EPA-600/2-77-066a
March 1977
Environmental Protection Technology Series
INVENTORY OF COMBUSTION-RELATED
EMISSIONS FROM STATIONARY
SOURCES (First Update)
Industrial Environmental Research Laijoratory
Office of Research and S^elopnuiRl
U.S. Environmental Protection Agency
Research Triangle Park, North Carolina 27711
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RESEARCH REPORTING SERIES
Research reports of the Office of Research and Development, U.S. Environmental
Protection Agency, have been grouped into five series. These five broad
categories were established to facilitate further development and application of
environmental technology. Elimination of traditional grouping was consciously
planned to foster technology transfer and a maximum interface in related fields.
The five series are:
1. Environmental Health Effects Research
2. Environmental Protection Technology
3. Ecological Research
4. Environmental Monitoring
5. Socioeconomic Environmental Studies
This report has been assigned to the ENVIRONMENTAL PROTECTION
TECHNOLOGY series. This series describes research performed to develop and
demonstrate instrumentation, equipment, and methodology to repair or prevent
environmental degradation from point and non-point sources of pollution. This
work provides the new or improved technology required for the control and
treatment of pollution sources to meet environmental quality standards.
EPA REVIEW NOTICE
This report has been reviewed by the U.S. Environmental
Protection Agency, and approved for publication. Approval
does not signify that the contents necessarily reflect the
views and policy of the Agency, nor does mention of trade
names or commercial products constitute endorsement or
recommendation for use.
This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.
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EPA- 600/2 -77-066a
March 1977
INVENTORY
OF COMBUSTION-RELATED EMISSIONS
FROM STATIONARY SOURCES
(FIRST UPDATE)
by
Owen W. Dykema and Vernon E. Kemp
The Aerospace Corporation
Environment and Energy Conservation Division
ElSegundo, California 90245
Grant No. R803283-02
ROAPNo. 21ADG-089
Program Element No. 1AB014
EPA Project Officer: Robert E. Hall
Industrial Environmental Research Laboratory
Office of Energy, Minerals, and Industry
Research Triangle Park, NC 27711
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development
Washington, DC 20460
-------
ABSTRACT
T1.1 re-ort describes the first and second years of a study performed
dy The Aerospace Corporation to satisfy the Emissions Inventory phase of a
federal grant entitled "Analysis of NO Control in Stationary Sources. " The
X,
grant defines a three-year program covering the period 15 July 1974 to
14 July 1977. The purpose of this phase of the program is to assist the
Environmental Protection Agency in establishing priorities for detailed
studies of techniques for the control of combustion-related stationary source
atmospheric emissions of (1) oxides of nitrogen, (2) unburned hydrocarbons,
(3) carbon monoxide, and (4) particulate matter. The emissions inventoried
are to be not only from recognized major stationary combustion sources but
also from other stationary source categories in which combustion plays a
secondary role. During the first year of this study, emissions were established
for 1975 and projected to 1980 from boilers, internal combustion engines,
chemical manufacturing, and petroleum refining. In the second year, emis-
sions data for 1976 and 1981 were obtained for point-source evaporation and
primary metals industries, and the first year's inventory was expanded to
include 1976 and 1981. The third year of the study will cover mineral pro-
ducts, secondary metals, and wood products. This (second year) report
identifies approximately 68 percent of all participate emissions and from 93
to 97 percent of unburned hydiocarbons, carbon monoxide, and oxides of
nitrogen for stationary point sources.
This report is submitted by The Aerospace Corporation under spon-
sorship of the Environmental Protection Agency in partial fulfillment of Grant
Number R803283. The remainder of the grant involves an analysis of oxides
of nitrogen. The first-year results of the emissions inventory study have
been reported by Aerospace in Inventory of Combustion-Related Emissions
from Stationary Sources. EPA-600/7-76-012, dated September 1976.
