United States Industrial Environmental Research EPA-600/7-80-111
Environmental Protection Laboratory May 1980
Agency Research Triangle Park NC 27711
Emissions of
Reactive Volatile
Organic Compounds
from Utility Boilers
Interagency
Energy/Environment
R&D Program Report
-------
RESEARCH REPORTING SERIES
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EPA-600/7-80-111
May 1980
Emissions of Reactive
Volatile Organic Compounds
from Utility Boilers
by
Bernard Jackson, Lou Scinto, and Chris Shih
TRW, Inc.
One Space Park
Redondo Beach, California 90278
Contract No. 68-02-3138
Program Element No. DUN120
EPA Project Officer: Wade H. Ponder
Industrial Environmental Research Laboratory
Office of Environmental Engineering and Technology
Research Triangle Park, NC 27711
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development
Washington, DC 20460
-------
ABSTRACT
The report gives results of the measurement of emission factors for
reactive volatile organic compounds (VOC) from 43 utility boilers firing
bituminous coal, lignite, oil, and natural gas. The boilers ranged in size
from 9 to 910 MW. The median reactive VOC emission factors were determined
to be between 0.47 and 1.85 ng/J for coal- and lignite-fired sources (ex-
cluding stoker data); between 0.03 and 1.48 ng/J for residual-oil-fired
sources; and between 0.01 and 1.00 ng/J for gas-fired sources. Approximate-
ly 50% of the coal- and lignite-fired plants and a majority of the oil- and
gas-fired plants were emitting reactive VOC below the 100-ton per year level.
-------
CONTENTS
Abstract iii
Tables v
Figures vi
1. Introduction 1
2. Summary 3
3. Sampling and Analysis Procedures 5
4. Results and Discussion 8
5. Conclusions and Recommendations 38
References 40
IV
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TABLES
Number Page
1 Reporting Ranges for VOC Analysis 6
2 Characteristics of Bituminous Coal-fired Utility Boilers
Selected for Testing 9
3 Characteristics of Lignite-fired Utility Boilers Selected
for Testing 10
4 Characteristics of Residual Oil-fired Utility Boilers
Selected for Testing 11
5 Characteristics of Gas-fired Utility Boilers Selected for
Testing 12
6 Operating Load and Fuel Feed Rates of Bituminous Coal-fired
Utility Boilers 13
7 Operating Load and Fuel Feed Rates of Lignite-fired,Utility
Boilers 14
8 Operating Load and Fuel Feed Rates of Residual Oil-fired
Utility Boilers 15
9 Operating Load and Fuel Feed Rates of Natural Gas-fired
Utility Boilers 16
10 Bituminous Coal-fired Utility Boiler VOC Emissions 17
11 Lignite-fired Utility Boiler VOC Emissions 22
12 Residual Oil-fired Utility Boiler VOC Emissions 23
13 Gas-fired Utility Boiler VOC Emissions 25
14 Total Volatile Organic Compound Emissions 26
15 Averaged Volatile Organic Compound Emissions 28
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FIGURES
Number Page
1 Cumulative Graph of VOC Data for Bituminous Coal- and
Lignite-fired Units With Pulverized or Cyclone Firing. . . 31
2 Cumulative Graph of VOC Data for Bituminous Coal-fired
Boilers 32
3 Cumulative Graph of VOC Data for Lignite-fired Boilers . . 33
4 Cumulative Graph of VOC Data for Oil-fired Boilers .... 34
5 Cumulative Graph of VOC Data for Gas-fired Boilers .... 35
VI
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1. INTRODUCTION
This report was prepared under the Conventional Combustion Environmental
Assessment program, to support the requirements of the Monitoring and Data
Analysis Division (MDAD) of the Office of Air Quality Planning and Standards
(OAQPS), for the development of reactive volatile organic compound (VOC)
emission factors for utility power plants. The emission factors developed by
TRW were derived from stack sampling tests conducted by TRW and its sub-
contractor, GCA, at a number of bituminous coal-, lignite-, oil- and gas-fired
utility boilers throughout the United States, as part of the "Emissions Assess-
ment of Conventional Stationary Combustion Systems" (EACCS) program under EPA
Contract No. 68-02-2197. The sampling and analysis procedures 'employed in the
EACCS program were an integral part of the phased environmental assessment
approach and applied primarily to Level I. The results obtained were intended
to provide the basis for establishing the priorities of streams, components,
and classes of materials for further testing by more stringent Level II tech-
niques and procedures. As such, the results of the sampling and analysis
procedures were designed to be quantitative within a factor of ħ 2 to 3. A
detailed discussion of the sampling and analysis methods used to determine VOC
emissions could be found in the Methods and Procedures Manual for Sampling and
Analysis prepared specifically for the EACCS program (1). In the preparation
of this manual, the IERL Procedures Manual - Level 1, Environmental Assessment
(2) was used as the guideline and made an integral part of it.
VOC's, as defined in the EACCS program, cover compounds that range in
boiling point from -160 to 300°C. This parallels the boiling range of n-alkanes
from methane (C-,) through n-hexadecane (C-ic)- Total VOC emissions include C-|
to C-jg hydrocarbons. However, only the reactive hydrocarbons, C2 to C^g, are
of regulatory interest to the EPA at this point. Methane has been excluded
from the reactive VOC emission factors calculated in this study. Although it
is obvious that most of the C^'s are methane, it is not known from the TRW/GCA
-------
data the quantity of other specific organic compounds present. This is
because of the nature of the Level I procedures utilized by TRW and GCA in
the sampling and analysis of utility boiler flue gases, for which no detailed
attempt was made to routinely identify individual organic compounds. Reactive
VOC emission data presented in this report, therefore, include all organic
emissions in the Cg to C^g n-alkane boiling range. The emission values
presented are conservative, since limited data acquired by Rockwell have
shown that most of the Cg compounds emitted are in the form of ethane, and
ethane is classified as non-reactive per the EPA July 8, 1977 VOC designation
(3). If the Rockwell data were substantiated, the C,, fraction of VOC's could
be subtracted from the emission factors, resulting in lower reactive VOC
emission estimates.
-------
2. SUMMARY
A number of utility boilers were tested for stack VOC emissions. Samples
were taken and analyzed in the field for C, to Cg's, and in the laboratory for
Cj to C-ig's. Fuel heating values, fuel analysis results, and stack gas oxygen
concentrations were used to compute emission factors on a mass per unit heat
input basis. Numbers calculated from laboratory analyses were on a mass per
standard gas volume basis (1 atmosphere, 20°C). Data for a total of 43 sites
have been analyzed in this report. The breakdown of utilities tested by
boiler type was:
3 pulverized bituminous coal-fired, dry bottom
t 6 pulverized bituminous coal-fired, wet bottom
6 cyclone bituminous coal-fired
3 stoker bituminous coal-fired
3 pulverized lignite-fired, dry bottom
2 cyclone, lignite
t 2 stoker lignite-fired
5 tangentially-fired oil
6 wall-fired oil
3 tangentially-fired gas
4 wall-fired gas
The breakdown by fuel type was:
18 bituminous coal-fired
7 lignite-fired
11 residual oil-fired
7 gas-fired
The size of utility boilers tested ranged from a small lignite-fired
boiler of 9 MW to a large bituminous coal-fired unit of 910 MW.
-------
Data were summarized in tabular form by site, fuel, and boiler type.
Summations were made for each of the following C, to C,g individual alkane
equivalents:
f C2 to Cg (-100 to 90°C boiling range)
C7 to C1g (90 to 300°C boiling range)
C2 to Clg (reactive VOC's, -100 to 300°C boiling range)
C1 to Clg (-160 to 300°C boiling range)
C.| to Cg's were determined in the field; C7 to C-jg's in the laboratory.
Means and standard deviations were calculated for each fuel and boiler type.
