECT , CH'K. BY
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A-19
-------
OCA COHPOHAIION ;'iaHniln»|i,«iHU.I.I /
Technology Division UM.HMHI M.iv,;ii.iiir.i:ii<.(ii/:«) '°-
JOB «n
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A-20
-------
GCA CORPORATION 213 Burlmglon Road _
Technology Division Bedford. Massachusetts 01730
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GCA COHPOHAIION :M:I HuiliMqimHo.-nl
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GCA/TLCHNOLCGY
DI VISION
CF.OWW ZE Li-L;i of
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17
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3 7
TIME
2345
0
15
30
45
ino
1 1. *j
130
145
200
215
230
245
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345
403
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430
445
500
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645
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730
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1100
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16
16
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30
31
25
21
20
20
20
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20
20
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1?
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37
36
36
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104
105
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56
35
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FPM
DRY
13
17
17
18
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30
32
33
28
22
22
21
21
22
21
21
21
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21
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21
1 1
20
24
26
42
42
41
40
40
39
3?
40
40
41
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56
111
111
112
113
115
112
112
61
38
38
MOX
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27
27
27
27
27
28
3*1
40
41
36
31
31
30
33
32
30
31
30
30
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34
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44
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39
39
38
38
38
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33
37
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102
102
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101
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34
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* NOX EMISSIONS
* FO METHOD
*
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0.095
0.095
0.094
C.095
0.095
0.097
a. 133
0.139
0.144
0. 12 ft
0.109
0. 109
0.107
0.108
0.112
C . 3. 0 7
0.107
0.1-16
0. 105
C . .1 0 5
0. 105
0. 106
0.1 0 5
0.104
0.137
r. 1 p 1
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0 .151
0. 139
0.136
0.135
0.133
0.133
0.132
C .134,
0.135
0.138
0.136
C.191
0.3=2
0. 391
0.392
0.398
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0.118
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0.115
0.314
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0.147
0.144
0.143
0.141
0.140
0.140
0.142
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0.203
U.413
0.405
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0.414
0.419
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0.408
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0.157
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27.9
27.6
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6CA/TECHNOLOGY
CI VISIOIvl
N. ZL'LLERuACfi
DUCT BURNER It-JurT MCX OATA SUHKASY
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A-27
-------
GCA/TtC:iMOLOGY
DIVISION
CROWN ZEuLilRjACH
OUCT ollRNER IMET NOX DATA SUMMARY
*
*
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TIME
4 1 S
430
445
500
515
530
545
600
615
630
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700
715
730
745
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27
27
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29
30
28
31
30
29
30
29
30
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38
39
38
33
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36
38
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12
23
28
23
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31
32
30
34
32
32
33
32
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33
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42
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41
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ISO
20
40
49
49
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42
39
37
55
32
31
33
32
33
33
33
32
40
41
41
40
41
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NOX EMISSIONS
FD METHOD
LB/fi&TU LB/HR
0.070
0.138
0.169
0.169
0.168
0.143
0.134
0.12 >'
0.123
0.111
0.108
0.112
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I-C METHOD
LB/MBTU LB/HR
0.070
0.136
0.167
0.166
0.165
0.140
0.131
0.126
0.1 20
0.109
0.107
0.110
0.110
0.112
0.112
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0.152
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0.151
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C . 156
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0.3? 5
LG/HR
20.5
20.5
20 .9
o o n
c. c. J
OO 1
£-£. i
22.0
21 .4
21 .1
,?1 .1
21 .1
20.9
23.0
19.4
15.1
3 ? . (j
45.7
43. U
43.1
(2 . 0
23.7
19.?
19.4
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20.5
20.2
20.2
41.2
64.0
64.0
62.0
f.3.8
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61 .b
60. 8
59. S
172
174
176
174
176
174
175
175
176
1 74
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* i
4
;Y
\'GX EMISSIONS * !
-KC H£ThO'J
*
* Lti/MBTU
*
*
*
*
*
*
*
*
ft
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»
*
*
*
*
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ft
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0.101
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0.100
0.09B
0. 098
0 . 0 V P.
t. 055
0.096
0. 09o
r/. 093
T; . 0 9 1
0. 163
i. . 1 '> 5
0 . 1 K 3
0.203
C.205
0.116
0. 094
0.095
0.096
0 . 0 9 4
0. 092
0.092
0.094
0.142
0.143
0.139
0-134
0.132
0.131
C.13U
0.127
0.127
0.391
C.325
C.357
0.394
0.395
0.40U
0.401
C.404
0.405
C.404
o . 4 0 f>
0.410
LB/HR
20. c
21. 1
21.3
O *3 -^
<: ^: . 3
22.6
21.9
U1.7
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C i . 6
.-'i. 3
2'j. 3
19. -5
19.4
3H.6
4c.3
43.5
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42.6
24.2
19.b
19.8
21.2
20. S
20.5
20.4
41.5
63.3
63.9
6C.3
63. S
62. 5
r. 2.i
61.S
60*7
60. 7
181
133
184
132
1S3
1'32
133
1'84
184
164
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1H7
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A
*
A
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i U . 5
21.1
20.1-
on 7
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c. u » f
20. f.
20.4
20. 1
1 c'. H
20.1
iiC. 0
20. 1
1?. 2
ia.7
3i. 3
40.7 '
3J..7 '
'f4.2
4'i. 5
24.9
2C.5
20.0
20.3
19. a
19.4
19. 6
20.2
47.9
61.7
59.5
57.. 2
56.7
56. R
1)5. 9
55. 6
55. P
159
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J 62
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161
161
161
163
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192 *
190 *
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TEST
COMD
12
12
12
12
12
12
12
12
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13
13
13
13
12
12
12
12
12
12
12
12
12
12
12
12
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2
2
2
2
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7
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V
. REFfESLNTS HISSING DATA
A-31
-------
GCA/rECHNCLOG
D I V I S I U\l
CROWN ZELLERBACri
DUCT faURNES li\LET .MOX DATA SUMMARY
*
*
*
* DAY
* 20
- 20
« 20
* 20
* 20
* 20
» 20
* 20
* 20
* 20
* 20
* 20
* 20
* 20
» 20
* 20
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* 20
* 20
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* .? 0
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* 20
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* 21
* 21
* 21
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ir
TIME *
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i i 3 fl *
1345 *
1400 *
1415 *
1430 »
144 'j *
15 on *
151 5 *
1530 *
1 =. t 5 «
1600 *
1 6 1 t> *
1630 *
1645 *
1715 *
1730 *
1745 -
1800 *
1*3 IE *
1S30 *
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1 'i 3 0 *
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2000 *
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2030 -
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21GC *
2i'i:: *
2130 *
2145 *
2200 *
2215 *
2230 *
2245 *
230 o *
2 ? 1 5 *
2330 *
2345 *
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f.CX
WET
104
104
104
105
105
105
105
105
105
105
135
1 06
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93
104
1C4
58
39
38
37,
36
36
36
36
36
3&
3t.
36
35
30
55
35
35
35
36
36
36
36
36
35
19
16
19
22
17
17
16
i\OX
PPM
DRY
112
111
112
113
113
113
113
113
113
113
113
114
113
99
112
112
63
42
41
41
4Cl
40
4u
39
40
40
40
39
39
39
39
39
39
39
40
40
40
40
4C
38
20
17
20
24
18
18
17
NOX
ISO
112
111
112
112
112
111
111
111
1 11
1 11
111
] 12
106
96
107
107
fil
41
Z'i
39
39
39
33
38
3£
39
3G
38
33
38
33
3c
37
3 K
38
3fi
39
39
39
38
29
26
31
27
27
27
27
*
*
*
*
4
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4
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NOX EMISSIONS
FD METHOD
LB/MBTU L6/nR
0 . 33 6
0 . 3«f;
0 . 38 7
0.389
0.392
0 . 3fl 9
0.389
0. 3H '3
0.33 -J
C..V37
0.38 i
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0. 3P8
0.34 7
0.384
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0.210
0.141
0.135
C.136
C.134
C . 3 ;<. 4
0 . 1 3 2
0 « ] i 1
0. 132
C.132
0.131
G. 131
0.13U
0, 129
C. . i 3 0
6.130
0.12 8
0.12?
0.131
0. 133
C.133
0.134
0.134
0.132
0.101
C . 0 8 9
0.109
0.126
0 . G 9 3
0. OS 2
0. 092
1 7 4
1 74
1 '74
175
17-J
175
174
171
1 73
172
1 73
1 74
173
160
1 77
176
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94 .?
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61 .0
62.4
61.7
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60.7
60.4
60 .0
60.3
1:0.2
59.3
59.7
60.9
60.1
o0.3
6J .6
60 .8
29.6
22.5
' 20.0
24.4
27.3
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NOX F. HIS MOMS
f'C METhOL-
LB/KBTU L3/HR
0.403
0 . 4 !) 1
0.406
ij. 41 2
j.420
0.415
0 . 4 1 6
0.413
0.413
0.413
0.4 ] fi
0.416
0.4 IS
0.376
3.404
0 . ;i G ;?
C . 7» 9 Q
1; . 2 1 8
0.145
0.139
0.140
0.139
0.13?,
0.136
c.l 35
0 , 1 ? 6
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0.135
0. 135
0.134
C.i 33
0.134
0.134
C.i 32
0.153
0.133
0.136
0.136
i; . 1 3 7
0.137
0.] 38
0.107
C.096
0.117
0.134
0.099
C . 0 9 5
0.098
13?
1 o 1
133
185
l&ci
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18 7
185
184
lo"!
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186
173
186
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62.6
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63.6
62. o
62.1
63. 0
62. 9
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62.6
62.2
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62.0
62.0
61.0
61.7
62.5
61.8
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62.3
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30.8
24. U
21.4
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29.0
21.3
21. 3
21.1
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4
4
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21.
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2
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1
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2
4
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2
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2
4
-------
GCA/T
£. T
*
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4
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21
21
21
21
21
21
21
21
21
21
21
21
21
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21
21
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21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
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21
21
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V i S K
TIME
100
115
130
14 b
200
210
230
24b
30U
315
330
341,
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43C
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500
51 5
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600
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700
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8.15
830
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900
1300
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4
* ,'jOX T-.OX
* PP-; PPM
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4
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16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
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16
16
32
40
36
37
37
36
36
36
36
36
35
35
37
37
37
37
38
37
38
37
38
38
3fi
37
37
37
37
13
IB
1".