11
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CONTENTS
ABSTRACT ii
ACKNOWLEDGMENTS xii
I. EXECUTIVE SUMMARY 1-1
1. 1 Introduction 1-1
1. 2 Study Summary 1-4
1. 3 Inventory Summary 1-14
1.4 Data Acquisition 1-83
1. 5 Data Handling and Storage 1-88
1. 6 References 1-93
II. EXTERNAL, COMBUSTION IN BOILERS 2-1
2. 1 Introduction 2-1
2. 2 Summary 2-3
2. 3 Approach 2-3
2. 4 Data Analysis ijrom Literature 2-41
2. 5 NEDS Data Analysis 2-48
2. 6 References 2-52
III. STATIONARY INTERNAL COMBUSTION ENGINES 3-1
3. 1 Introduction 3-1
3. 2 Summary 3-2
3. 3 Point Sources 3-2
3.4 Area Sources 3-21
3. 5 References 3-26,
iii
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CONTENTS (Continued)
IV. CHEMICAL MANUFACTURING 4-1
4. 1 Introduction 4-1
4. 2 Primary 4-1
4. 3 Emission Analyses. 4-15
4.4 References 4-37
V. PETROLEUM REFINERIES 5-1
5. 1 Introduction 5-1
5. 2 Summary 5-1
5. 3 Approach 5-1'
5. 4 General Refinery Statistics 5-16
5. 5 Processes Evaluated 5-18
5. 6 Results and Discussion 5-22
5. 7 Petroleum Refinery Practices 5-23
5. 8 References 5-28
VI. POINT SOURCE EVAPORATION 6-1
6. 1 Introduction 6-1
6.2 Summary 6-1
6. 3 Processes Evaluated 6-2
6.4 Emissions Analysis 6-42
6. 5 Emission Factors Derived from API Analysis 6-47
6.6 Comparison of API and EPA Emission Equations 6-54
6.7 Error of Emission Factors Based on API Analysis 6-56
6.8 References 6-57
VII. PRIMARY METALS 7-1
7. 1 Introduction 7-1
7.2 Summary , 7-1
IV
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CONTENTS (Continued)
7.-3 Processes Evaluated 7_2
7.4 Emissions Analysis 7-24
7. 5 References 7-26
APPENDICES
A. CONVERSION FACTORS A_l
B. GLOSSARY B_ 1
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FIGURES
1-1 1975 and 1980 Emissions from Stationary Sources 1-7
1-2 1976 and 1981 Emissions from Stationary Sources 1-8
3-1 Electric Utility Gas Turbine Fuel Demand 3-18
4-1 Emissions from Chemical Manufacturing 4-24
4-2 Synthetic Ammonia Production 4-27
4-3 Total Carbon Black Production 4-32
4-4 Breakdown of Carbon Black Production 4-33
6-1 Effects of Vapor "Pressure on Fixed-Roof Breathing
Losses 6-63
6-2 Effects of Tank Diameter on Fixed-Roof Breathing
Losses 6-64
6-3 Effects of Ullage Depth on Fixed-Roof Breathing
Losses 6-65
6-4 Effects of Daily Temperature Excursion on Fixed-Roof
Breathing Losses 6-66
VI
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TABLES
1-1. 1975 and 1980 Stationary Source Emissions 1-5
1-2. 19?6 and 1981 Stationary Source Emissions 1-6
1-3. 1975 Distribution of Point Source Emissions 1-10
1-4. 1976 Distribution of Point Source Emissions 1-11
1-5. 1975 and 1980 Uncertainties in Point Source
Emission Rates 1-12
1-6. 1976 and 1981 Uncertainties in Point Source
Emission Rates 1-13
1-7. Definition of Summary Categories 1-15
1-8-a. Summary of 1975 Emissions and Charge Rates 1-18
1-8-b. Summary of 1975 Emissions and Charge Rates