Emission data were analyzed by plotting reactive VOC emission values
versus the cumulative frequency in the population sampled. Based on equivalent
alkane groups, the median reactive VOC emission factors were determined to be
between 0.47 and 1.85 ng/J for coal- and lignite-fired sources (when stoker
data were excluded), between 0.03 and 1.48 ng/J for residual oil-fired sources,
and between 0.01 and 1.00 ng/J for gas-fired sources. The range of emission
estimates represents different interpretations of the emission data and
whether upper detection limits were used in the computation of emission
factors.
For a 1000 MW power plant operating at 33 percent efficiency and a load
factor of 60 percent, an emission factor of approximately 1.58 ng/J is
required in order for the power plant to exceed 100 tons reactive VOC's per
year. Analysis of the emission data indicated that approximately half of
the coal- and lignite-fired plants, and the majority of residual oil- and
gas-fired plants are emitting reactive VOC's below this level.
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3. SAMPLING AND ANALYSIS PROCEDURES
Stack gas emissions from a number of utility boilers were sampled in the
"Emissions Assessment of Conventional Stationary Combustion Systems" (EACCS)
program. In the analysis of samples, a gas chromatograph (GC) was calibrated
and the results tabulated as total hydrocarbon mass corresponding to the various
alkanes. These alkanes, their boiling points and the reporting ranges are shown
in Table 1. Most saturated and aromatic hydrocarbons are relatively nonpolar
and thus eluted at retention times corresponding to their boiling points on the
GC columns chosen for the EACCS program. Possible hydrocarbons in each reported
boiling range could be tentatively established. However, polar compounds with
functional groups do not always follow the same bp-retention time relationships
as the hydrocarbons. For example, a C? organic acid, bp 119°C, may or may not
elute in the boiling range 110-140°C. The scope of the EACCS program did not
include specific identification of individual compounds.
Sampling and analysis of VOC's were performed in two distinct parts (1).
In part 1, the C,-Cg materials were collected on site in Tedlar bags utilizing
EPA Method 3. This bag sample was then analyzed immediately on site using a
dual column FID gas chromatograph with 6 ft. (1.8 m) x 1/8 inch (3.2 mm) stain-
less steel columns packed with Poropak Q. The instrument was calibrated with
a C-,-Cg standard accurate to ħ 15-20%. During the early testing phase of the
EACCS program, however, erratic electrical fields at most power plant sites
have precluded use of the maximum sensitivity of the instrument.
During the EACCS program, TRW was directed to attempt an increase in the
GC sensitivity by a factor of approximately 10 to achieve a new sensitivity of
about 0.1 ppm. This was done by using a larger sample size and by installing
a special electrical isolation transformer.
In the second part of the sampling and analysis methodology, the Cy to C16
materials were collected in the field using a porous polymer resin (XAD-2)
mounted downstream of the filter in the particulate sampling portion of the SASS
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TABLE 1. REPORTING RANGES FOR VOC ANALYSIS
Methane
Ethane
n-Propane
n-Butane
n-Pentane
n-Hexane
n-Heptane
n-Octane
n-Nomane
n-Oecane
n-Undecane
n-Docane
n-Tridecane
n-Tetradecane
n-Pentadecane
n-Hexadecane
Boiling Point °C
-161
- 88
- 42
0
36
69
98
126
151
174
196
216
234
252
270
288
Reporting
-160 to
-100 to
- 50 to
0 to
30 to
60 to
90 to
110 to
140 to
160 to
180 to
200 to
220 to
240 to
260 to
280 to
Range, °C
-100
- 50
0
30
60
90
no
140
160
180
200
220
240
260
280
300
Reported As
c1
C2
C3
C4
C5
C6
C7
Cg
cg
C10
c. ,
C12
c13
CH
C15
C16
train. Some VOC's might have also been adsorbed on the collected participate
or condensed in the train. Organic material collected on the resin and on the
participate catch was then extracted with methylene chloride in Soxhlet ex-
tractors in the laboratory. Condensed material was analyzed using a dual
column FID gas chromatograph with 6 ft. x 1/8 inch (1.8 m x 3.2 mm) stainless
steel column packed with 1.5% SE-30A OV-101 on Gas Chrom Q. These results were
reported separately.
-------
It must be realized that less than 100% VOC sample collection efficiency
(in the field) or sample recovery efficiency (in the laboratory) may have
introduced error in the reported Cy-C^ values. Arthur D. Little, Inc., is
presently documenting collection efficiency, while experiments at TRW indicate
that substantial (*50%) losses of Cy materials are observed in the Level I
analysis preparation procedure.
In analyzing Cy to C-^'s, gas chromatography was used to determine the
quantity of lower boiling hydrocarbons (boiling points between 90° and 300°C)
in the concentrates of all organic solvent rinses and XAD-2 resin fractions
encountered in Level 1 environmental sample analyses. Typically, this pro-
cedure generated analytical results based on the sum of Cy to C16 total
chromatographable organic (TCO) contributions from each part of the SASS sample
train. However, TCO analyses of particulate extracts and probe and cyclone
rinses were eliminated after March, 1978, by an official EPA change to Level I.
This change was subsequently incorporated into the EACCS analysis procedures,
as contributions to TCO's from these components were found to be negligible.
Filter catches and XAD-2 module condensate contributions to TCO's were analyzed.
The conditions under which TCO analyses were conducted provided a lower
-4 3
detection limit equivalent to a hydrocarbon concentration of 2 x 10 mg/m in
30 m of sample gas (the quantity of gas required in these tests).
In contrast to Cy to C,g analyses, which were quantitatively determined due
to low detection limits, many C, to Cg analyses were reported as less than 0.1
ppm, or less than 1.0 ppm, based on methane. Thus, a reported value of less than
1 ppm for any C, to Cx- implies an actual value anywhere between 0 and 667 ug/m .
3
Alternatively, a reported value of 1 ppm was defined as 1251 yg/m for C?'s,
3 e-
3585 yg/m for Cg's, etc.
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4. RESULTS AND DISCUSSION
The rated capacity, age, and pollution control method for the 43 sites
tested are presented in Tables 2 to 5. The operating load and fuel feed
rates for these sites at the time of testing are presented in Tables 6 to 9.
These data are provided to associate the test results with site character!sties,
Table 10 provides a detailed tabulation of C, to C,g orgam'cs for each
bituminous coal-fired utility boiler tested, The analyses are grouped by
boiler type - pulverized coal, dry bottom, wet bottom, cyclone, and stoker.
All values are listed opposite their equivalent C, to C,g alkane group in
ug/m . In addition, total values for C2 to Cg, C7 to Clg, CĞ to Clg, and C,
to C,c are summed for each site at the bottom of each column. These totals
3
are given in both ug/m and ng/J.
To convert from ug/m to n/J required computation of site specific factors
from boiler operating parameters, including oxygen percent in the outlet flue
gas, fuel composition, and fuel heating values. Specifically, the number of
gm moles of flue gas per gm of fuel was first computed using the fuel com-
position analysis and effluent CL concentration:
4.762 (nr + nc + 0.5 nw) + .9405 nu - 3.762 nn
u j IN n UĞ
1
- 4.762 (02/100)
where: npG = gm moles of dry effluent/gm of fuel under
actual operating conditions.
n. = gm moles of element j in fuel per gm of fuel.
J
0Ğ = volumetric Op concentration in percent.
The emission factor expressed as ng/J was then computed from emission con-
centration expressed as ug/m using the following equation:
(Emission)
{ Factor }
(Mass \ 3
(Concentration/" (yg/m ) x n x 24.04
nting V.l
8
(kj/kg fue' '
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TABLE 2. CHARACTERISTICS OF BITUMINOUS COAL-FIRED
UTILITY BOILERS SELECTED FOR TESTING
Combustion
Source Type
Pulverized
Dry Bottom
Pulverized
Wet Bottom
Cyclone
Stoker
Site No.