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17
17
13
17
17
17
17
17
17
i 7
17
17
IV
17
17
17
17
35
44
42
41
41
40
40
40
40
40
39
39
41
41
41
41
41
41
41
41
41
42
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41
41
41
41
Ci
f'iOX
ISO
26
26
26
26
26
27
27
26
26
26
24
24
r.5
25
25
24
25
25
25
?5
39
41
3fi
37
37
36
36
37
36
37
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41
39
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39
39
39
39
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39
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40
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39
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19.0
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60 .0
59.5
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63.0
63.6
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£»?.5
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62.0
61.8
61.5
* .\GX EMISSIONS
* rC METhC.'J
* LE/iV3TU Lb/riS
*
4
*
*
4
*
4
4
4
4
*
4
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0.093
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0. 097
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0.097
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0. 096
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21.4
22.4
22.5
21.6
21.7
21.9
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21.7
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20.9
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. REP,"£:SE:NTS HISSING DATA
A-33
-------
C-CA/TLCHKCLOGY
Q1V 1 SIJM
CKOl-'fJ 7ELL
DUCT bURMlR I.'JLE.T NGX DATA iil.lM.'-'ARY
A
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22
22
22
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TIM-:
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12
12
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MISS1NS DATA
A-34
-------
GCA/TLCKNCLGGY
D I V1 S I CW
DbCT
J.'JLET MGX DATA SUMMARY
*
*
*
*
*
*
*
*
+
4
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DAY
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
£2
22
22
:?2
22
22
22
22
22
22
22
22
22
22
22
22
22
22
TIME
515
530
545
600
61 b
630
64b
700
71 j
730
745
800
SI?
945
10CO
101 «!
1C3G
104'j
1100
llli
113P
a i4-j
1200
1215
1230
1245
13UO
1315
123C
1345
1400
1*15
1430
144b
1500
1523
1530
1543
16CC
1615
1*30
1645
17UO
1715
1730
1745
I?. GO
1 1 1 :;
*
* KOX NOX
* ppy. PPM r-:ox
* >.-^T DRY ISC
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17
17
17
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15
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15
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15
15
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15
15
15
15
15
15
15
16
15
16
16
16
16
J.7
17
17
17
16
17
17
17
17
17
17
17
16
15
16
16
16
15
19
19
19
19
18
IS
18
18
16
16
16
16
16
la
16
16
17
la
16
16
16
17
17
16
17
16
17
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17
16
18
18
18
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IS
18
18
IB
18
18
IB
17
17
17
18
17
17
21-
28
23
26
27
27
27
27
2b
2 5
25
26
2fa
23
23
23
23
23
22
22
22
23
22
22
?2
22
t'2
23
23
22
23
23
23
23
23
24
24
24
23
24
24
24
23
23
23
24
23
22
*
w
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4
*
*
4
*
«
*
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*
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4
4
4
*
4
*
4
4
4
*
*
NOX EMISSIONS
hD METHOD
LB/K6TU L'j/hrt
0. 096
0.096
0.096
0. 096
0. 094
0."94
0.053
0. CT3
0.085
0. 035
0. 08 '»
0.086
O.Ofib
0.076
0.076
0.076
T.073
0.076
0.076
C.07&
0. 075
0.077
0.076
C. 076
0.077
0.076
li.078
0.079
0.080
0. 079
O.OP.2
0.0*1
0.082
0. 062
0. 0=1
C. C-83
' 0.034
O.CS4
0.082
0.083
0.083
C . 0 6 4
0.051
0.07 a
0.00 1.
0. 022
0.07v
0.077
22.8
22.7
22.7
22.2
21. S
21. «
21 .6
21 .'J
19.8
19.6
19.4
19.5
19.4
17.5
16. 6
16.8
17.2
16.8
i 7 . 0
17.0
16.7
17.2
17.3
17.2
17.3
17.1
17.3
17.5
17. B
17.4
18.5
18.4
18.5
IS.b
13.2
18 . £
IS . S
18.9
16.4
IS. 2
IS. 3
IS . 4
17. 3
17 . 3
l?.r-
18.1
17.4
17.0
* iviCX EMISSIONS
» rC METhOU
*
* Lb/MbTu LB/HR
*
*
*
*
*
*
A
*
ti-
ll
*
*
*
*
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*
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0.097
0.096
0. 096
0.09b
0.094
0.095
&.093
C . U 9 3
0. Ofi5
0.004
0.084
0.085
C.C85
C.092
C . U 9 1
1.092
C , u 9 2
C.090
U : D 9 0
O.OSS
c.oas
0.091
0.001
C.091
c.o?;?
0.091
G, J-V4
0.091
C . 0 9 >.-.
0 . C 5 5
0.098
C.,098
0.093
0. 09&
C . U 9 7
C . C 9 v
0. 100
0.100
0. 098
0. 099
U.099
0.099
0.097
0 . U 9 4
C.097
0.097
0.094
0.094
23.1
?2. 7
22.9
22.3
21.9
21.9
21.5
21.b
19.8
19.6
19.5
19.3
19.4
21.2
IS. 5
20.2
20.3
19.9
20. I
20.1
20.0
23.4
30.6
20.5
20.9
2 J. 5
2':. 7
20.9
21.3
21.0
22. 1
22.0
22. 0
22. 1
21.7
22.3
22.5
22. 4
22. 1
21.7
21.7
21.8
21.4
2 C . 9
21.4
21.5
20.7
20.6
* MOX EMISSIONS *
* OS METnOD *
* TRANS TRAV *
* Lo/HK LB/HR »
4
4
*
*
4
*
4
4
*
*
4
4
4
4
4
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23.0
2i!.6
22.6
23. P
22.7
22.5
21.4
ili:. 3
19.5
19.4
19.2
19.4
19. 2
1 9 .
-------
GCA/7 LCHN'OLOGY
D I V I S U :
CROUN ZELLtKBACK
DUCT LURUER I:\I_ET NOX DATA SUMMARY
A-
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22
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22
22
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22
22
22
23
23
23
23
23
23
23
?3
23
23
23
23
23
23
23
2 3
23
23
23
23
23
23
23
23
23
TIN?:
1630
1845
1500
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1530
19't5
20CO
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2145
2200
2215
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230G
2315
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2345
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30
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100
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130
145
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215
230
245
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315
330
245
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435
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MOX
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15
15
16
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16
16
15
15
15
15
15
15
15
15
15
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16
16
15
15
15
15
15
15
15
19
33
41
33
32
33
33
33
31
v 3
33
y T
33
33
29
16
16
15
15
IV OX
PPM
DRY
17
17
16
17
16
17
16
17
17
17
16
16
16
IS
IS
16
lb
IS
lb
17
17
17
16
17
IS
16
16
16
21
36
44
35
34
35
35
35
33
35
35
35
35
35
31
17
17
16
16
NOX
ISO
23
22
22
23
22
23
23
23
23
23
22
22
25
22
23
22
23
23
22
23
23
23
23
23
23
22
23
23
25
49
57
49
46
49
49
49
47
49
49
49
49
48
41
24
24
23
23
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A
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A
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A
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*
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A
A
A
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*
*
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A
A
A
A
*
A
*
KOX EMISSIONS
f- D K£THOD
LB/M3TU LB/HR
O.OBO
0.073
0.077
O.C78
0.076
0.078
0.078
0»C79
0.07-7
O.C73
0.077
C.C76
0.077
0077
. u / /
C.075
u 0 "* &
0.076
0 . C 7 6
0.076
0.076
0.07B
0.078
0.078
C.C77
0 . 0 7 b
0.077
0.076
0.076
0.07?
0.095
C. 164
0.152
0.166
0.163
U.165
0. 163
0.164
0.15H
0. Io4
0.166
0.364
0. 164
0.163
0.138
0. OS1
O.OSO
C.077
0.07 S
17.5
17.1
16.6
16.3
16.3
lo.9
17.3
17.6
IV. 6
17. 4
17.3
16.8
17.0
1 fj + S
17,1
16.6
la. 7
16.7
17.0
17.5
17.5
17.4
16.5
17.2
16.9
16.9
17.3
17.3
22.1
37.1
42.5
.36.6
36.0
36.6
36.2
3b.4
35.0
36.4
38 . 1
37.6
37.7
37.4
25.4
17.3
17. U
16.5
35.2
A
*
A
;
A
A
*
A
A
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A
A
A
A
A
A
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*
A
A
A
*
A-
*
A
A
NOX EMISSIONS
FC ME THOU
Lb/NJBTU LB/HR
0.095
O.D94
0.092
0.095
0*091
0.093
0.092
C . 0 9 *
0.094
0*092
O.C92
0.090
0.092
On p 1
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0 . 2 9 li
U . C ? ?.
0 . 0 !J U
0 . 0 S 3
0.050
0.090
0.092
0. 092
O.G°2
0.091
C.091
0.090
0.089
0.090
0.090
0.1 14
0.1 50
0.220
0.195
C. 191
0.194
0.193
0.192
0.187
0.193
6.154
0.194
0.193
0.192
0.161
0 . 0 9 ' j
C .094
0.092
U.09i
20.9
20.6
15.5
20.2
19.6
20.2
20.6
20.9
20.9
2 i! . c.
2U.6
15.?
20.3
10 a
1. s m 7
1 c,; . S
2 U.I
15.8
19.6
19.8
20. 0
20.5
20. 5
20.5
20.0
20.1
19. 9
19.7
20.4
20.4
25.5
43.0
4h.S
43.0
4,?. 2
42.5
4?. 7
42.5
41.5
42.8
44. fa
"4.5
44. 3
44.0
34.4
20.4
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lv.7
41.3
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A
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W
A
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' *
NOX EMISSIONS *
r,S METHOD *
TKANS TRAV *
LB/HR LB/HR *
20.6
20.3
19.5
20.4
19.2
20.4
20. 2
20.C.
20.6
20.1
lv.9
19.6
19.9
i c 7
J. 7 . /
19.2
20.2
19.5
19.S
19. 8
19.5
20.5
20.5
20.3
2C.1
20.4
20. U
19.8
20.1
19.6
25.2
44.1
53.6
43.0
41.4
42. 6
43.0
42.4
41.6
43. 6
43. 7
42. c.
42.5
42.6
37.6
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20.9
20.2
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COND
12
12
12
12
12
12
12
32
1 2
12
12
12
12
15
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12
12
12
12
12
12
12
12
12
12
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13
13
13
13
13
13
13
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13
13
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. REPfCSE.'JTS MISSING DATA
A-36
-------
CCA/TECHNOLOGY-
DIVISION
DUCT
CKOWN JCLLLRliACH
E'. IKLET '-ICX DiTA SUMMARY
*
*
* DiY
* 23
* 23
'* ? 2
* 23
, ?3
* 23
* 23
* 23
* 23
* 23
v 23
* 25
* 23
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- 23
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» 23
* 23
» 22
* 23
* 25
> 22
* 22
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* 22
23
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w 23
23
22
* 22
* 23
*> T
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* 22
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* ?2
. * 23
* 23
» 23
« 23
* 23
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-:'3
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*
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f,15 *
620 *
b'ib *
700 *
715 »
72 0 *
7*5 *
915 *
V ^i 0 *
1C30 -
1 3 ft '3 *
lino »
1 '-. 3 0 *
11 * lr. *
; 2 1- c- «
22;-: «
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12*5 »
]200 *
1 T- ! rj *
1330 »
1 3*5
j. ' .: 'J *
1*15 *
1*30 *
1 * * '3 »
1500 *
1 ? 1 ? *
1 1. 2 0 *
ifr*5 »
1700 *
1 M 5 *
173C *
1 7 * t «
ISO? *
2 f. "i :". *
. i - 3 n *
1 f : b *
ISCC *
1915
1S20 *
1 9 * i. *
2000 *
2013 *
< 0 2 v *
2 o * r *
'.OX
PPM
WET
33
38
37
35
36
3e
fi*
99
100
1C2
57
101
101
103
103
* fl p
IC-'t
1C*
1C'*
10*
103
103
10*
:.C3
105
1U5
105
102
41
i..-]
*0
40
40
39
39
32
36
J>6
3b
29
39
39
39
40
40
39
*n
MCX
r- f rf
ORY
36
42
11
39
40
39
39
107
107
109
1C4
103
109
110
110
i 'J9
i.'. 1
3 !i
11 '.