Uncertainty 1-23
1-9-a. Summary of 1980 Emissions and Charge Rates 1-29
1-9-b. Summary of 1980 Emissions and Charge Rates
Uncertainty 1-34
1-10-a. Summary of 1976 Emissions and Charge Rates 1-40
1-10-b. Summary of 1976 Emissions and Charge Rates
Uncertainty 1-50
i-ll-a. Summary of 1981 Emissions and Charge Rates 1-62
1-11-b. Summary of 1981 Emissions and Charge Rates
Uncertainty 1-72
1-12. Study List Emissions 1-84
vii
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TABLES (Continued)
2-1. Definition of External Combustion (Boiler) Processes 2-4
2-2-a. 1975 External Combustion Emissions and Charge Rates. . . . 2-8
2-2-b. 1975 External Combustion Uncertainties 2-11
2-3-a. 1980 External Combustion Emissions and Charge Rates ... 2-16
2-3-b. 1980 External Combustion Uncertainties 2-19
2-4-a. 1976 External Combustion Emissions and Charge Rates . . . 2-24
2-4-b. 1976 External Combustion Uncertainties 2-27
2-5-a. 1981 External Combustion Emissions and Charge Rates . . . 2-32
2-5-b. 1981 External Combustion Uncertainties 2-35
3-1. Definition of Internal Combustion Processes 3-3
3-2-a. 1975 Internal Combustion Emissions and Charge Rates .... 3-4
3-2-b. 1975 Internal Combustion Uncertainties 3-5
3-3-a. 1980 Internal Combusjion Emissions and Charge Rates .... 3-7
3-3-b. 1980 Internal Combustion Uncertainties ' 3-8
3-4-a. 1976 Internal Combustion Emissions and Charge Rates. ... 3-10
3-4-b. 1976 Internal Combustion Uncertainties 3-11
3-5-a. 1981 Internal Combustion Emissions and Charge Rates. . . . 3-13
3-5-b. 1981 Internal Combustion Uncertainties 3-14
3-6. Internal Combustion Engine Distribution: Number
Versus End Use 3-20
3-7. 1980 Projection of Total Internal Combustion Engine
Emissions « 3-22
3-8. 1980 Projection of Area Source Internal Combustion
Engine Emissions 3-23
vili
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TABLES (Continued)
4-1. Definition of Chemical Manufacturing 4-2
4-2-a. 1975 Chemical Manufacturing Emissions and Charge
Rates 4-3
4-2-b. 1975 Chemical Manufacturing Uncertainties 4-4
4-3-a. 1980 Chemical Manufacturing Emissions and Charge
Rates 4-6
4-3-b. 1980 Chemical Manufacturing Uncertainties 4-7
4-4-a. 19*76 Chemical Manufacturing Emissions and Charge
Rates 4-9
4-4-b. 1976 Chemical Manufacturing Uncertainties 4-10
4-5-a. 1981 Chemical Manufacturing Emissions and Charge
Rates 4-12
4-5-b. 1981 Chemical Manufacturing Uncertainties 4-13
4-6. Nationwide Point Source Emissions 4-16
4-7. Industrial Process Emissions 4-17
4-8. Producers of Greatest-Emissions in Chemical
Manufacturing 4-18
4-9. Producers of Greatest HC Emissions in Chemical
Manufacturing 4-19
4-10. Producers of Greatest CO Emissions in Chemical
Manufacturing 4-20
4-11. Summary of Chemical Manufacturing Emission
and Charge Rate 4-23
ix
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TABLES (Continued)
5-1. Definition of Petroleum Industry Processes. 5-c.