154
205-1
205-2
206
212
213
218
336
338
134
207
208
209
330
331
137
204
332
Rated
Capacity,
MM
358
91
77
128
145
137
825
360
360
874
643
360
643
135
135
12.65
12.65
7.5
Age as
of 1979,
Years
4
22
21
17
21
21
3
9-10
9
10
11
16
12
24
20
22
IB
21
Pollution Control Device
Met scrubber utilizing lime/alkaline fly ash with tested efficiencies of 99.5%
for particulate removal and 70-75% for SOg removal.
Mechanical precipitator of 202 design efficiency in series with ESP. Combined
design efficiency: 90-99.5%. Combined tested efficiency: 98.6%.
Mechanical precipitator of 20% design efficiency In series with ESP. Combined
design efficiency: 90-99.5%. Combined tested efficiency: 98.6%.
Mechanical precipitator of 83.5-84% design efficiency in series with ESP.
Combined design efficiency: 99.6%. Combined estimated efficiency: 99.6%.
ESP with 99.9% design and 99.9% estimated efficiency.
ESP with 99.9% design and 99.9* estimated efficiency.
Venturl wet scrubbing system utilizing thiosorbic lime, with 99.9% tested
particulate removal efficiency and 95.0% tested S02 removal efficiency.
ESP with 99.0% design and 94.5% tested efficiency.
ESP with 99.0% design and 94.5% tested efficiency.
Het scrubber utilizing limestone with design efficiency of 98.75% for particulate
removal and 76.0% for S02 removal; tested efficiency 98.2% for particulate
removal and 76.2-80.14% for S0£ removal.
ESP with 98% design and 94.30% tested efficiency.
ESP with 96.0-98.0% design and 96.70-98.70% tested efficiency.
ESP with 98% design and 94.30% tested efficiency.
ESP with 99.65% design and 96.08% tested efficiency.
ESP with 99.65% design and 98.55% tested efficiency.
Baghouses with 99.92% tested efficiency.
Mechanical precipitator with 94.9% design and 85.5-85.6% tested efficiency.
Multiclone with 92% design and 75.0-83.5% tested efficiency.
Efficiencies apply to particulate removal unless otherwise stated.
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TABLE 3. CHARACTERISTICS OF LIGNITE-FIRED
UTILITY BOILERS SELECTED FOR TESTING
Combustion
Source Type
Pulverized
Dry Bottom
(Front-fired)
Cyclone
Spreader Stoker
Site
No.
314
315
318
155
316
317
319
Rated
Capacity,
MM
20
20
66
437
440
8
15
Age as
of 1979,
Years
29
27
15
4
6
31
30
*
Pollution Control Device
Multlclones with 84% design efficiency.
Multlclones with 84% design efficiency.
ESP with 98.5% design efficiency.
ESP with 98.8% design and 99.8% test efficiency.
ESP with 99.05% design and 99.53% test effi-
ciency.
Multlclones with 89.5% design efficiency.
ESP with 99.82% design efficiency.
Listed efficiencies are for partlculate removal.
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TABLE 4. CHARACTERISTICS OF RESIDUAL OIL-FIRED
UTILITY BOILERS SELECTED FOR TESTING
Combustion
Source Type
Tangentlally
Fired
Wall Fired
Site No.
210
211
322
323
105
109
118
119
141-144
305
324
Rated
Capacity,
MW
75
158
637
40
44
170
750
345
350
560
40
Age as
of 1979,
Years
24
14
7
26
21
24
11
17
14
11
29
*
Pollution Control Device
Mechanical precipitators.
ESP.
Cyclone separators with 85% design efficiency.
None.
None.
None.
Off-stoichiometric firing and flue gas recir-
culation for NOX control.
None.
Off-stoichiometric firing/flue gas recircula-
tion for NOX control.
ESP with 99% design efficiency.
None.
Efficiencies listed are for particulate removal. Particulate removal efficiencies for the control
devices associated with Sites 210 and 211 are not available. For Sites 322 and 305, the stated
design efficiencies for particulate removal may be for coal firing and not for oil firing.
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TABLE 5. CHARACTERISTICS OF GAS-FIRED
UTILITY BOILERS SELECTED FOR TESTING
ro
Combustion
Source Type
Tangentially
Fired
Wall Fired
Site
No.
113
114
115
106
108
116
117
Rated
Capacity,
MM
113.6
80
180
42
170
50
75
Age as
of 1979.
Years
13
23
15
21
24
19
17
Pollution Control Device
None.
None.
None.
None.
None.
Overflre air for NO control.
Over fire air for NO., control.
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TABLE 6. OPERATING LOAD AND FUEL FEED RATES OF
BITUMINOUS COAL-FIRED UTILITY BOILERS
Combustion
Source Type
Pulverized
Dry Bottom
Pulverized
Wet Bottom
Cyclone
Stoker
Site No.
154
205-1
205-2
206
212
213
218
336
338
134
207
208
209
330
331
137
204
332
Operating
Load, MW
282
91
77
110
135
130
830
356
324
690
440
310
450
119
119
11.2
9.9
6.5
% of
Base Load
79
100
100
86
99
95
100
99
90
79
68
86
70
85
85
89
78
87
Fuel Feed
Rate, kg/hr
159,500
33,680
25,630
47,000
38,520
37,100
240,360
126,550
129,500
295,000
213,000
126,530
210,000
60,200
53,928
5,800
5,570
4,060
Energy Input
GJ/hr
3,175
930
710
1,300
1,050
1,030
7,120
3,790
3,900
7,090
5,000
2,900
5,120
1,540
1,330
166
148
10
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TABLE 7. OPERATING LOAD AND FUEL FEED RATES
OF LIGNITE-FIRED UTILITY BOILERS
Combustion
Source Type
Pulverized
Dry Bottom
(Front fired)
Cyclone
Spreader Stoker
Site No.
314
315
318
155
316
317
319
Operating
Load. MW
20
20
68
420
383
7.5
12.3
% of
Base Load
100
100
103
96
87
94
82
Fuel Feed
Rate, kg/hr
19,200
17,700
54,000
336,500
372,900
8,230
13,000
Energy Input
GJ/hr
292
290
855
4,780
5,420
91
187
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TABLE 8. OPERATING LOAD AND FUEL FEED RATES OF
RESIDUAL OIL-FIRED UTILITY BOILERS
en
Combustion
Source Type
Tangential ly
Fired
Wall Fired
Site No.
210
211
322
323
105
109
118
119
141
142
143
305
324
Operating
Load, MW
79
152
548
42
44
171
702
281
330
218
325
560
43
% of
Base Load
105
96
86
105
100
100
94
81
94
62
93
100
108
Fuel Feed
Rate, kg/hr
18,500
35,600
111,800
12,200
13,000
40,800
165,100
61,700
69,000
54,900
66,300
116,100
12,500
Energy Input
GJ/hr
860
1,650
4,780
520
580
1,830
7,010
2,920
3,030
2,410
2,920
5,100
530
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TABLE 9. OPERATING LOAD AND FUEL FEED RATES OF
NATURAL GAS-FIRED UTILITY BOILERS
CTl
Combustion
Source Type
Tangentially
Fired
Wall Fired
Site No.
113
114
115
106
107
108
116
117
Operating
Load, MW
90
76
193
36
19.5
162
48
70
* of
Base Load
79
95
107
82
65
95
96
93
Fuel Feed
Rate, m3/hr
22,710
22,650
50,970
13,310
7,500
40.210
14,050
20,400
Energy Input
GJ/hr
870
870
1,950
510
290
1,540
540
780
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TABLE 10. BITUMINOUS COAL-FIRED UTILITY BOILER VOC EMISSIONS
Boiler Type
Site No.