Ill
110
11G
1 11
112
112
113
112
109
45
44
44
4*
44
43
43
42
39
*0
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43
43
*5
*3
45
4*
*3
44
NOX
ISO
36
38
27
35
35
35
3 is
90
110
111
112
ICi 7
11?
109
3 0^
10=5
1C3
1 0 -',
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07
107
10?
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1U9
109
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105
42
41
40
42
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40
41
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3-)
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42
42
*3
42
*3
*2
42
42
* ixiCX FTKISSION-S
FO METHOD
* LR/KUTU I.R/HR
V
n
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*
*
*
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r
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P. 120
0 . 1 2 .->.
0.121
0.122
U.120
0.13*
0. 331
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0. 3i,?
0.37c
0.338
0.388
0.39b
C.39C
0 . 3 H i
0 . « ; n
c ., . .; c
C . ? 9 8
0. 3?9
0.. 29 C-.
C.396
O.*0 C
0 . t Q 2
f, , 4 C-- 5
0 . * 0 =
O.*05
0.3-58
0.156
0.155
0.152
C.lb2
0.15:
0.1*5
C ,1*F
0.1*6
0 . 1 3 fl
C . 1 3 v
0. 1-i*
C . 1 * 7
0.1*7
0. ' * y
0.147
0.153
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0.151
0.152
0.113
0.111
(1.115
0.131
0.179
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0.113
0.118
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0.132
0.137
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0.323
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0.116
0.137
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0.217
0.215
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0.118
0.139
0.139
0.110
0. 130
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0.150
0.101
0.108
0.113
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0.130
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0.213
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. REPPLSEWTS MISSING DATA
A-38
-------
GCA/TLCHNOLOGY
01 VJ SIGN
CKOWK Z
DUCT BURNER I\'LET fJOX DATA SUMMARY
*
*
*
DAY
* 24
* 24
* 24
* 24
* 24
* 24
* 24
» 24
24
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* 24
* 24
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55
55
56
55
55
53
55
56
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54
52
54
53
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62
63
60
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60
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58
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56
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57 *
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55 *
57
57
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48 -
51 *
50 -
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52 *
NOX EMISSIONS *
KO METHOD *
*
LE/MoTU LB/hR »
0.21 r<
0 . ? 2 1
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0*205
0.214
0.210
0.209
0.203
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0.210
0. 21 0
0.211
0.207
0.213.
0.205
0.176-
0.191
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93.8 «
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MOX EMISSIONS *
FC METHOD *
ft
LS/KiiTU LB/HR *
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0.21^
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0.213
0.209
0.206
0.202
0.207
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C.207
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0. 197
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Lb/HR LE/rlR * COfJD *
91 .2
91.3
86. 0
86 . C
67. b
83.7
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. REPRESENTS HISSING DATA
A-39
-------
:GCA/TECHNOLOGY
OIVISI.CM
CROWN I'ELLEh'QACH
DUCT tiURMER OUTLET NOX DATA SUMMARY
*******»******,************************ * * ********* ******** * A *****.*** i* * * * * * * £ * * A***
A
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37
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42
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42
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44
46
46
46
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45
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47
46
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45
45
45
45
44
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45
43
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64
47
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* NOX FMISSIONS
* F'D METHOD
*
« LB/MBTU LB/HR
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0.139
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0 . 1 i1 5
C. 132
0.12 'j
0.13b
0.143
C.143
0.14?
0 . 1 4 K
0.148
0.147
C. 146
0.144
0.149
0.152
0. 152
0.147
0.147
0.147
0.148
0.147
0 . J 4
54.1
56.3
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57.5
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55.3
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55.8
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51.8
52.1
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60.5
60.0
59.7
59.8
£3.5
102
71.5
71.3
* NOX EMISSIONS
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* LB/HR LB/HR
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*
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*
*
*
*
*
*
*
*
*
*
*
1*
*
*
*
*
*
*
*
*
it
*
*
*
*
i-
*
*
*
*
*
*
*
*
A
*
64.4
ia. 1
54.8
56.1
57.3
53.8
50.6
46.3
46. i;
44. C
4 /. 4
46.7
33. 1
34.0
36.0
33.8
25.1
26. fJ
25.5
4 8 . 0
4o . 1
51.6
D'i.9
60. 0
6u>. 9
58.9
65.7
64. 1
70.2
6C. fi
Co. C
51. . 2
47.7
49.6
54.6
D 4 . 3
70.2
68.7
bb. 2
60.3
64. 6
66.2
67.1
67.6
68. 3
115
97.7
91.5
25
25
25
25
2'j
5:5
2-')
25
25
25
27
25
26
24
26
24
27
27
.
.4
.6
.9
H
.3
. 2
. I
.1
.4
.3
.1
. 3
j
. o
.7
. 'J
.8
.2
.5
.
.
.
.
.
.
.
.
.
.
.
.
.
w
.
.
.
*
.
.
»
*
.
*
.
.
-
*
*
* TEST
* CO NO
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
A
*
*
*
»
«
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
.
8
a
8
p
e
g
?.
o
8
8
8
ft
P.
8
8
8
9
3
9
9
9
3
9
9
9
q
9
9
9
9
9
9
9
9
9
9
9
9
9
Q
9
9
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
it
*
*
*
*
*
*
*
#
*
*
*
*
*
*
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*
*
*
*
*
«
*
*
*
*
*
*
*
*
*
*
*
. r.EPMSiCWTS KISSING DATA
A-40
-------
GCA/TtCHNOI.OGY
DIVlbK'J
*
W
*
*
+
*
*
*
*
*
*
ft
*
*
*
*
*
ik
*
*
A
*
*
*
M
*
*
*
*
*
*
*
*
*
V
*
*
«
*
*
*
*
«
*
*
*
*
*
*
»
*
OH Y
16
Ik
16
16
16
16
16
16
16
16
16
Ifc
16
16
16
16
16
16
3.6
16
16
16.
16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
It,
16
16
16
16
iC
1 6
DUCT
CZ
* r.cx NOX NOX
* PPM PPM PF'H
TIHt » WET w£T DRY
700
715
730
715
300
ais
i 30
bl3
'3 CO
915
S3f
11C3
1100
1115
1130
,1 115
li!CC
1215
12 3D
1210
1JCO
131-5
1330
1 3 1 0
1315
no;
3 lib
1130
1115
1500
1515
1530
Iblb
16CC
16 It-
.1*30
1M5
17CO
1715
1720
1715
1800
If IS
1830
If 15
l'-00
1"-1 r1
1^-3-
*
*
*
+
*
*
*
*
*
*
*
*
*
*
*
*
*
*
A
*
*
*
*
*
*
*
*
*
*
*
+
*
*
k
*
*
*
*
*
*
*
»
*
*
*
*
*
ii
11
10
10
1C
10
39
36
.18
38
38
3?
37
37
3?,
39
33
10
3'1
3o
57
37
37
37
37
37
37
28
31
3S
28
28
31
32
37
39
38
36
39
39
A 5
37
37
38
38
37
37
35
37
m
.
.
.
.
.
.
.
.
.
.
31
.
33
.
.
35
35
33
27
36
37
38
31
3*
38
36
11
37
38
3E
35
35
36
35
31
37
.
3S
36
f-
35
37
37
38
38
38
37
16
15
15
15
15
11
10
13
13
13
13
11
11
12
13
13
15
5r»
39
11
11
11
11
11
11
11
31
3"5
12
12
31
38
35
11
13
12
1C
11
13
39
11
11
12
12
11
12
1C
11
CrOUN ZEL
tURfiES OUT LE T
* NOX Ef-ilSSIONS
* f-0 KETHJO
*
* LB/MBTU LLVHR
*
*
*
*
*
*
*
*
*
»
*
*
*
*
*
*
*
*
*
*
*
»
»
»
»
*
-
*
*
*
»
W
*
*
*
*
*
*
»
w
*
*
*
*
*
*
*
*
0.128
0.126
0.125
0.121
0.121
0.122
0.112
0.115
C . 1 1 8
C . 1 .? 0
0.120
0.112
0.112
C i 1 o
0.115
0 . 1 1 6
0.118
0.112
0.11 o
0.117
0.117
0.118
0.119
C . 1 1 ft
0 . 1 1 '>
0.118
0.109
0. 1CJ
0.122
0.122
0.392
0.111
0 . 1 1! 6
t . 11 f.
0 .i2i
0.122
0. 115
0.126
0. 123
0.110
c.na
0. 11 o
0. 120
0.120
o . 1 1 a
0.11 5
0.113
0.118
1)7 .2
bo.1
6b.O
(-,5 . 1
t5.9
6D.3
09.8
62.4
60 .6
61 .3
61.1
ol .2
C2.3
61 . 1
!.:.?. 6
tO . 7
b2.'l
r,r; q
5b . 3
??, . 7
5;;. 6
03.7
59.3
5tJ.5
'J9.2
5H.S
01 .1
ba«1
60 .6
60 .2
15.6
51 .9
b?.6
58.7
61 .1
60 .5
jb.5
b3.2
ol.7
5'J . 3
59.2
59.0
60.1
60.3
59.2
!i? .;
06.6
59.?
.LL'RtfCh
M3 X D A 1 A
SUMMARY
* .MCX EMISSIONS
* FC METHOD
*
* LB/MBTU LB/HR
*
*
A
*
*
*
*
*
*
*
*
*
*
f
*
*
*
*
*
*
*
*
*
*
*
*
*
*
1e
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*.
*
0.137
0.135
0.134
0.133
f: . i 3 3
0.131
C.121
C.I 28
0.127
0.128
C. 129
j . 1 .? 1
0.121
0. 126
0 . 1 2 U
0.121
0. j 26
U. 127
0.123
0.129
0.125
0.129
0.13C
0.129
O.loO
0.130
u > 1 31
C.120
0. 133
0.133
0.101
0.122
(J.119
0.12-7
0.1 31
0.133
0.125
U.I 33
0.135
0.121
0.1 30
0.129
0.131
0.131
0.129
0.130
0.123
1.12 }
72. 0
71.2
70.7
70.0
70.7
70. 0
61.3
6ft. 0
65.1
bj.R
b'j. 1
69.1
67.0
6b. 1
67.1
t.5. a
66. S
63. 4
61.6
61.3
61.1
6't.l
61.9
61.6
c.1.9
c.1. 6
65.2
59.9
66.2
65.9
51.5
60. 5
59.1
61.0
fc6. 5
66.1
62.0
69.1
67.7
&U. 7
t5. n
C.1. 7
66. G
6r>. 9
61.7
o5. 3
62. C
bl.S
* NOX EMI
* GS ME
* THAWS
* Lb/HR
.