5-2-a. 1975 Petroleum Industry Emissions and Charge Rates .... 5-3
5-2-b. 1975 Petroleum Industry Uncertainties 5-4
5-3-a. 1980 Petroleum Industry Emissions and Charge Rates .... 5-6
5-3-b. 1980 Petroleum Industry Uncertainties. 5-7
5-4-a. 1976 Petroleum Industry Emissions and Charge Rates .... 5-9
5-4-b. 1976 Petroleum Industry Uncertainties 5-10
5-5-a. 1981 Petroleum Industry Emissions and Charge Rates .... 5-12
I
5-5-b. 1981 Petroleum Industry Uncertainties 5-13
5-6. 1973 Distribution of Petroleum Products 5-17
6-1. Definition of HC Evaporation 6-3
6-2-a. 1976 HC Evaporation Emissions and Charge Rates 6-7
6-2-b. 1976 HC Evaporation Uncertainties 6-13
6-3-a. 1981 HC Evaporation Emissions and Charge Rates 6-23
6-3-b. 1981 HC Evaporation Uncertainties 6-29
6-4. Evaporation from Service Stations: Gasoline
Transferred Charge Rates and Emissions 6-43
6-5. Vapor Pressure Effects on Fixed-Roof Breathing
Losses 6-59
6-6. Diameter Effects on Fixed-Roof Breathing Losses 6-60
6-7. Ullage Depth Effects on Fixed-Roof Breathing Losses .... 6-61
6-8. Temperature Excursion Effects on Fixed-Roof
Breathing Losses 6-62
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TABLES (Continued)
7-1. Definition of Primary Metals Processes 7-1
7-2-a. 1976 Primary Metals Emissions and Charge Rates 7-6
7-2-b. 1976 Primary Metals Uncertainties 7-9
7-3-a. 1981 Primary Metals Emissions and Charge Rates 7-14
7-3-b. 1981 Primary Metals Uncertainties 7-17
XI
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ACKNOWLEDGMENTS
Robert E. Hall, the Environmental Protection Agency (EPA)
Project Officer, Combustion research Branch, is acknowledged for his
guidance during this study and for his assistance in the data collection process,
The efforts of EPA personnel Jacob Summers and Martha Abernathy of the
National Air Data Branch are acknowledged for providing magnetic tapes con-
taining point source emission data from the National Emissions Data
Systems (NEDS).
The following personnel of The Aerospace Corporation made
valuable contributions to the performance of this study:
Keith W. Aaron
t
Siumay Cheung
Otto Hamberg
Norman E. Kogen
Robert B. Laube
Patricia L. Merryman
Elliot K. Weinberg
Herbert M. White
The overall emissions inventory project was managed by
Owen W. Dykema, and the pro;°,ct coordination and organization of this
report was accomplished by Vernon E. Kemp.
Office of Stationary Systems
Environment and Energy
Conservation Division
^a^^^-
Toru lura, General Manager
Environment and Energy
Conservation Division
Civil Operations
Xll
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SECTION I
EXECUTIVE SUMMARY
1. 1 INTRODUCTION
1.1.1 Background
A cost-effective approach to nationwide reduction of air pollution
requires an accurate assessment of the air pollutants being discharged into the
atmosphere by combustion-related processes and other related activities. Since
there is a long lead time between the recognition of a large source of air pollu-
tion and the implementation of control methods, it is further required that the
magnitude of these emissions be estimated for an appropriate time in the future.
Studies of specific industries have been and are being con-
ducted. Because the sources of air pollution are numerous and geographically
scattered, few studies have involved the gathering of significant samples of
measured emission data. Most tend to review, analyze, summarize, and pro-
ject the same data.
The National Emissions Data System (NEDS) of the U.S.
Environmental Protection Agency (EPA) has generated a large volume of
detailed, measured emission data, covering a wide range of industries. Most
of these data were gathered in the 1970 through 1972 time period. Efforts
to update the data base are continuing. However, as of 1975, the NEDS data
were incomplete, contained some errors, and represented data from an
average time period of about 1971. The NEDS contains no means for pro-
jecting the data beyond the acquisition period. Despite these drawbacks, the
NEDS has the largest, most comprehensive, and detailed sample of original
emission data available.
1-1
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The other studies containing original data surveys serve as a
check on the completeness of the NEDS data and provide the rationale for
projection of the data into the future.