Cl
C2
C3
C4
C5
C6
C7
C8
C9
C10
Cn
C,2
C13
C14
C15
C16
Add'l C,-C,,
7 16
TOTALS
C2-C6
VC16
/ 1 U
C2-C16
t | U
Crci6
1 1 U
Pulverized coal, dry bottom
205-1
<667
<667
<667
<667
<667
<667
38.1
206.8
69.9
75.2
<1.0
205.4
32.0
13.6
2.5
4.6
0
wg/m ng/J
0-3335 0-1.587
648- 0.309
649
648- 0.309-
3984 1.896
648- 0.309-
4651 2.214
NOTE: For conversions from metric to
6.
2.
243 x 10"11 x Mg/m3 = lb/ft3
326 x 10"9 x ng/J = Ib/Btu
205-2
<667
<667
<667
<667
<667
<667
17.0
133.0
72.9
306.7
41.5
192.3
73.0
45.8
82.8
4.1
0
M9/m3 ng/J
0-3335 0-1.605
969 0.466
967- - 0.466-
4304 2.072
967- 0.466-
4971 2.393
English units:
(pg/m3)
154
3337
<334
<334
<334
3301
<334
22
68
44
4
16
6
8
4
8
0
0
fg/m3
3301-
4637
180
3481-
4817
6818-
8154
ng/J
1.551-
2.178
0.085
1.635-
2.263
3.203-
3.830
-------
TABLE 10. (Continued)
CD
Boiler Type
Site No.
Cl
C2
C3
C4
C5
C6
C7
C8
C9
C10
cn
C12
C13
C14
C15
C16
Add'l C?-C)6
TOTALS
C--C,
2 o
Crci6
c -c
crc
Pulverized coal, wet bottom (pg/m )
206
10.544
838
<334
<334
34.305
<334
75.7
106
81.9
77.7
<0.8
447.2
19.6
13.6
25.9
37.0
0
pg/m ng/J
35.143- 16.508-
36.145 16.978
871.8- .410-
875. 4 .411
36.015- 16.917-
37,020 17.389
46,559- 21.870-
47.564 22.342
212
1268
<67
<67
<67
<67
<67
<0.2
77.1
43.0
<0.4
1.1
5.0
6.7
3.8
0.9
<0.4
0
pg/m ng/J
0-335 0-.163
136.0- .066-
138.6 .067
136- .066-
474 .230
1404- -682-
1742 .846
213
4872
250
<67
<67
<67
<67
3.2
31.4
39.9
<0.4
<0.4
2.1
3.3
<0.4
1.6
<0.4
0
Mg/m ng/J
250- .122-
518 .252
79.9- .039-
83.1 .040
330- .161-
601 .293
5202- 2.535-
5473 2.667
336
734
876
<334
<334
034
<334
-<1
98
"1
96
9
"1
<1
18
<1
12
0
pg/m ng/J
876- .367-
2212 .928
233- 0.098-
238 0.100
1109- .465-
2450 1.028
1843- .773-
3184 1.335
338
1001
1626
<334
<334
<334
<334
104
203
3
272
8
126
52
14
4
35
0
Mg/m ng/J
1626- .713-
2962 1.299
821 ,360
2447- 1.073-
3783 1-659
3448- 1.512-
4784 2.098
218
1602
<334
<334
<334
O34
<334
21
41
39
0
18
39
0
12
0
9
0
ng/m ng/J
0-1670 0-
.621
179 .067
179- .067-
1849 .688.
1781- .662-
3451 1.283
-------
TABLE 10. (Continued)
Boiler Type
Site No.
Cl
C2
C3
C4
C5
C6
C7
C8
C9
C,0
Cll
C12
C13
C14
C15
C16
Add'l C?-C16
TOTALS
C,-C,
2 6
C -C
7 16
C--C,,
2 16
1*1 ~ l*i f
1 16
134
1800
<667
<667
<740
<667
<667
<0.2
50
13
260
300
71
7.4
2.4
27
42
0
pg/m ng/J
704- .312-
3408 1.510
773.0 .343
1477- .655-
4181 1.853
3277 1.452-
5981 2.651
207
<67
<67
<67
<67
<67
<67
31.0
43.0
12.5
27.8
4.0
108.4
7.4
3.9
0.6
1.3
0
3
^g/i" ng/J
0-335 0-.212
237.1- .151
239.9
237- .151-
575 .363
237- .151-
642 .405
Cyclone
208
f
1
NO
DATA
1F
<0.4
<0.2
<0.2
0.9
<0.4
5.0
2.3
<0.4
<0.4
<0.4
0
ug/m ng/J
_ _
7.0- .0037-
10.6 .0055
_ _
_ _
(iig/m3)
209
<67
<67
<67
<67
<67
<67
10.0
26.0
26.7
52.4
5.1
35.4
12.1
8.8
0.4
19.8
0
Mg/m3 ng/J
0-335 0-.137
- 193.3- .081
196.7
193- .079-
532 .218
193- .079-
599 .245
330
187
<667
<667
9865
<667
56,711
28
<]
Ğ1
2
24
31
<1
<1
<1
3
3
ug/m ng/J
66,576- 27. Se-
es, 577 28.38
91- .038-
96 .040
66.667- 27.59-
68.673 28.42
66,859- ,27.67-
68,860 28.50
331 .
1068
<667
<667
<667
<667
12,403
1080
2290
83
1127
70
2
50
110
319
794
0
u g/tn ng/J
12,403- 6.434-
15.071 7.819
5925 3.074
18,328- 9.508-
20,996 10.89
19,396- 10.06-
2?. 064 11.45
-------
TABLE 10. (Continued)
ro
o
Boiler Type
Site
Add'l
No.
Cl
C2
C3
C4
C5
C6
C7
C8
C9
C10
CU
C12
C13
C14
C15
C16
C,-C,,
7 16
TOTALS
VC6
£ U
7 Ifi
/ IU
VC16
c,-c,.
1 16
137
734
<67
<67
<67
<67
<67
4.3
160.0
5.1
33.0
0.4
0.4
10.1
3.2
0.4
11.7
0
n9/m ng/J
0-335 0-.184
225.4- .126
228.6
225- .124-
564 .310
959-
1298 .527-
.713
Stoker (wg/m3)
204
<667
<667
<667
<667
<667
<667
76
32
1
305
2
31
4
127
27
93
0
pg/m ng/J
0-3335 0-1.817
698 .380
698- .380-
4033 2.197
698- .380-
4700 2.560
332
1201
11,508
<667
<667
<667
<667
14,776
400
47
330
214
42
43
57
10
20
0
>j g/m
11,508-
14,176
15.939
27.447-
30.115
28,648-
31 ,316
ng/J
5.487-
6.759
7.600
13.09-
14.36
13.66-
14.93
-------
The final row of data, before totals and immediately following C,g's is
identified as additional C-, to C,c's. This number takes into account com-
/ i o
ponents in the SASS train (such as probe rinse, cyclone rinse, etc.) which
contained less than the minimum sample quantity required for individual analyses
by alkane group.
Tables 11, 12, and 13 provide the same type of data as shown in Table 10,
but for lignite, residual oil, and gas-fired utility boilers, respectively.
Table 14 presents a summary of totaled data from Tables 10 to 13 in both SI
Q
units (ng/J) and English units (lb/10 Btu). Data are presented for each site
tested by feed type (coal, lignite, residual oil, and gas) and boiler type
(pulverized dry bottom, pulverized wet bottom, cyclone, stoker, tangentially-
fired, and wall-fired).
Means, x, and standard deviations of the mean, s(x), have been calculated
for each group of data in Tables 10 to 14 corresponding to a common fuel and
boiler type. These statistical parameters have been tabulated1in Table 15 for
each of the four totals (CĞ to Cc, C-, to C,c, C0 to C,c, and C, to C,c) by fuel
C 0 / ID £ ID I ID
and boiler type.