*
*
*
*
*
*
*
*
*
*
*
A
*
*
*
*
*
*
Ik
*
*
*
*
*
*
W
*
»
*
*
4
*
*
ft
*
«
*
*
*
*
*
*
>
*
*
«
*
P-3.6
S3. 0
79. c'.
76.7
75., 7
72.3
66 . c
65 . (>
65.3
73.1
70. t
o 5.6
t>5. 6
67.1
68.0
68.9
7G . 7
? 5 . 5
57.2
5S.6
58.1
61.6
66. 6
68. 0
68. 8
68. i;
18.7
59.3
65. 3
65.8
16.3
55.6
52.2
60 . is
63. 5
63.6
60.6
61.0
63.0
1)7. 3
55. o
5S. 5
51.2
51.0
56.5
62.1
57. b
60.8
SCIONS *
mco *
TRAV * TEST
L3/HR * COiMO
. *
*
4 *
*
. *
. *
*
. *
. *
. 4
4. *
.. *
, *
*
* *
*
*
0 *
. *
t, *
*
*
. *
0 *
« *
*
*
*
. *
*
. *
*
* *
. *
. *
*
75. 4 *
82.8 *
31.2 *
72.6 *
77.7 *
77.3 *
79.0 *
78. * *
77.5 *
78.2 *
74.1 *
77.4 *
«
3
3
3
3
3
3
3
3
*
a
i
i
.
.
.
.
.
.
.
.
.
»
.
.
.
.
.
.
.
.
.
.
.
.
.
3
3
3
3
3
3
2
3
3
3
3
3
*
*
*
V
*
*
it
*
*
*
*
*
*
*
*
*
4
*
-*
*
*
A
*
*
w
*
»
*
*
*
*
*
*
*
*
*
*
*
*
*
*
ft
it
*
*
*
*
*
*
*
*
. REPRESENTS MISSING DATA
A-41
-------
GCA/T LCHNGLOGY
D I VI SI ON
CROU'N 2ELLERO-ACH
DUCT tURNER OUTLET NO X DATA SUMMARY
*
*
*
*
*
*
*
4
*
*
*
*
*
*
*
*
*
*
*
*
*
V
*
*
it
*
*
*
*
A
4
*
*
*
*
A
*
*
*
rf
*
*
*
k
*
*
*
*
*
«
*
DAY
16
16
IS
Ib
16
16
16
16
16
ID
16
16
16
16
16
17
17
17
17
17
1?
J. (
17
17
17
17
:. 7
:7
17
17
17
37
r/
17
17
17
17
17
17
17
17
17
17
17
17
17
17
17
,«
1945
200C
2315
2030
2115
2130
2145
2200
2 PI 5
s;.1 -so
2 24 5
2300
2315
2330
234b
0
15
30
. 45
IOC
115
130
i4b
200
;215
230
T4'J
300
315
330
345
^00
415
4 3 C
445
5 CD
lilt
530
5 4 b
6 no
C- 1 ';.
630
6 4 C-
/ r. o
V15
730
74 b
SCO
*
*
*
*
*
+
*
*
*
*
*
*
*
it
*
*
*
*
*
*
*
it
*
*
«
*
*
*
vr
*
*
*
*
*
*
*
*
*
*
*
*
lit
*
*
*
*
*
*
*
*
w
CZ
MOX MiX
PK-: H'M
wET V.ET
37 36
37 36
37 38
37 36
39
37
40 .
40
40
40 .
40 .
29 .
20 .
23
20
20
19
20
20
19 .
31
33
27 .
2 o .
25
25
24
£4 .
19
24
24
23
23 .
23
23
23
23
22
26 .
26
38
3,V
36
37
37
36
37
38
i';OX
PPM
DRY
42
42
41
42
44
41
45
45
45
45
45
32
22
2.2
22
22
21
22
22
21
34
36
30
31
28
27
2b
26
21
26
26
26
25
25
26
26
25
25
29
31
4?
42
42
42
41
41
42
42
4
*
is
*
*
ir
*
*
*
W
*
*
*
~
*
*
*
*
«
fi
*
*
*
*
*
*
*
*
*
tt
*
*
*
*
*
«
*
»
*
*
*
*
*
*
*
*
*
*
*
*
*
NOX F.H1SSIONS
KD KETH'-U
Lb/NBTU LB/HR
0.119
0.119
0.117
C.119
Q.116
0.107
0.117
C.117
0.117
0.117
C- . 1 1 5
C. Otl
C . C 6 7
0.065
0.065
1' . 0 b 4
0 . C 6 3
O.Ct-4
0 . C 6, 4
Ci . 0 6 J
C . 0 d 3
C.103
0 . 0 P. 3
0 . C t P.
o . c 7 ;
0.078
0. 076
C.076
G . 0 (-. C
C . 0 7 5
0.075
0.074
0.073
C.073
0. 074
0.074
0.07 3
0.072
0 . 0 S 1
0.097
C.113
0.114
0.113
a. 112
0. 11 1
0.110
0.112
0.114
59.9
60.2
59.1
59.5
64.9
59.9
fab .0
59.3
59 . 0
6?. 3
=P.3
.? 2 . £
24 .3
23 . 6
23.7
23.1
22.5
23.1
?2 .ft
26.9
3q .5
43.7
35.2
33.3
3-J . 1
29.7
2£.7
29.C
23.0
2B.6
28.7
23.3
2%. C:
27.8
if. .3
29.1
2h.9
2B.3
31.9
4a .0
60 .1
bO .3
59.9
fj'J .0
60.2
?9 . 6
60 .4
61 .P
ir
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
»
*
*
*
.
*
*
A
*
*
*
*
*
*
*
*
*
*
*
It
ir
k
*
*
*
*
*
*
*
i-j 0 X C M 1 5
i- r n c i
Lb/MBTU
0.130
0.130
0.127
0.129
0.125
0.116
0.127
0.127
0.126
0.127
C.125
(J.104
U . 0 7 5
0.073
0.073
0.072
0.070
0.072
0.071
0.0 12
c.ioa
0.113
0.091
0.097
a . o e s
o . c e 7
C.C81
O.CB4
0.067
0.083
C.CSo
0.062
C.081
O.OtlQ
0.0fc2
O.OfcJ
C.OS1
0.079
U . 0 R 8
U . 0 9 5
C.l?2
0.123
0.122
0.122
0.121
0.120
C . 1 2 1
0.124
LS/HR
65.3
65.6
64.3
65.2
70.5
c-5.2
71.6
64.3
fc.3.8
64. 1
63.2
37.9
27.3
26.5
26.6
25.8
25.1
25.3
25.5
30.7
42.8
48.3
3i.6
36.8
33.3
22.8
31. S
32.0
2h.4
31.7
31.7
31.2
30.9
30.7
31.2
32.1
31.9
31.3
34.9
5U.4
t>4.9
b5. 3
t>4. 9
65. 9
b5.3
b4. 9
65.6
67. 3
* IkOX EMISSIONS *
* OS HLTHOD *
* TKA.MS TRAV * TLST
* LB/HR LB/Hrt * COND
*
*
*
*
*
*
1h
*
*
*
W
*
*
*
*
*
*
A
*
*
*
*
*
*
*
*
*
*
A
*
*
*
*
X
*
*
ik
*
*
*
i.
*
*
*
*
*
*
*
59.7
56.6
57 .0
57.9
62.6
5a.8
61.7
62. 0
61 .5
62. 6
61.3
37.6
23.3
21.5
20.4
19.5
1C. 1
18. 3
IB. 4
U. 2
32. ?.
36.4
25.6
25.3
21.5
22.6
21.5
18.3
12.6
lb.4
C.8
10.3
17.9
20. C
2G. b
2 C . 2. '
19.7
19. 0
26. 2
27. L-
44.fi
5o. 7
5S. 9
40.4
42.3
46.2
£4.9
69. 1
78.2 *
78.3 »
76.8 *
78.0 *
*
. *
» *
*
*
* *
*
*
*
*
*
*
* *
. *
*
*
*
*
*
*
*
* *
* *
» *
*
0 *
*
*
. *
*
*
* *
*
*
*
* *
* *
» *
*
*
*
. *
*
*
3
3
3
3
2
2
2
2
.
.
.
1
1
I
1
.
.
*
.
.
.
.
.
1
1
1
1
1
1
1
1
1
1
1
1
.
.
.
.
.
e
.
.
3
3
3
3
*
A
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
K
*
*
*
*
*
A
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
MISSING DATA
A-42
-------
GCA/ TECHMC-LOC-Y
DIVtSIo'i .nuCT
*
*
*
*
*
*
*
*
*
'
ft
*
*
*
*
*
ft
*
*.
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
.*
> *
*
*
*
ft
*
*
ft
A
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DAY
17
17
17
17
17
17
17
17
17
17
17
17
17
17
17
17
17
17
17
17
17
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17
17
17
17
17
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17
17
17
17
17
17
17
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17
17
17
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17
17
17
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100C
1015
1030
1045
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1115
1130
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12.15
1230
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1345
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1430
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105 102
108 109
100 111
107 107
1C5 84
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77
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56 86
67
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116
115
114
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LB/XBTU
I' . 1 1 8
0.134
0.133
0.173
0.353
0.346
0.345
C. 253
0.3? 9
0.35 1
0.347
0.207
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0.135
0.134
C.132
C . 1 4 Z
0.272
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0.277
0.281
0.257
C.263
0. 244
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0.282
0.286
0.300
0.316
0 . 322
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C.112
0.112
0.112
0.113
0.115
0.114
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0.082
0.030
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U.107
0.10 6
0.065
0.039
LP/nR
61 .0
67. C
66.4
85.4
175
169
165
173
161
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155
94.2
55.2
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61.4
60.6
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123
120
124
125
114
117
109
121
126
125
127
133
141
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52.2
52.4
49.6
49.9
53.8
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36.4
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0.146
0.143
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0.376
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0.226
0.142
0.151
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0.147
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0.302
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0.305
0.313
0.350
0.300
C.2°l
0.307
C.316
C.314
0.318
U.336
U.352
0.361
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0.125
0.125
0.125
C.128
C.127
C.125
0.091
0.101
0.091
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0.118
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LB/HR
67.2
72.8
71.4
92.4
190
184
183
137
175
173
174
104
65.3
69.2
68.2
67.4
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134
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156
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58.3
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SUMMARY
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TIME
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100
130
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200
215
230
2*5
300
315
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315
400
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630
615
700
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31
31
33
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27
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32
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23
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26
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27
34
31
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31
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33
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0.037
0.051
0.032
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0.095
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0.11 1
0.115
0.113
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£.113
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0.142
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L .-./' .'i o T u LB/HR
P. 122
0.126
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0.122
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0.126
C.126
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C.093
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J 1 0 J
0 . 0 9 'j
U . C 5 5
0.095
0.096
0.098
67.o
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6«. 7
67.8
68.5
69. 8
69.9
bH.B
93.3
tilt.l
b7.2
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34.9
34.7
34.2
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32.8
35.4
34.2
35.2
38. 5
5H. a.