1.1.2 Scope
The purpose of this strrly, which is part of a three-year program,
is to assist the EPA in establishing priorities for combustion-related detailed
air pollution control studies. The atmospheric pollutants of interest are oxides
of nitrogen (NO ) unburned hydrocarbons (HC), particulate matter (PART), and
5C
carbon monoxide (CO). The study utilizes the NEDS original emission data
base, as well as original data obtained from individual studies, to generate
a detailed inventory of emissions, with projections to the early 1980s.
The nationwide emissions inventory compiled by this study is
limited to atmospheric point source emissions. Point sources are defined as
stationary sources contributing more than 100 tons per year of pollutant.
Area sources, i.e., stationary sources of pollution exclusive of point sources,
are considered only in cases where a point source is likely to develop.
The industries from which the emissions of interest emanate
are referred to as process or source categories and are classified under the
NEDS Source Classification Code (SCC). A detailed breakdown of these source
categories is further defined by the Modified SCC (MSCC) developed by The
Aerospace Corporation for this study. The emissions inventoried during the
first year of the study, reported here, are from the following major source
categories: external combustion in boilers, internal combustion, chemical
manufacturing, and petroleum refineries. Evaporation and primary metals
emissions were studied in the second year of the program; emissions from
mineral product, secondary metal, and wood product industries will be
investigated in the third year.
Uncertainty values are given for the current emission
estimates and for emission projections to the early 1980s. The variables
determining these values are process usage rates, emission factors, control
applications, and time derivatives or trends. Statistical engineering
1-2
-------
estimates, current and potential legislative controls, and several independent
sources of data were considered in calculating the uncertainty of each of the
emissions inventoried.
1.1.3 Objectives
The objectives of this study are as follows:
a. Establish current and future five-year estimates of significant
nation-wide atmospheric stationary point source emissions of
particulates, NO , HC, and CO, particularly from industries
involving combustion.
i,
b. Determine the uncertainty of current and future emission rates.
1.1.4 Approach
The objectives of the study were accomplished by the perfor-
mance of the following tasks:
a. Establish a list of processes which yield a significant
quantity of atmospheric emissions. The selection of
processes and subprocesses is described in Sections
1.4. 1 and 1.4.2.
b. Determine a data base (starting point) and slopes for
time-dependent variables from which current and future
emissions can be calculated. Accomplishment of this task
for each process is described in Sections II through VII.
c. Establish and code equations, for computer usage, which
allow emissions and their uncertainties to be estimated
for the year of interest. Section 1. 5 describes these
equations.
d. Calculate and publish emissions for the current year and
the fifth year hence. The detailed results of these calculations
are listed for each process in Sections II through VII. The
summarized results are published in Section 1. 3.
1.1.5 Organization of Report
The Executive Summary section presents (1) an overview of the
study and a concise review of the significant results; (2) an inventory summary
of the 1975, 1976, 1980, and 1981 emissions, charge rates, and uncertainties
for the broadest categories of the process studies; and (3) a description of
1-3
-------
the data acquisition techniques and the methods used to perform the
computational analyses. Each of the major processes stv 'ied in the emis-
sions inventory is presented separately in Sections II through VII. For the
convenience of selective users, these sections are independently oriented.
The overall study is a three-year effort scheduled to continue
to July 1977. Each year, a selected industry, process, or group of sources
is studied. Also, during th^ ':hird year, the inventory of the previous two
years will be updated. The basic report will be revised annually during the
course of the study, with subsequent inventories and updates of previous
inventories incorporated.
Metric equivalents for English units used in this report are
listed in the conversion table in Appendix A. A glossary of terms is pro-
vided in Appendix B.