The standard deviation calculated in this report is based on a limited
sample size and is designated as s(x). six) differs from the estimate of the
population standard deviation, s(x). s(x) is based on the sample x,, x^... x
and is calculated by the following formula (4):
s(x) =
n-T
The use of n-1 in the denominator offsets the bias due to calculating the
deviations of x from x, the sample mean, rather than from the unknown true
population means.
s(x) designates the estimated standard deviation of the means of samples
of size n drawn from the populaton which is estimated to have a standard
deviation of s(x). These two quantities are related in the following way:
s(x) =
21
-------
TABLE 11. LIGNITE-FIRED UTILITY BOILER VOC EMISSIONS
Boiler Type
Site No.
Cl
c.
2
C3
C4
C5
C6
C7
C8
C9
C10
Cll
C12
C13
C14
C15
C16
Add'l C7-C,,
/ ID
TOTALS
C2'C6
£ D
C7-C.,
1 16
C2'C16
£. 1 U
Crci6
1 1 U
Pulverized, dry bottom (119/01
314
1.335
<667
<667
<667
9,004
32.263
<0.2
*1'0
13.8
82.3
37.3
132.0
0
1.94
14.8
40.4
106.0
3
iig/m ng/J
41.267- 14.21-
43,268 14.90
428.5- .148
429.7
41,696- 14.36-
43,698 15.05
43.031- 14.82-
45,033 15.51
315
5.339
<667
<667
<667
<667
<667
<0.2
<0.2
4.0
73.5
133.3
96.8
313.8
3.2
291.0
6.7
14.0
3
fg/m ng/J
0-3335 0-1.125
936.2- .316
936.6
936- .316-
4.272 1.441
6.279- 2.116-
9.611 3.241
3)
318
1.034
1.751
1.211
<667
<667
<667
4.8
<1.0
71.0
56.2
<0.2
94.0
43.1
63.5
35.9
32.9
18.0
3
i'9/m ng/J
2,962- 1.820-
4,963 3.049
419.4- .258
420.6
3.381- 2.077-
5.384 3.308
4.415- 2.712-
6.418 3.943
Cyclone
316
10.677
<667
<667
<667
<667
<667
<0.2
<0.2
0
143
0
75
0
3
.2
123
2
3
tig/iii ng/J
0-3335 0-1.308
382.4- .150
382.6
382- .150-
3718- . 1.458
11.059- 4.336-
14,395 5.645
(pg/ffl3)
155
2.202
<334
<334
<334
5.102
<334
14
29
30
23
5
10
6
6
8
7
0
3
pg/m ng/J
5102- 2.065-
6438 2.605
138 .056
5240- 2.121-
6576 2.661
7442- 3.012-
8778 3.552
Stoker
317
1,782
<667
<667
<667
<667
<667
<0.2
<1.0
0
164
202
104
0
22.5
12.3
34.5
104
i
ng/m ng/J
0-3335 0-1.839
643.3- .355
644.5
643- .355-
3980 2.195
2425- 1.337-
5762 3.178
(ng/m3)
319
^
n
DATA
<0.
<1-
16.
60
00
67.
33
37
12
19
23
^
pa/"1
..
269.0
270.2
..
--
2
o
3
1
6
7
0
1
0
2
ng/J
--
.148
--
--
-------
TABLE 12. RESIDUAL OIL-FIRED UTILITY BOILER VOC EMISSIONS
ro
CO
Boiler Type
Site No.
Cl
C2
C3
C4
C5
C6
C7
C8
C9
C10
Cll
C12
C13
C14
C15
C16
Add'l C,-C1C
/ 1 D
TOTALS
C2'C6
C. V
C7'C16
/ 1 V
C2'C16
C -C
1 16
Tangential ly-fi red (pg/m )
210
<667
<667
<667
<667
3,301
<667
17.5
62.5
13.4
3.4
0.3
2.9
2.2
0.6
0.6
2.0
0
3
pg/m ng/J
3301- 1.438-
5969 2.601
103.2- .056
105.4
3404- 1.483-
6074 2.647
3404- 1.483-
6741 2.819
211
734
<67
<67
<67
<67
<67
22.8
0.8
0.9
45.7
<0.4
5.1
15.8
5.6
0.8
2.8
0
3
pg/m ng/J
0-335 0-.135
98.1- .041
100.7
98-436 .039-
.176
832- .335-
1170 .471
322
2,469
<667
<667
<667
<667
<667
<1
44
36
0
0
59
47
0
0
0
0
3
pg/m ng/J
0-3335 0-1.264
187 .071
187- .071
3522 1.335
2656 1.007
5991 2.271
323
2,669
<667
<667
24,903
<667
<667
<1
16
<1
0
0
0
1
0
0
0
0
3
pg/m
24,903-
27.571
19
24.922-
27,590
27.591
30,259
ng/J
11.82-
13.09
.009
11.83-
13.10
13.10
14.37
-------
TABLE 12. (Continued)
Boiler Type
Site No.
Cl
C2
C3
C4
C5
C6
C7
C8
C9
C10
C
ro 'I
c,2
C13
C)4
C15
C16
Add'l C?-C,6
TOTALS
C,-C,
2 6
C C
r 16
C2-C16
C -C.,
105 109
16,684
<667
<667 Nl
<667
<667
<667
-------
TABLE 13. GAS-FIRED UTILITY BOILER VOC EMISSIONS
Boiler Type
Site No.
Cl
C2
C3
J
C4
C5
C6
C7
C8
C9
C10
r
ro 11
C12
C13
C14
C15
C16
Add'l C?-C)6
TOTALS
C,-C,
2 fa
c7-c16
/ 1 D
c,-c16
£ 1 0
crc,6
1 1 D
113
<334
<334
<334
<334
<334
<334
3.2
18.0
11.7
<0.2
<0.2
<0.2
<0.6
3.2
2.1
<0.6
0
3
pg/m
0-1670
37.0-
40.0
37-1710
37-2044
Tangential ly-flred {pg/m )
114
<667
<667
<667
<667
<667
<667
<0.8
17.2
5.3
11.3
<0.4
<0.4
<0.4
1.2
2.5
<0.6
0
3
ng/J pg/m ng/J
0-0.50 0-3335 0-.987
.012 36.5- .012
40.1
.012- 37-3375 .012-
0.51 .999
.012- 37-4042 .012-
0.61 1.197
115
<667
<667
<667
<667
<667
<667
12.6
32.4
5.1
22.6
35.9
16.5
34.2
57.1
107.8
98.6
0
3
pg/m ng/J
0-3335 0-1.309
419.2- .166
422.8
419- .166-
3758 1.475
419- .166-
4425 1.736
106
24.692
9,669
<667
<667
<667
<667
<1
396
1.288
891
23,900
1.80Q
2,971
1.684
<1
<1
0
3
pg/m ng/J
9.669- 3.095-
12.337 3.949
32.930 10.54
.