37. 1
3-5.5
35.5
37.4
3S.1
* 'OS MLTnCO
* TRi,\S TR6V
» 65.5 79.2
* bci.C 31.7
* 59.4 60.5
* 48.8 79.3
* 43. h 80.2
* 43.4 81.7
* 46.9 S 1 . 9
* 6 3 . F. 60.7
* 82>G
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TEST
2
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MISSINS DATA
A-45
-------
c
*
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G I VI SJC-1
DAY
19
19
19
19
19
\h
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19
19
19
19
19
19
15
13
15
19
19
19
19
19
19
i ^
19
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19
19
19
19
1?
15
19
19
19
19
* l-J
15
\ ?
19
15
19
19
15
19
* 9
19
19
19
TlfE
330
345
400
415
430
44b
500
515
530
545
600
6 It
. 630
6 4 5
720
71 5
730
745
e.no
815
1R15
: :i 3 o
1045
1 ifi'G
111-J
1130
114D
1 ? C 0
1211
lisa
12-', 5
13-5C
1345
1 4 C C
1 '"* J J
3. & 4 5
1500
i 5 } -
i -; 3 c
1 54b
1600
1 6 1 ^
163S
is: 6
it 30
1245
t 9 S 0
1515
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PPh PPM
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27
25
19
25
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26
43
43
M
40
40
40
41
41
4i
c:3
C ',-
6 c
5 v
5ft
57
~. 3
36
59
59
b C
60
60
61
60
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56
59
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55'
43
44
44
44
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.
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5S
56
53
61
59
60
62
64
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64
61
64
61
65
64
62
62
6?
61
65
65
.
»
^
.
.
o;
NOX
FPM
DRY
30
28
21
28
2?
2fi
an
2t
25
29
29
4P
49
46
45
45
46
46
47
46
69
71
6 ?
o5
64
6?
64
64
65
6'i
bo
66
66
67
66
£4
65
b5
64
64
65
65
b5
4S
49
49
50
49
;CT
*
*
w
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vr
*
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ft
*
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*
-V
*
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»
*
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C.:'(
o!JRME3
Vvrj 7T4
UJTLEl
NOX EMISSIONS
hD METHOD
LB/M3TU
0.086
0.082
0.062
O.OS1
C. 081
O.Ofcl
C . 0 S 1
C.061
0.0?!
0.081
0. 082
0.125
0.125
C.llv
rJ . 1 1 6
0.116
ti. 11?
0.119
0.120
0.123
0.202
0. 21 C
C . 2 0 4
0.193
U . 1 f-. t>
0.186
o . i .« e
G . 1 f. 1
0 . 1 -j 1
o, : = i
o . r? o
0.193
0. !93
0 .195
0 . 1 v 0
0 . 1 9 r-
0.193
rj .101
0. 13 ;
0.184
0 . 1 fe 5
0.192
c . i : o
n. 141
0.135
0 . i 3 4
0.135
0.13U
LE/hR
33.4
31.7
23.7
30 .9
31.2
31 .2
3'i.Q
33.6
33.9
33.7
34.2
53 .7
70.2
60 . 3
' t ;-..?
65.9
67.3
68.0
t.5.4
67.0
99 .5
1 03
101
55 . 2
93.2
52.4
92.7
92. B
S3. 9
93.8
96.2
94.7
55.0
57.0
93 . 0
v? . i
93. 'J
Co . 1
ri ';, .
'.- 2 > ft
1<2 .3
9J..7
5 '5 . n
74.5
71.1
7u»3
71.9
71.8
.L^SB-iCh
I NOX DATA
*
*
*
*
*
*
»
*
*
*
*
*
*
*
*
*
*
*
*
*
*
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*
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*
*
*
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*
*
*
*
*
*
A
*
*
it
*
*
*
it
*
*
*
*
*
*
*
*
*
SUMMARY
iJOX EMISSIONS
FC METHOD
LTi/MiiTU
0.097
.0.052
0,069
0.091
G . 0 9 2
0.092
0 . u 9 <)
a .0 94
G.094
0.094
0.095
0.146
0.141
0.13-1
0.131
U.I 31
0.134
0.135
0. 136
0.141
0.219
0.227
0.221
C . 2 0 8
U . 2 0 4
0.201
0. 204
0.205
0,207
1.2C7
C : . 2 1 2
C.210
0.211
0.213
0.206
C.208
0.211
C . £ G 5
C.207
0.200
0.201
J.209
o . 2 o a
0. 154
0.145
0.144
0.144
0.144
L&/-1R
37.5
35.6
26.6
34.7
35.2
36.4
i"3. 1
39.1
39.4
39.2
39.7
6U.9
79.1
74. 5
74.5
74.7
7o.3
77.1
74. 0
76.3
103
112
109
103
liil
100
101
101
1C2
102
10 b
103
104
106
101
101
103
102
105
103
100
104
104
fcO.j
76. 2
7b. 0
76.8
76.9
*
*
*
NOX EMISSIONS
GS METhOD
TRANS TRAV
* LB/HR
*
*
*
*
*
*
*
*
*
*
*
*
*-
*
*
K
*
*
*
*
ir
ft
*
*
*
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A
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it
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.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
102
102
6 ;i . 1
87.0
89. 7
o9. 5
91.4
39. 1
b"J,b
63. 1
V<^ u
95.9
>7. t:
95.4
9f . 1
3 V. . O
: a . 4
V 'J . Li
^3.1
1 2 . 3
95.5
97.2
9i. 5
71.6
71.7
71.4
72.0
71.8
L3/HR
.
.
.
.
.
.
.
*
.
.
.
.
*
.
.
.
a
.
.
1 18
1 1- 2
110
112
109
103
11U
110
111
1 1 1
114
113
114
i 15
1 13
11 1
i I 2
ill
: 10
110
111
113
112
.
.
.
*
*
*
*
*
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*
*
A
it
*
*
*
*
A
*
*
*
*
A
*
*
*
*
*
*
*
TEST
CO 1^0
12
12
12
12
12
12
12
12
12
12
12
.
.
.
.
2
2
2
2
.
b
5
5
5
5
5
5
5
5
5
5
5
5
5
5
5
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5
5
5
5
5
5
»
.
.
*
*
*
*
*
*
*
*
*
*
*
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*
*
A
*
*
*
*
*
*
*
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*
*
w
k
*
*
*
TT
»
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),
*
*
*
*
*
*
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KISSING UATA
A-46
-------
GCA/TLCHNULOGY
0 I V I S I :JN
CrtOWN ZELLuKi.vACll
DUCT bUkr,L"3 OUTLET wax DATA SUVMARY
A
A
*
A
*
*
A
*
*
*
A
w
A
*
A
*
*
A
A
*
*
A
a
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A
A
A
*
*
*
*
*
*
*
*
*
*
*
*
*
*
.
*
*
*
.*
i*
,
*
DAY
19
19
19
19
15
19
19
19
19
19
19
19
19
19
19
19
19
19
20
20
CO
20
?0
20
O P.
cv
20
'* f»
f. \J
2Q
5 *!
2 '.'
20
20
20
2C1
20
£0
20
20
20
20
?.1
20
20
2C
20
20
20
CO
20
TINT.
1930
1545
2003
2015
2 J 3 0
2045
2103
? 1 1 0
2130
2145
2200
221 f
2230
2245
2200
2315
233P
2245
0
1 :.
30
4 t
IOC
lla
1 % n.
1 o> U
145
2n rv
V I'
215
*? X n
2 « u
240
300
315
335
345
400
415
430
445
50 C
515
Son
345
e.oo
615
630
645
700
715
*
*
A
A
A
A
w
*
»
*
Hf
*
A
A
A
*
*
A
A
*
A
.
+
A
.*
A
V
*
A
A
A
*
*>
A
A
«
A
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*
A
ft
A
+
*
A
A
A
*
*
CZ
f.ox r;ux NOX
r-Tfi PPM PPM
VET '.ET OKY
44
43
43
42
41
41
41
41
42
42
42
43
44
44
23
20
19
19
IV
IS1
15
l r.
IS
13
1 ft
1 O
13
t C.
i C
16
14
33
5G
41
45
47
23
17
17
17
15
If.
16
17
36
42
41
41
4B
49
48
49
47
46
. 47
45
46
. 47
47
. 47
. 4o
49
49
. 25
. 22
21
21
. 21
20
21
£0
. 20
. 20
1C
7
19
U>
%
3 ~
If
O
15
36
. 55
. 44
51
51
. 25
. 18
. 15
lo
. 17
18
18
. 19
40
47
46
. 46
. 44
* NOX EMISSIONS
* FD METHOD
A
LB/MCTU LB/HR
A
A
A
*
*
A
A
*
A
A
*
*
A
A
A
A
*
A
A
A
A
K
*
*
A
*
IT
*
*
*
*
*
*
*
«
*
*
*
*
*
*
»
*
*
*
C.134
0.136
0.133
0.12b
C. 126
0.126
U.125
0.126
H . 1 2 H
0.12?
0.129
0.130
0.133
C.13b
0. 079
0.071
0.068
0.066
G.C66
0.065
u . C .- 6
O.CitS
'C . 0 C- 4
0.063
Oft (L 1
U D 1
0.062
On C 7
U -j
C . C :. 7
r 1 c; t
U J t> 1
0.050
p . 11 a
C . 1 7 *
0 . 1 <* 2
0.1*1
C' . 1 1 2
O.uSl
0.05?
0.059
0. 059
0 . C 5 5
0.057
0.057
0.06G
0.120
0.. 132
0. 132
0.127
71.3
72.4
t'U . 5
77 .6
76.2
76.6
64 . 5
o4.7
66 .0
6b.3
58.4
52.9
60.4
f.l .4
26 . 9
2't.2
23.0
22.5
:'2 .3
23.1
23 .'!
23 .2
22.2
21.9
"1 L
(. ± » "1
21.4
15.2
1 "7 "
L i * J
43.1
65.fi
52.2
59.0
54 . f.
27.3
15.8
20 .0
20.6
39.3
20.0
19. fc
30.8
61 .4
67.5
67.8
69.2
0.123 67.3
* MC.\ EMISSIONS
* . r"C METHOD
*
* Lu/MBTU LB/HS
A
A
A-
*
A
*
A
A
*
A
A
A
A
A
A
*
*
A
A
*
A
*
A-
*
i-
w
A
A
A
A-
*
A-
*
*
w
w
i
.