42,599- 13.64-
45,267 14.49
67,291- 21.54-
69.959 22.40
Wall -fired
108
NO
DATA
<1
199
99
298
1,192
1,093
1.490
994
1.292
1,590
0
3
--
8248 3.356
--
(pg/m3)
116
<667
<667
<667
<667
18.000
<667
1.3
37.5
1.2
14.7
562.4
252.5
156.5
166.6
207.7
304.9
0
3
pg/m ng/J
18,000- 6.651-
20,668 7.640
1702.9- .694
1705.3
19.703- 7.284-
22,373 8.271
19.703- 7.284-
23.040 8.517
117
<667
<667
<667
<667
<334
<334
3.5
30.0
<0.6
2.2
1.6
<0.6
11.5
0.3
6.1
1.0
0
3
0-2669
53.8-
57.4
54-
2726
54-
3393 1
ng/J
0-.891
.019
.019-
.910
.019-
.133
-------
TABLE 14. TOTAL VOLATILE ORGANIC COMPOUND EMISSIONS
Boiler
Code*
C, PDB
C, PUB
C, CC
C. S
L, PDB
L, CC
Site
205-1
205-2
154
206
C2'C6
ng/J lb/109 Btu
Orl.587
0,1.605
1.551-2.178
16.508-16.978
212 0- .163
213
336
338
2)8
134
207
208
209
330
331
137
204
.122- .252
.367- .928
.713- 1.299
0- .621
.312- 1.510
0- .212
_-
0- .137
>7.56 -28.38
6.434- 7.819
0- .184
0- 1.817
332 5.487- 8.759
314 L.21 -14.90
315 1 0- 1.125
318
316
155
1.820- 3.049
0- 1.308
2.065- 2.605
0-3.7
0-3.7
3.6-5.1
38.4-39.5
0- .4
.3- .6
.8- 2.2
1.7- 3.0
0- 1.4
.7- 3.5
0- .5
--
0- .3
64.1-66.0
15.0-18.2
0- .4
0- 4.2
12,8-15.7
33.1-34.7
0- 2.6
4.2- 7.1
0- 3.0
4.8- 6.1
C7-C16
ng/J lb/109 Btu
.309
.466
.085
.411
.067
.040
.100
.360
.067
.343
.151
.0055
.081
.040
3.074
.126
.380
7.600
.148
.316
.258
.150
.056
.7
1.1
.2
1.0
.2
.1
.2
.8
.2
.8
.4
.01
.2
.0007
.01
.3
.9
17.7
.3
.7
.6
.3
.1
C2'C16
ng/J lb/109 Btu
.309-1.896
.466-2.072
1.635-2.263
16.917-17.389
.066- .230
.161- .293
.465 1.028
1.073 1-659
.067- .688
.655- 1.853
.150- .363
--
.079- .218
27.59 -28.42
9.508-10.89
.124- .310
.380- 2.197
13.09 -14.36
14.36 -15.05
.316- 1.441
2.077- 3.308
.150- 1.458
2.121- 2.661
.7-4.4
1.1-4.8
3.8-5.3
39.3-40.4
.2- .5
.4- .7
1.1- 2.4
2.5- 3.9
.2- 1.6
1.5- 4.3
.3- .8
--
.2- .5
64.2-66.1
22.1-25.3
.3. .7
.9- 5.1
30.4-33.4
33.4-35.0
.7- 3.4
4.8- 7.7
.3- 3.4
4.9- 6.2
C1"C16
ng/J lb/109 Btu
.309-2.214
.466-2.393
3.203-3.830
21.870-22.342
.682- .846
2.535- 2.667
.773- 1.335
1.512- 2.098
.662- 1.283
1-452. 2.651
.150- .405
.079- .245
27.67 -28.50
10.06 -11.45
,527- .713
.380- 2.560
13.66-14.93
14.82 -15.51
2.116- 3.241
2.712- 3.943
4.336- 5.645
3.012- 3.552
.7-5.2
1.1-5.6
7.5-8.9
50.9-52.0
1.6- 2.0
5.9- 6.2
1.8- 3.1
3.5- 4.9
1.5- 3.0
3.4- 6.2
.3- ..9
--
.2- .6
64.4-66.3
23.4-26.6
1.2- 1.7
.9- 6.0
31.8-34.7
34.5-36.1
4.9- 7.5
6.3- 9.2
10.1-13.1
7.0- 8.3
rv>
en
The first letter refers to feed type: C (coal); L (lignite); 0 (oil); and, G (gas).
The second group of letters refer to boiler type: PDB (pulverized dry bottom; PWB
(pulverized wet bottom; CC (cyclone); S (stoker); TF (tangentially-fired); and, WF
(wall-fired).
-------
TABLE 14. (Continued)
Boiler
Code
L,S
O.TF
O.WF
G.TF
G.WF
Site
317
319
210
211
322
323
105
109
118
119
305
324
141-3
113
114
115
106
108
116
117
VC6
ng/J lb/109 Btu
0 - 1.839
-
1.438- 2.601
0 - .135
0 - 1.264
11.82 -13.09
0 - 1.213
.799- 1.651
0 - 1.683
0 - 1.435
0 - 1.334
0 - .151
0 - 0.50
0 - .987
0 - 1.309
3.095- 3.949
-
6.651- 7.640
0 - .891
0 - 4.3
.
3.3- 6.0
0 - .3
0 - 2.9
27.5-30.4
0 - 2.8
--
1.9- 3.8
0 - 3.9
0 - 3.3
0 - 3.1
0 - .4
0 - 1.2
0 - 2.3
0 - 3.0
7.2- 9.2
-
15.5-17.8
0 - 2.1
C7"C16
ng/J lb/109 Bti
.355
.148
.056
.041
.071-
.009
10.84
1.889
.023
.034-
.022
.066
.023
.012
.012
.166
10.54
3.356
.694
.019
.8
.3
.1
.1
.2
.02
25.2
4.4
.05
.08
.05
.2
.05
.03
.03
.4
24.52
7.8
1.6
.04
C2"C16
ng/J lb/109 Btu
.355- 2.195
-
1.483- 2.647
.039- .176
.071- 1.335
11.83- 13.10
10.80- 12.05
--
.821- 1.675
.034- 1.716
.022- 1.457
.063- 1.400
.020- .147
.011- .51
.011- .999
.164- 1.475
13.64 -14.49
-
7.284- 8.271
.018- .910
.8 - 5.1
-
3.4 - 6.2
.1 - .4
.2 - 3.1
27.5 -30.5
25.1 -28.0
-
1.9 - 3.9
.08- 4.0
.05- 3.4
.1 - 3.3
.05- .3
.03- 1.2
.03- 2.3
.4 - 3.4
31.7 -33.7
_
16.9 -19.2
.04- 2.1
C1~C16
ng/J lb/109 Btu
1.337- 3.178
-
1.483- 2.819
.335- .471
1.007- 2.271
13.10- 14.37
16.87- 18.12
-
.827- 1.888
.034- 2.053
9.668-11.103
.223- 1.560
.020- .347
.011- .61
.011- 1.197
.164- 1.736
21.54 -22.40
-
7.284- 8.517
.018- 1.133
3.1 - 7.4
-
3.5 - 6.6
.8 - 1.1
2.3 - 5.3
30.5 -33.4
39.2 -42.1
-
1.9 - 4.'4
.08- 4.8
22.5 -25.8
.5 - 3.6
.05- .8
.03- 1.4
.03- 2.8
.4 - 4.0
50.1 -52.1
-
16.9 -19.8
.04- 2.6
*The first letter refers to feed type: C (coal); L (lignite); 0 (oil); and, G (gas).
The second group of letters refer to boiler type: PDB (pulverized dry bottom; PWB
(pulverized wet bottom; CC (cyclone); S (stoker); TF (tangentially-fired); and, WF
(wall-fired).
-------
TABLE 15. AVERAGED VOLATILE ORGANIC COMPOUND EMISSIONS
ro
CO
Fuel*
C
C
C
C
L
toiler*
Type
POB
PUB
CC
S
PDB
Alkane
Group
C2'C6
C7'C16
C2-C16
C1-C16
c2-c6
C7~C16
V0!!
c2-c6
C7-C16
C2~C16
C1"C16
C2'C6
C7'C16
VC16
crcie
c2-c6
C7"C16
C2"C16
crcie
X
pg/m3 lb/109 SCF
1.100- 3,769
599
1.696- 4.368
2.808- 5.925
6.316- 7.307
339
6703- 7696
10.040-11.033
15.937-17,545
1207
17.380-18,991
17,991-19.629
3.836- 5.949
5.622
9.457-11.571
10.100-12.438
14.743-17.189
596
15,338-17.785
17.907-20.354
69- 235
37
106- 273
175- 370
394- 456
21.2
418- 460
627- 689
995-1095
75
1085-1186
1123-1225
239- 371
351
591- 723
631- 777
920-1073
37
958-1110
1118-1271
X
ng/J lb/109 Btu
.52-1.80
.29
.80-2.08
1.32-2.81
2.95-3.37
.174
3.12-3.55
4.67-5.10
6.86-7.61
.62
7.60- 8.35
7.88- 8.65
1.83-2.92
2.70
4.53- 5.62
4.86- 6.07
5.34-6.36
.24
5.58-6.60
6.55-7.56
1.2- 4.2
.7
1.9- 4.8
3.1- 6.5
6.9- 7.8
.4
7.3- 8.3
10.9-11.9
16.0-17.7
1.4
17.7-19.4
18.3-20.1
4.3- 6.8
6.3
10.5-13.1
11.3-14.1
12.4-14.8
.6
13.0-15.4
15.2-17.6
s(-}
ng/J lb/109 Btu
.19
.11
.11
.51
2.73
.067
1.45
3.46
5.38
.49
5.39
5.37
1.98
2.45
4.40
4.46
4.31
.05
4.26
3.98
.4
.3
.3
1.2
6.3
.2
3.4
8.0
12.5
1.1
12.5
12.5
4.6
5.7
10.2
ib.4
10.0
.1
9.9
9.3
C. L. 0. and 6 refer to coal, lignite, residual oil. and gas. respectively.
tPDB means pulverized dry bottom. PUB - pulverized wet bottom; CC - cyclone;
S - stoker; TF r Tangentially-fired; and. HF - wall-fired.
-------
TABLE 15. (Continued)
ro
vo
Fuel
L
L
0
0
G
G
Boiler
Type
CC
S
TF
MF
TF
UF
Alkane
Group
c2-c6
VC16
VC16
Crci6
C2'C6
C7-C,6
crc!e
C2-C6
C7-C,6
Cl-Cl'l
C2-C6
C7'C16
Crci6
crc6
C7-C16
C2-C16
Crci6
c2-c6
C7-C16
V'l6
X
ug/m3 lb/109 SCF
2.551- 4,887
260
2.811- 5.147
9.251-11.587
0- 3.335*
457
643- 3,980
2.425- 5.762
7.051- 9.303
102
7.153- 9.406
8.621-11.040
500- 3,124
82
581- 3,194
5.145- 8.142
0- 2.780
168
164- 2,948
164- 3,504
9.000-11,669
880
9.880-12.550
9.880-13,216
159-305
16
175-321
578-723
0-208
29
40-248
151-360
440-581
6.4
447-587
538-689
31-195
5
36-199
321-508
0-173
10
10-184
10-219
562-728
55
617-783
617-825
X
ng/J lb/109 Btu
1.03-1.96
.10
1.14-2.06
3.67-4.60
0-1.84
.252
.36-2.20
1.34-3.18
3.31-4.27
.044
3.36-4,31
3.96-4.98
.16-1.25
0.033
0.19-1 .28
2.15-3.39
0-0.93
.033
.06- .99
.06-1.18
3.32-4.27
0.36
3.65-4.59
3.65-4.83
2.4- 4.6
.2
2.7- 4.8
8.5-10.7
0-4.3
.6
.8- 5.)
3.1- 7.4'
7.7- 9.9
.1
7.8-10.0
9.3-11.6
.4- 2.9
0.077
0.4- 3.0
5.0- 7.9
0- 2.2
.1
.1- 2.3
.1- 2.7
7.7- 9.9
0.8
8.5-10.7
8.5-11.2
s(x)
ng/J lb/109 Btu
.65
.05
.60
1.05
--
.10
--
2.93
.01
2.97
3.17
.28
.008
0.29
1.95
.24
.05
.28
.33
3.37
0.34
3.68
3.69
1.5
.1
1.4
2.4
--
.2
--
6.9
.02
6.9
7.4
.7
0.02
0.7
4.5
.6
.1
0.7
.8
7.8
0.8
8.6
8.6
Data based on only one site.
-------
Examination of the data presented indicated unusually high C2~C16 emis-
sions from bituminous coal-fired sites 206, 330, 331, and 332, lignite-fired
site 314, residual oil-fired sites 105 and 323, and gas-fired sites 106 and
116. For sites 105 and 106, the extremely high levels of organic materials
in the blanks for the XAD-2 resin and in the solvent blanks have rendered the
organic emission data unusable. Data from these two sites are, therefore,
not included in the determination of emission factors. For the remaining
sites associated with high Co^ie emissions, however, examination of the
field and laboratory operation data revealed no indication that these high
values are artifacts. A possible explanation for these higher emissions is
that in source testing of the EACCS program, no special readjustments of
burners at any of the sites were ever made. Therefore, some of the boilers
tested may be in poor operating condition with inefficient mixing between
air and fuel, and resulted in high organic emissions. Nevertheless, because
of the existence of a few high emission values which cannot be discarded as
outliers, the calculated average emission factors presented in Table 15 are
it
"biased" and not representative of VOC emissions from typical power plants .
Another method of data analysis was, therefore, used in determining repre-
sentative VOC emission factors.
In Figures 1 to 5, the reactive VOC emission data from Table 14 are
summarized in graphical form for each fuel type by plotting reactive VOC
emissions versus the cumulative frequency in the population sampled. Both
the maximum and minimum reactive VOC emission data are presented in the same
diagram. These minimum and maximum values are based on the detection limits
of the procedures employed. The minimum emission values were computed by
assuming all "less than" values in reported data as zero, whereas the maximum
emission values were computed by assuming upper limit values for all "less
than" values. Thus, the range in emission values represents data uncertainty
due to the low sensitivity of the field gas chromatograph used in determining
C,-Cg emissions. The true value is expected to lie between the minimum and
These average emission factors, however, are useful in determining total
emissions from all sources, which include both typical and atypical plants.
30
-------
s
u
Q
-------
z inn
m ' "
u
a. 90 -
9 80-
ĞP^
fğ 70
z
o
fr-t
fc 60-
a:
3
& 50
a.
z
U ^1 *
2 30
^J
s
^ 20
$
P 10
-------
y i nn _
z 100
u
(V
a 90-
*
_, QO-
i
-------
Q loo-
u
IV
o! 90
§ 60
4
-------
a I0°
u
90 H
Q
80
(L
"ğ 70 H
o
fe 6(H
50 H
u
a
u
30-
20-
10-
MflX EMISS
MIN EMISS
J
f->
0.00 0.25
0.50 0.75 1.00 1.25 1.50
VOC EMISSION FflCTOR, NONOGRflMS/JOULE
1.75 2.00
Figure 5. Cumulative graph of VOC data for gas-fired boilers.
-------
maximum values. For example, the plot 1n Figure 1 shows that between 42
and 63 percent of all bituminous coal-fired and lignite-fired pulverized
and cyclone boilers tested had reactive VOC emissions less than 1.58 ng/J
(equivalent to less than 100 tons/year). The same plot also shows that the
median value of the reactive VOC emission factor for these types of boilers
is between 0.47 and 1.85 ng/J. Similar information can be obtained from
Figures 2, 3, 4, and 5 for bituminous coal-fired, lignite-fired, oil-fired,
and gas-fired utility boilers, respectively.
Data presented in Figures 1 to 5 were used to determine total quantities
of reactive VOC's emitted annually from hypothetical 1000 MW power plants
fired with each type of fuel. The following assumptions were used:
Each power plant has a maximum rated capacity of 1000 MW.
Each power plant operates year-round at a load factor of 60%.
t Overall efficiency is 33 percent for each power plant,
regardless of fuel type.
a Median values of reactive VOC emission factors are represen-
tative of reactive VOC emissions from typical power plants.