*
*
*
*
*
*
0. 143
0. 14S
0.141
C.137
0.134
0.135
Li. 133
0.134
0.136
0.1 37
0.1J6
0.138
0.141
0.144
0.088
0.079
0.075
0.073
0.072
O.U71
0.070
& . :; 7 2
(i . C 7 0
0 . C 6 9
0 0 r- O
W . J C- f }
0 S i) 6 <)
U . 0 o j
Or '^ 7
0 W ; -' 1
(J.liO
O.lSo
C.156
C.I 76
0.177
L . C 3 9
C . t 6 5
0.065
O.ObS
n.Ofai
0.062
0 .062
C' » 0 6 b
0.128
0.139
0.141
0.134
* u. 130
*********
7n. 4
7S. 7
c5. 3
83. U
61.4
82.0
63.7
69. 1
70.2
70.4
61.9
62.4
64.0
65.3
29.5
26.7
25.4
24.9
24.5
25.4
25. S
2 5 -.
24.5
24.1
O T A
d O M O
23.7
21.3
1 ,*} /;
i J * S
IP. 7
47.6
7.2. 7
57.3
b4.6
55. v
30.0
21.8
22. C
22.7
21.4
21. -3
21.7
33. 7
65.5
71.4
72.3
73. 1
71.1
*******
* l\,CX EMISSIONS
* GS'KETriOD
* T ,; A K S T R A V
* LLi/HR L3/HR
*
A
A
A
A
*
A
A
A
A
A
*
A
A-
*
A-
*
A
A-
A
*
A
*
*
*
*-
*
*
*
*
v
A
*
*
*
*
tt
*
*
*
*
*
*
*
***
72.6
70.6
70.4
6R.1
66. 5
66.7 .
66.5 .
66. 2
f>7. 2
6<5. 0 .
68.0
68. 6
7C.3
67.2 . .
34.6
27. u .
25.0
24. 8
.53.9
23.9
^4. 0
23.5
23.1
22.7
22.2
20 . 7
.1 ,3.1
42.6
65.9 .
52.? .
59.9
tl. 1
30.4
22.1
22. 0
21.6 .
1 9 . 7
21» 1
21.3
22.7
54.;: .
o&. 1 .
66.3
65.7
64.5
*************
*
A
*
*
A
*
A
*
*
*
*
A
*
*
A
A
*
*
*
*
A
*
A
*
*
*
V
A
*
A
A
*
*
*
*
*
*
*
A
*
*,
*
*
A
*
*
*
**
W
*
TLST *
COND *
^
.
.
2
2
2
2
2
2
2
2
.
.
.
.
12
12
12
12
12
12
12
1 2
IZ
12
1 9
.1 c.
13
3.3
13
12
12
12
12
12
12
12
12
12
12
12
12
.
»
.
.
2
A* A A
*
*
*
*
*
A
*
*
*
*
*
*
*
*
*
*'
*
A
A
A
A
*
*
*
*
w
*
*
*
*
*
*
*
*
*
*
*
*
A-
*
*
*
*
*
*
* * *
. REPfcESEMS HISSING DATA
A-47
-------
C-CA/7 LCrfK'CLOGY
CIVISION
DUCT bUKMt1!
i,!N ZLLLE.RLACH
OUTLET ttOX 3ATA SIHKARY
A
4
A
A
A
A
A
A
A
i
A
vlr
A
*
A
*
*
A
*
*
A
*
rt
A
*
A
A
A
A
*
a-
»
it-
*
A
A
*-
*
*
4
»
A
4
*
A
*
A
^
A
A
A
DAY
20
20
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20
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20
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*
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TIME *
730 *
745 *
300 *
815 *
1000 *
1015 *
1C30 *
1045 *
1100 *
1115 *
1130 *
1145 *
1200 -
1215 *
l;?3C «
1 2 4 a -
1303 *
1 3 ' 5 v
1 3 o f »
1 ,' 4 1 *
1 4 J o ' *
1415 »
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1 '1 4 5 -
1500 »
1515 *
1 r,5 30 *
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1 '- H 2 *
1615 *
1630 *
1 645 *
1700 *
1715 -
1730 -
1 ?;;ii *
1 f. C C *
1£'15 «
1*30 *
1 i 4 f. *
1 V C 0 *
: 9 1 5 *
1 c; 3 P *
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20flO *
2015 *
2030 *
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r;ox
FPM
40
39
38
31
i ni-
gs
98
95
98
96
97
98
97
56
97
97
97
96
96
97
-"39
96
96
y7
97
9b
96
94
c;7
62
103
104
100
52
35
33
32
32
32
32
32
32
32
32
32
32
32
31
CZ
NOX
PPM
WET
.
.
.
.
108
.
110
1C7
108
110
109
103
111
.109
110
103
111
113
109
112
103
1C3
lOv
111
109
113
112
1C8
110
113
105
109
109
.
.
.
.
.
.
.
m
.
.
.
.
.
.
IMOX
PPM
CKY
45
44
43
34
110
108
106
103
106
104
105
106
105
101
105
105
1 05
104
1C1
1 05
106
10".
1 C4
1 05
105
1C3
104
1C2
105
6 o
112
112
ioa
57
38
it.
36
36
36
36
36
36
36
36
36
36
36
35
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A
A
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A
A
A
A
jr
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A
A
A
A
A
»
«
A
A
*
NOX. EMISSIONS
FC METHOD
LF/MOTU LB/riR
0. 121
0.122
0.120
0.095
0.330
0.322
0.31 S
0.31 0
0.31 7
0.312
0.315
0.316
0.31 5
' 0.312
.0.313
0.31 2
0.314
0.310
0.31 1
0.31 3
0.3:6
0.31 1
1.5 u 'J
0.312
C.513
0.307
C.310
0 . 3 0 5
0.31 1
U.2S7
C.333
0. 333
0.323
o . : 6 n
0.104
0.101
l;. 105
0.105
0.106
0. 10 0
C . C 9 5
0 .097
0.093
U . 1 0 C
0.092
0.0^2
0 . 0 9 t
0. 096
67.5
66.8
65.3
52 .0
166
162
160
156
160
155
157
157
157
155
1 5o
1 55
155
152
153
154
155
1 52
151
153
153
1 49
151
148
151
1 31
167
167
Ibb
r.?. . s
53.3
t: .7
t't.3
J4.5
55. n
51 .7
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53.5
51 .3
55.4
50.1
50.2
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52.4
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*
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*
*
*
*
NOX EHISSIOMS
HC METHOD
Lu/MBTU LB/HR
0. 130
0.129
0.126
0.101
0.353
C.345
0.340
0.331
0.339
0.334
0.338
0.339
0.338
0 . 3 3 5
0. 336
0.336
0 .338
0.333
C . 3 3 b
0.338
C . 3 4 C
J.334
C.333
U.33b
U 3 3 8
0.331
C . 3 3 r.
0. 329
0.336
C.292
0 . 3 a 0
0.360
0.349
0.170
0.111
0.10-
0. 113
J.I 11
0.116
0.106
0 . 1 0 2
C . 1 0 2
C . 0 ~j '>
0. 107
0.097
0.097
U..1G4
Li. 102
71.3
70.5
68. 3
51.9
17 fc
174
171
1A7
171
166
168
168
168
16 fc
167
157
16 =
It, 4
165
15:')
1 LJ 6
iol
163
165
.\D 4
161
1S3
ISO
164
146
130
100
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66. b
5b. 7
50.2
be. <.i
5;,. 9
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54.8
52. R
56.5
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59.3
52.6
52.7
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A
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A
A
*
A
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A
*
A
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ftOA EMI
OS ME
T H A -V S
LB/HR
65. 2
64. 1
63.5
50.5
162
158
156
151
155
151
153
15'*
153.
153
154
132
152
149
15 1
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150
152
177
176
169
159
159
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173
174
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£9.4
59.3
57.1
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54.2
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53.9
53.9
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52.7
52.5
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THOD
TRAV
LB/HR
.
.
.
.
.
181
152
J 77
1B1
179
180
181
183.
179
179
179
1 "",0
1 78
179
1?. 0
181.
1 7 a
178
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177
17S
175
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15?
1 32
193
186
.
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* COND
A
A
A
A
A
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A
A
A
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2
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7
7
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7
7
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7
7
7
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REPRESENTS KISSING DATA
A-48
-------
'.OCA/ 1 LCHfiLLOOY
D I V I £ I CM
CkOWN 2KI.LL«uACI(
DUCT bURNf* OUTLET fJ3.\ DftfA SUMMARY
*
*
» DA V
* 20
* 20
* 20
* 20
* 20
* 20
* 20
* 20
20
* 20
* 20
* 20
* 21
'* 21
* C -
« 21
* 21
* 21
* 21
* 21
* 21
* 11 1
* 21
* 21
* 21
* 21
* 21
« 21
* 21
* 21
* 21
* 21
* 21
* 21
* 21
* 21
21
- 21
* 21
* 21
* 21
» 21
21
» 21
* 21
* 21
* 21
*****<
*
*
TIKE *
?100 -
2115 *
2130 *
2145
2200 *
2215 »
223G *
2245 *
2300 *
2315 *
2330 *
2345 *
0 *
i : «
7 o *
4i
1 U w *
J 15
130 *
145 *
200 *
CIS *
245 *
300 *
Mu *
ZJ
333 *
345 -
400 *
415 *
420 *
44 1
5Ci) *
51 b *
530 *
:i41L *
600 *
615 *
630 »
64 b -
700 *
715 *
720 *
745 *
cOO *
615 *
330 *
845 «
ia ******
NOX
PPM
VET
32
32
32
32
33
33
33
33
32
18
14
17
21
12
^ £
12
2
12
12
12
12
12
12
12
1 />
J. C.
12
12
12
12
12
12
11
12
12
12
12
2S
35
33
33
33
23
o3
33
32
33
32
*** *
C2 *
NOX ,\OX *
PPM PPM *
WET DRY *
36 *
36 *
. 36 -
36 *
. 37 -
. 37 *
37 *
37 «
. 36 *
20 *
15 *
. 15 *
23 «
13 *
!3 *
13 *
13
13 *
13 -
13 *
. 13 *
13 «
13 *
13' *
\ \ *
. X J
13 *
. 13 *
. 13 *
. 13 *
13 -
13 *
12 *
13 *
14 *
13 *
16 «
. 31 *
39 *
. 27 *
37 *
37 *
. 37 *
37 *
37.*
36 *
37 *
36 *
*** *******
NOX EMISSIONS *
FC METHuO *
*
LB/MIjTU LH/HR *'
P . 0 9 f.
C.09fa
0. 09*
0.102
0. 104
0. 10 4
0.105
C.105
0.102
0.063
0.048
0.062
0.075
O.C44
C. 04J
0.043
0.042
Cn i ~t
\J ** sj"
C.043
0.043
On a t.
U t »J
0.042
0.041.
0.042
0.042
0.042
0.041
0.039
0.040
0.043
0 . 0 -i 1
C.041
0.094
0.107
0.10 1
0.101
0.103
0.103
0.102
0.120
0,10 0
C.101
0.099
*******
53 . 3 *
51.4 *
02.1 *
53 . 4 *
53.4 *
53.4 *
=4 .1 *
53.9 *
3:3.0 »
21 .5 *
16. b *
21.? *
24 .5 *
14.3 *
14.1 *
!» . 3 *
1-t .; *
j. * ~ r
14.? .
i * . » *
13.5 -
14.2 -
I'l b *
14.5 *
14.2 *
13..°. *
14.2 *
14.2 *
14.3 *
14 .0 *
13.0 *
13.4 *
14.3 *
13.8 *
20.0 *
45.o *
52 .6 *
49.5 *
53.2 *
54.2 *
C-4 . 0 *
b3.b *
E3 « 4 *
53.4 *
52.6 *
52.8 *
*********
NiGX EMISSIONS *
FC METHOD *
*
Lo/MBT'J LL'/ri3 *
u. 1 OD
U.1C4
0.106
C.109
0.110
C.I 10
0.112
0.111
0.103
0.069
0. 053
0.069
0.383
0 . i: 4 q
i) . 0 4 .c
C . U 4 5
t . 0 -. *
C . J if
i . S < 7
:.o* r-.
0.347
0.04 S
p */ '> n
V » J * !
0,049
On 4 c
U ~ O
O.u47
0.046
C . 0 4 7
0.043
C, 049
0.048
0.045
0.047
O.U49
C . 0 4 B
0.048
0.105
0.113
0.110
0.110
0.112
0.111
0.110
(J. IDS
0. 109
0.107
0.106
********
57.1 -
b4.6 *
Sb. fl *
b7.1 *
5 o.9 *
56.7 *
57.6 *
57. 5 *
37.5 *
23.6
18.3 *
23.8 *
27.4 *
lf.,1 *
lu. « *
If.. 5 *
-T.3 *
i .--. ; *
lr.2 *
IT. c "
15. b *
16.0 *
1 c . 1 *
lii.3 »
1 o 0 **
15.9 *
15.3 *
1 6 . C *
16.1 *
1 b. 4 *
16.3 *
15.2 *
15. & *
15.b *
16.0 *
23. 3 *
51.4 *
57.? *
54.0 *
5o. 0 *
58.8 *
5&. b' *
5!-.Q »
57.5 *
5S.O *
57.2 *
5h. 5 *
***** ***
!MOX EMISSIONS * *
OS METHOD * *
TKA^MS TRAV * TtST *
LB/HR LB/HR * COT-JO «
b5. 1 .
51.!:
51.4
52-5
53. 7
54.4 .
54.6
53.6 .
5C. 8
24.6
16.2
22. C
25.7
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J 5 . I
id. 7
1 p. b .
I6.b
16.1
15. 8
16.1
1 ^. K
x r? . t> .
Ic. 3
la. 7
15. i
15. 5
15.7
16.1
16.1
15.0
15.6
16.6
15.9
15.7
42.4
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o4 . 0 .
54. 3
54.7
54.4
37... Q .
53. fi .
53.0
54.6 .
53.3
* * * * *********
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* 5
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13
13
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3
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A *
TS i'lISSINu DATA
A-49
-------
GCA/TECHNOLOGY
D 1 VIS KM
DUCT
CKOWN
bUKNES OuTLtT MOX DATA SUMMARY
It
'«
*
*
*
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DAY
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
2i
ft 1
SI
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
11
21
21
21
22
22
22
22
22
TIME
900
1303
1315
1330
1345
14 CO
1115
1430
1145
1500
1515
1530
154o
1603
1615
1630
lf>45
1700
1 "/ 3 r<
1 ;' 4 b'
1 .-. 0 '..-
lei 15
1'33
1 -^45
l"sCO
1915
1530
1945
2000
2G15
2C30
21 15
2130
214 a
2200
2215
2230
2215
23CG
2315
2330
234:3
C
15
5Q
15
100
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r-PH PPM f-Pi-l
UET WtlT DRY
31
10
36
35
35
35
31
34
35
36
35
37
36
37
37
is.
35
37
T /
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3j
3 a
35
35
31
34
33
32
34
33
32
32
33
36
35
34
33
33
32
32
27
32
14
14
14
13
13
13
37
44
40
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39
. 39
39
38
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. 36
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. 37
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38
33
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. 40
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37
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30
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(VOX friTSS JOAiS *
f o ?-:ETHCD *
LS/Mi3TU LB/hR *
0 . 1 0 ..t
0.118
0.109
C . 1 C 5
P. 10 4
0 . 1 U G
0.103
C.103
0.104
0.10ft
0.105
0.103
0.107
C - 1 J I
0.112
0-106
C . 1 0 5
U . 1 1 0
U «> 1 0 !
0.102
0 . 1 C- 4
2 . 1 j ')
0.104
G . 0 9 ?
0. 100
0,102
0.097
0. 0"? 3
C . 1 0 0
0.101
C. 098
C.C95
0.108
c- . i o e
1.1:5
C . 1 G i
o . : y i
C . 3 "r 9
C. C??!
O.Cr7
0 . 0 ') 2
li . 11' 9
0.049
0.048.
0.049
C. (J46
0.047
0.044
o ri 2
£2 . 7
57.4
55.4
55.1
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55. 3
55.0
5b.8
56 . 2
55.7
£7.7
bo. a
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58 .5
55.7
54 .?
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52. b
5? .6
t.4.7
51 .9
b.? .1
53.5
53.6
52.1
50.8
5S.4
f-b.b
f.7.3
55 .3
54.7
53.7
53.3
3'."- . 4
33.6
40.0
ld.0
16.8
17.1
16.3
16.3
15.5
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viOA EMISSIONS
PC METnOO
Lo/McsTU LB/HR
I). 110
0. 127
C . 1 1 6
0.113
0.112
0.114
C.112
0.111
0.113
0.1 16
0.115
0.119
0.11?
U122
C.I 23
0.118
0. 116
0.12o
r i 1 P
t * lie
C.llo
i . .! 1 4
0.115
C.I 15
o . i : 3
c ..no
C . 1 1 3
c . i u ^i
L. . I 0 S
J . 1 0 v
C.I 1CJ
C.104
0.101
C . 1 1 5
* . 1 1 4
C.112
G . 1 1 9
(J.1G7
U.1C5
3.104
C'-. 103
C..101
0.120
0.054
U. C ;>3
0.054
0.052
0.051
0.049
59.7
b7. 2
61.6
5^.5
59.3
61.3
60.3
59.3
60.7
61.3
61.0
63.1
6?.. 4
63.5
t.4.8
bl. 3
6U.7
66.1
o 3 . 4
61.1
61. o
6 1 . LI
57.b
5-i.O
6-J.4
St.. 3
56.0
5 -'.3
58. 6
55.6
54.1
62. 1
62.1
60.7
5^.2
58.1
5b.9
5 1 . b
37.6
37.0
44. 0
19.S
18.5
lii.9
13. 0
18.0
17.1
* NOX EMISSIONS *
* CS Mf.THGD *
- Ti\ANS TRAV - TLiT
- LiVHR LB/riR * COND
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
f,
*
A
*
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*
tr
*
*
*
«.
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*
*
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*
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*
*
*
*
*
*
*
*
*
*
55.4
fa5. ^
59. 2
56.2
56.2
57. 1
57. 3
55.3
56.0
56.9
57.2
59.7
5 8 . 3
oO. 3
60.0
56.5
55.6
08. 3
K 7 ^
O I * i.
5b. C
j -, . 7
J b . 3
56. 1
53. 7
c.- 4 . 9
55. 1
j3 . C
52.5
5b. 0
54.0
52. b
52. 0
57.2
J $ . 1
57.7
55.7
34.4
53.5
53.3
5 i . 4
37. 3
41 . 5
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18.6
19.1
17.6
17.6
16.8
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. *
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2
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2
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2
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.
.
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12
12
12
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it
*
*
*
*
*
*
A-50
-------
GCA/TECHNOLOGY
DIVISION
CROWN ZELLE^BACh
DUCT BURNER OtTLET NOX DATA SUMMARY
4
4
4
4
*
4
4
4
*
4
4
4
4
4
4
4
4
4
4
4
4
.
»
4
*
4
4
4
4
*
4
rt
4
Jr
4
4
4
4
4
it
4
4
4
*
4
4
*
4
DA Y
22
o o
c .;
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
'.'.2
22
22
21
C.
7.2
22
22
20
22
22
22
22
22
22
22
22
22
22
22
22
22
2.2
22
22
22
22
22
22
22
TlfiC
11 5
\ \ f\
i O J
145
200
215
230
245
300
-IS
330
345
400
415
430
44-5
500
515
33n
'J45
(- '! 0
615
(~ \ n
- J U
645
7 or
71 !;
73 P
7tb
f,on
il 5
945
1000
*» * o
i. O Ji U
1100
lll'j
113P
1145
1 ?. C: 0
1215
123 J
1245
1300
1315
1333
1345
1 -': C 0
1415
* CZ *
* WOX i\OX NQX *
* FPM PPM PPM *
- wET l.'ET DRY *
A
*
*
*
*
*
*
*
*
*
*
.
*
*
*
*
*
*
*
-
*
*
*
*
H
»
4
4
4
4
4
4
4
4
4
4
4
4
4
4
*
4
4
*
4
14
13
12
12
13
13
13
13
12
12
12
12
12
11
10
! 2
12
12
12
12
12
12
12
9
S
a
8
8
14
15
12
11
11
12
12
13
12
12
12
13
13
14
14
13
14
14
15
9 n
£. U
15
13
14
14
. 14
14
. 15
13
. 13
. 13
13
13
. 13
11
. 13
. 13
. 13
13
13
1 T.
. i *J
13
. 13
10
V
9
. n
9
16
. 16
. 13
* T.
0 1 ->
. 12
. 12
13
. 13
14
13
13
. 13
14
. 15
. 15
15
. 15
15
15
4
4
*
4
4
4
4
*
4
4
*
*
*
A
4
4
*
4
*
A
*
*
4
A
*
4
*
*
*
4
tr
it
4
4
4
*
*
4
4
4
4
4
4
Jr
4
4
NO A EKISSIOfJS
tr\ vrTp'*^
LB/METU LE/HR
0.047
On f. f.
U D *t
0.046
O.Ci o
p. 04;
0.045
C. 044
0.044
0.046
0.042
0.042
0.042
0.042
0. 042
0.040
Q . 0 4 1
C.047
0.046
O.U47
0.047
0.046
0.046
0.045
0.045
C . 0 3 5
0.03 i
O.Q33
0.033
0.033
O.CS1
0.053
0.043
On /i n
P U *t U
0.038
0.039
0.040
0.042
0.043
0. 042
0. 042
0.042
0.044
0.045
0.047
0.047
0.046
0.047
C.047
lb.4
->> o
w*- . c.