On the above basis, the calculated reactive VOC emissions from typical 1000
MW power plants are as follows:
Fuel Type
i
Coal and Lignite
Coal
Lignite
Residual Oil
Gas
Med1an
Emission Factor
(ng/J)
0.47-1.85
0.47-1.85
0.38-2.65
0.03-1.48
0.01-1.00
Annual Reactive
VOC Emissions
(Tons/year)
30-117
30-117
24-168
2-94
1-63
Based on data from Figure 1, these are combined test data from bituminous
coal-fired and lignite-fired utility boilers, with the exception that all
stoker test data have been excluded.
36
-------
The percentage of hypothetical 1000 MW power plants with annual reactive
VOC emissions less than 100 tons/year can also be obtained from Figures 1
to 5. It was determined that 42 to 63 percent of coal- and lignite-fired
*
plants , 55 to 89 percent of residual oil-fired plants, and 80 percent of
gas-fired plants emit less than 100 tons/year of reactive VOC's.
Based on data from Figure 1, these are combined test data from bituminous
coal-fired and lignite-fired utility boilers, with the exception that all
stoker test data have been excluded.
37
-------
5. CONCLUSIONS AND RECOMMENDATIONS
Based on the emission data collected and analyzed by TRW and GCA at 43
coal-, lignite-, residual oil-, and gas-fired utility boilers, the following
conclusions can be reached:
Median values of reactive VOC emissions ranged between 0.47 and
1.85 ng/J for coal- and lignite-fired utility boilers, between
0.03 and 1.48 ng/J for residual oil-fired utility boilers, and
between 0.01 and 1.00 ng/J for gas-fired utility boilers. The
ranges in emission values represent data uncertainty due to the
low sensitivity of field gas chromatograph used in determining
Ci-Cg emissions. Comparison of these median emission values
indicates that reactive VOC emissions are highest for coal- and
lignite-fired sources, and lowest for gas-fired sources.
Five of the boilers sampled had reactive VOC emissions above'
10 ng/J. These higher emissions were probably due to burner
maladjustment with inefficient mixing between air and fuel, and
demonstrate the importance of proper maintenance.
The percentage of hypothetical 1000 MW power plants with annual
reactive VOC emissions less than 100 tons/year was 42 to 63
percent for coal- and lignite-fired sources, 55 to 89 percent
for residual oil-fired sources, and 80 percent for gas-fired
sources.
The Level I organic analysis procedure used provided data on emissions
of gaseous organics (C-|-Cg), volatile organics (Cy-C^), and nonvolatile
organics (>C^g). The gas chromatographic (GC) analyses performed were used
to obtain Information on the quantity of organic material boiling within
discrete ranges corresponding to the boiling points of the n-alkanes. Organic
emissions were classified solely on the basis of their retention time relative
to n-alkanes and were quantitated as n-alkanes. Thus, any oxygenated hydro-
carbons emitted were included in the reported Cg-C^ and >ci6 Va1ues as
n-alkane equivalents, although separate, quantitative determinations of the
oxygenated hydrocarbons were not made.
According to the Level I procedure, further organic analysis is conducted
only if the total organic concentration in the stack gas exceeds 500 ug/m .
38
-------
The additional analysis includes a class fractionation by liquid chromato-
graphy (LC), followed by gas chromatography (GC) and infrared (IR) analysis.
For LC fractions containing substantial quantities of organics (>500 yg/m ),
low resolution mass spectrometric (LRMS) analysis to determine compound
types was also performed. Examination of IR and LRMS analysis results
obtained in the EACCS program has indicated the presence of aldehydes/
ketones, carboxylic acids, alcohols, phenols, ethers, and esters in stack
emissions from utility boilers. However, these analysis techniques only
provide qualitative determination of the oxygenated hydrocarbons. If more
refinements in the current reactive VOC emission data base are desired,
additional work in the following areas are recommended:
Quantitative identification of oxygenated hydrocarbons using
specially designed Level II sampling and analysis procedures.
Monitoring of C-|-C6 emissions with high sensitivity gas
chromatograph in the field, so that emission data can.be
reported as exact values and not "less than" values due to
detection limit problems. This would result in more
accurate estimates of VOC emission factors.
Evaluation of the effects of boiler types and boiler operating
parameters on VOC emissions by a statistically designed
experimental matrix. This would result in the subgrouping of
VOC emission data and lead to better estimates of VOC emission
factors for each fuel/boiler subcategory.
39
-------
REFERENCES
1. Hamersma, J.W., D.G. Ackerman, M.M. Yamada, C.A. Zee, C.Y. Ung, K.T.
McGregor, J.F. Clausen, M.L. Kraft, J.S. Shapiro, and E.L. Moon. Emissions
Assessment of Conventional Stationary Combustion Systems: Methods and
Procedures Manual for Sampling and Analysis. Report prepared by TRW, Inc.,
for the U.S. Environmental Protection Agency. EPA-800/7-79-029a. January
1979.
2. Hamersma, J.W., S.L. Reynolds, and R.F. Maddalone. IERL-RTP Procedures
Manual: Level 1 Environmental Assessment. Report prepared by TRW, Inc.,
for the U.S. Environmental Protection Agency. EPA-600/2-76-160a. June
1976.
3. Memorandum from Tom Lahre to R.E. Neligan, March 12, 1979.
4. Volk, W. Applied Statistics for Engineers. New York, Mc-Graw Hill, Inc.
2nd Ed. P. 68-70, 110-112. 1969.
40
-------
TECHNICAL REPORT DATA
(Please read fatfructiom on the reverse before completing)
1. REPORT NO.
EPA-600/7-80-111
2.
3. RECIPIENT'S ACCESSION NO.
Ğ. TITLE ANDSUBTITLE
Emissions of Reactive Volatile Organic Compounds
from Utility Boilers
5. REPORT DATE
May 1980
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
Bernard Jackson, Lou Scinto, and Chris Shih
8. PERFORMING ORGANIZATION REPORT NO.
9. PERFORMING ORGANIZATION NAME AND ADDRESS
TRW, Inc.
One Space Park
Redondo Beach, California 90278
10. PROGRAM ELEMENT NO.
DUN120
11. CONTRACT/GRANT NO.
68-02-3138
12. SPONSORING AGENCY NAME AND ADDRESS
13. TYPE OF REPORT AND PERIOD COVERED
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND
Final; 8/79-4/80
14. SPONSORING AGENCY CODE
EPA/600/13
is. SUPPLEMENTARY NOTES ffiRL-RTP project officer is Wade
541-3997.
H. Ponder, Mail Drop 62, 919/
16. ABSTRACT
The report gives results of the measurement of emission factors for reac-
tive volatile organic compounds (VOC) from 43 utility boilers firing bituminous coal,
lignite, oil, and natural gas. The boilers ranged in size from 9 to 910 MW. The
median reactive VOC emission factors were determined to be between 0.47 and 1. 85
ng/J for coal- and lignite-fired sources (excluding stoker data); between 0. 03 and
1.48 ng/J for residual-oil-fired sources; and between 0.01 and 1.00 ng/J for gas-
fired sources. Approximately 50% of the coal- and lignite-fired plants and a majority
of the oil- and gas-fired plants were emitting reactive VOC below the 100-ton per
year level.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lOENTIFIERS/OPEN ENDED TERMS
COSATi Field/Group
Pollution
Boilers
Utilities
Emission
Organic Compounds
Volatility
Fossil Fuels
Pollution Control
Stationary Sources
Reactive Volatile Or-
ganic Compounds
13B
13A
14G
07C
20M
2 ID
18. DISTRIBUTION STATEMENT
Release to Public
19. SECURITY CLASS fThi] Report/
Unclassified
21. NO. OF PAGES
47
20. SECURITY CLASS (This page)
Unclassified
22. PRICE
EPA Form 2220-1 (9-73)
------- |