IS. 9
15.4
15.5
16.1
16.0
15.1
15.6
14 .5
14 .3
14.1
13.9
13.9
13.5
12.5
14.5
14.2
14.4
14.3
14 .0
13. (
13.7
in. 6
10.0
9.9
10.9
10.8
18.1
17.9
14.4
12.9
13.7
14.1
14.9
15.1
14.3
1» .8
14 .9
15.7
15.7
16.2
16.2
16.0
16.5
16.6
» NOX CM: Si I UN'S
* h'C METHOD
tr
* LB/MbTU LB/HR
*
*
4
4
4
4
4
*
*
*
tr
4
W
4
4
*
4
*
*
*
4
4
*
A
A
*
4
4
4
it
4
4
4
4
4
*
4
4
*
4
4
*
4
*
4
0.052
n n 7 n
u u / u
0.050
0.047
0. C43
0.049
0.049
0.049
0 . C 7i 1
0.047
u . !i 4 7
P . C 4 7
C . C "t a
C . C ' 6
0.045
0.047
0. Ci.4
C. C53
0 . U b 'i
C.Lbi
U.054
0 . 'J ; 2
0. C52
0 . 0 4 C
0.. 038
C . 0 i 8
C.C39
C.C38
0.057
0.059
0.047
On u u.
U ** 3
0.043
0. 044
C.046
C.C47
S . U 4 6
0.046
0.04C
O.C 49
C.C50
O.C52
0.052
0.051
0.052
0.052
18.1
O li £1
17.fi
17. i
17. 1
17.8
17.6
lf>.7
17.2
16.0
1-3.3
15. S
15.4
15.3
15.0
14.5
If.. 7
16.4
16.7
16.5
16.2
15.7
15.8
12.2
11.7
11. b
12.7
12.4
20.1
19.9
16. 0
1C 1
J. D 1
14.3
15.1
15.6
16.4
16.6
16.3
16.4
H-.b
17. 4
17.4
17.9
18.0
17.6
16. 4
13.4
* iJCx L'MSSI::.MS *
* CS !/.E7.-'OD *
* tuANS TRAV * TCST
* Ld/HR LB/HR * CONCl
*
4
4
4
4
4
-*
4
*
4
*
*
4
4
4
4
4
*
4
*
4
4
4
4
«
4
H
*
4
4
4
4
4
4
4
4
4
*
tt
*
w
4
4
4
*
IR. 3
04 c
t ^ v
17.f.
16. 1
16.7
17.1
17.1
17.4
17.7
* r.- . 1
lb.
-------
GCA/TECH.'.'CLOC-Y
DIVIS] '^i
DOCT
CUTLET NOX DATA
w
*
* DA Y
« 22
* 22
* 22
* 22
* 22
* 22
* -*?
* 22
^ 22
* 22
* 22
* y 7
* c. c.
* 22
* 22
* 22
* 22
* 52
* 22
* 22
> 22
« 22
* 22
25
* 22
*' 22
* 22
« 22
* 22
* 22
* 22
* 22
» 22
* 22
* 22
* 22
* 22
* 22
- 23
* 23
» 2'i>
* 23
* 23
* 23
* 23
* 23
- 23
TIME
1 " '*, 0
1115
1500
1515
1530
1515
1 6 1, 0
1630
1615
1700
17! j
1 7 -a, r.
JL / C L*
1715
leuo
1815
1330
1 bli.
1 9 0 C
i 9 1 b
1530
1 915
2 OOP
?. e 1 5
21 1 1 --
U 1 .*
2C3C,
.- J ~ '_
2100
2115
2130
2115
22 OP
2211-
2230
2216
2300
2315
233?
2315
C
If.
30
11"
100
115
130
115
2 2 0
*
A
*
*
*
*
*
*
4
*
4
4
*
4
*
*
*
4
*
4
K
4
4
*
.
*
*
.
*
*
*
-
rtr
*
*
#
*
*
*
*
*
*
*
*
*
*
C2
.ox NCX r>ox
PPM PPM PPK
WET I..-ET DRY
15
15
15
15
15
1 6
JL T
?.i
13
13
1 7
*
*
W
o . n b 3
0 . U 5 1
0.056
0.055
P . 0 b b
0.056
0.056
i n ' "-i
J » U « j
O.nbb
0. 0 55
Q. C50
D . C 1 9
On " n
i,' j U
0.050
U.C17
I). 016
C. 017
0. U17
0.016
0 . u 1 F.
0 C -T O
C . 016
C . C 1 5
C . 0 1 5
On t c
« U 'T b
C . 0 ') b
C , . C 1 7
I . t; '< 8
0 . U 't S
0. Olb
C.013
0. 015
C. Oil
0 . 0 4 5
0.011
0.017
0.017
t . 0 1 7
0 : C 1 6
'J . I) 1 7
^ '.!; -; 5;
0 . 0 > 7
C. 015
C. 011
Q.U1S
C.075
0 . 1 3 i
0.159
Ih. b
1 ?.b
1-5.3
19.5
19.5
19.6
1 . fj
i rl » f J
1H.&
i '.) . b
17. D
17.2
17 £l
X / H
17.7
lb»1
16.0
16. 6
1 !J . S
15.9
1-...7
Ifi.B
15. £
1 b . C
16.2
lo.l
16.9
1 o, &
17.0
16.0
15.3
15.0
15.1
15.5
15.1
16.5
16.6
16.3
16.5
1 6U b
16.6
1.S.1
15. ry
10.6
16.9
26.5
17.1
53.8
4
4
4
4
4
*
4
4
4
4
4
*
4
*
4
4
4
4
4
*
4
4
4
*
y-
*
4
4
4
4
it
*
*
4
4
4
*
4
4
4
4
A
4
*
4
4
4
,MOX EMISSIONS *
T « 4 M S T R A V *
Lo/HR LB/HR *
If.
1?.
lc.
19.
19.
19.
i y .
19.
19.
17.
17.
1 "*
J. » »
17.
lu.
15.
1C.
16.
16.
17.
15.
i J*
i!5.
4. -)
1 ^
1 O »
11;
it..
17.
17.
15.
1 1.
15.
15.
» 1-.
A <«r
15.
16*
16.
16.
1 '.": .
i 0 .
1 6 «
1 '..- c
^ c. .
:5.
17.
26.
IS.
55.
.1
i
3
6
a
6
5
6
6
1
1 1
9
3
6
1
5
U
3
7
7
f,
6
6
b
0
1
6
ft
3
1
7
1
3
e
1
1
6
5
4
U
6
0
2
0
<:,
. *
. *
v 4
*
*
ft *
ft *
* *
» 4
« *
* *
* *
*
, *
» 4
*
*
e *
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. 4
*
*
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*
ft *
*
^ *
>
. *
. *
«. *
. *
. *
. *
. *
. *
*
t *
» *
. *
*
. *
. *
. *
TEST
COND
] 3
13
13
13
13
13
13
13
15
13
1 ?
i i
J a.
12
22
12
12
12
12
1?
12
12
12
1 2
1 2
1 ?
1 2
1 2
:2
12
12
12
12
12
12
12
12
12
12
12
12
12
.
.
*
*
*
*
*
»
*
*
*
*
*
*
*
f
-»
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n
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>
4
*
.
-
*
*
»
*
*
*
*
*
*
*
*
»
*
*
*
*
REPRESENTS MISSING DATA
A-52
-------
GCA/TcCH.rjOLO&Y
C ! V1 S I U!
C.KOWN ZF.LLLRBACH
DUCT bUKNL* OUTLET NOX DAI A SUMMARY
*
ft
*
.
*
*
it
*
*
*
*
*
*
*
*
*
A
W
*
*
rt
*
*
*
*
*
*
*
*
*
*
A
«
*
*
*
*
*
V
-*
W
*
A
*
*
*
W
*
*
DAY
23
23
23
2T[
v
23
23
23
23
23
23
23
23
23
23
23
23
23
23
27
~
23
23
23
?3
2Z
23
2i
25
23
23
23
2i
* 7
23
23
23
23
23
23
23
23
2?
23
23
23
23
23
.?3
^ «
TI^E
215
230
245
» d r
O U u
315
330
345
iCfi
415
430
44b
500
c. 1 5
530
Dfci
£ 00
615
63 n
TOO
7i5
' 3 0
.' 4 5
"r." :
. 9 :< 0
9 'i ?
1000
1015
;. C3D
i 0 4 5
1 1 C C
1113
1130
ills
120i)
1215
i?3n
12': rj
1 3 0 C
131?
1330
1345
i"or
1415
1 " 3 C
1445
lf-0'-
i r, ; *=.
*
*
*
*
*
*
*
*
«
*
*
*
*
*
*
*
*
>
*
*
4
W
*
*
*
*
*
*
*
*
-r
ft
A
*
r
*
*
«
*
*
*
*
*
*
*
ft-
-
-
NOX
PPM
UET
35
35
36
T K
+j J
35
34
35
30
35
34
36
28
13
12
11
11
?f{
31
31
31
31
31
£7
93
56
97
96
96
96
95
95
98
99
99
100
5.9
ICO
103
9T
99
ICC
101
101
102
102
101
37
cz
NOX
F-PM
WET
.
*
m
.
.
.
.
.
»
.
.
.
.
.
0
.
.
.
.
1U3
'L 3~j
105
lOb
104
ioe
10 Y
107
106
111
109
10ft
111
103
1C6
i\.?.
10^
10b
110
111
1CS
113
113
111
,\ox
PPM
3RY
3ft
39
39
I. C
O C
38
37
38
3 .".
37
37
39
31
14
13
1?
12
31
3b
35
35
3b
f U
c: :;
1 C 'A
lOf.
107
106
105
105
105
104
1C7
109
108
110
103
10')
1 0 9
103
108
110
110
1 11
111
111
111
42
« NOX EMISSIONS * MOX EMISSIONS
* rD KCTHGD * PC METHOD
* *
* Lb/hoTU LB/HR * LE/MBTU LB/HR
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
it
*
*
*
*
*
*
*
*
*
*
it
*
*
X
*
0.12*
0.12 b
f 1 ^ 9 S
U . j. S O
0.124
0.122
0.123
0. 12i
0. 122
C.12o
u.125
t.097
0.046
C ,043
C.040
O.n^-o
O.OS1
C. 097
On Q a
« U . o
0. 09ft
0..09B
0.097
0.09?
0.24C
I . 2 7 1
o .2f,::
15b
157
156
158
159
15f.
S59
59.5
p
.
-
m
.
.
o
.
.
.
.
.
t .
.
.
.
O
*
.
.
161
Io2
173
160
176
178
17S
177
177
132
154
183
186
184
135
135
183
1F.3
13G
lf/7
187
139
1 39
1 ^3
6 G* 9
*
*
* TiLST
* CQND
*
*
*
*
*
*
*
*
*-
*
*
*
*
A
*
*
*
*
A
*
*
*
»
*
*
*
*
*
*
V
Vr
*
*
*
*
*
*
*-
*
*
*
*
*
it
*
*
} 3
1 '7
.1 «.
1 T
13
13
13
13
»
*
.
.
13
13
13
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A-53
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A-54
-------
GCA/ TLCHK-GLOGY
01 vi SUM
DUCT oUKNEP.
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SUMMARY
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A-55
------- |