1. 2 STUDY SUMMARY
A summary of the stationary point source emissions inventory
conducted in the first and second years of this program is given in Table 1-1
for 1975 and 1980 ard in Table 1-2 for 1976 and 1981, respectively; a summary
of all stationary source emissions is shown in Figures 1-1 and 1-2. The gen-
eral trend of reduced emissions--or, at worst, small increases--over the next
five years is attributed to increased compliance with new standards during
this period even though industrial production is expected to increase appreci-
ably. The most noteworthy emission rate determined is the 1975 CO value
from petroleum refineries, which is 17-million tons per year. This number
is approximately four times that reported in any of the recent NEDS nation-
wide emission summary reports. The difference is attributed partially to the
emission factors used in computing emissions from fluid catalytic
cracking processes, but the exact cause for the difference is unresolved at
this writing.
As shown in Table 1-3, which identifies the contribution of
the inventoried emissions to the total point source emissions, approximately
95 percent of the NO and 28 to 53 percent of the HC, CO, and PART are
1-4
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Table 1-1. 1975 AND 1980 STATIONARY SOURCE EMISSIONS
Source Category
Steam Boilers:
1975
1980
Internal Combustion Engines:
1975
1980
Chemical Manufacturing:
1975
1980
3
Petroleum Refineries :
1975
1980
Internal Combustion Engines:
1980
Emissions, million tons/yrc
N0x
7.59
6.22
0.60
0.57
Neg
Neg
0.56
0.38
2.96
HC
0. 15
0. 19
0.35
0.42
1.08
1.13
0.41
0.45
0.99
CO
0.37
0.44
Neg
Neg
2.63
2.76
17.04
11.61
13.57
PART
5.58
5.68
Neg
Neg
Neg
Neg
0.30
0.24
Nog
aPoint source: more than 100 tons per year of pollutant.
Area source: all stationary sources exclusive of point sources.
GNeg is defined as less than 1% of the NEDS 1975 stationary source
emissions.
i-5
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Table 1-2. 1976 AND 1981 STATIONARY SOURCE EMISSIONS
Source Category
Steam Boilers
1976
1981
Internal Combustion Engines
1976
1981
Chemical Manufacturing
1976
1981
Petroleum Refireries
1976
1981
Primary Metals
1976
1981
Evaporation Point Source
1976
1981
Area Source
1976
1981
Emissions, million tons/yr
NO
X
7. 37
5.88
0.60
0.56
Neg
Neg
0. 52
0.35
0.01
0. 01
Neg
Neg
Neg
Neg
HC
0. 16
0.20
0.36
0.43
1.09
1.14
0.42
0.46
0.20
0.20
4. 24
2.43
0.63
0. 14
CO
0. 39
0.46
Neg
Neg
2.65
2. 79
16.09
10. 32
11. 35
6.66
Neg
Neg
Neg
Neg
PART
5.65
5. 62
Neg
Neg
Neg
Neg
0. 29
0. 22
1.55
0. 71
Neg
Neg
Neg
Neg
"Neg" is defined as less than 1% of the 1975 NEDS value for that emission.
Retail service stations.
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* LESS THAN 1% OF NEDS 1975
STATIONARY SOURCE EMISSIONS
6
4
2
0
OXIDES OF NITROGEN
* #
1975 1980 1975 1980 1975 1980
STEAM INTFRNAL CHEMICAL
BOILERS COMBUSTION MANUFACTURING
ENGINES
1975 1980
PETROLEUM
REFINERIES
1975
OTHER POINT
SOURCES
1975
AREA SOURCES
Figure 1-1. 1975 and 1980 emissions from stationary sources
-------
8
6
4
2
>-«•
i
00
0
< 6
UJ
LU 4
Q.
on
1 2
U_
o 0
o*>
0
E± 16
>X 12
— 8
en
on
s 4
'
\ i
|
1
ISSSaS
T?3
'^ '
•• >•'>
~f •
n,nj ,,
I I
1
1976 1981 1976 1981 1976 1981 1976 1981
STEAM INTERNAL CHEMICAL PETROLEUM
BOILERS COMBUSTION MANUFACTURING REFINERIES
*
-------
accounted for in the initial inventory. When the second year inventory is
included, 93 to 97 percent of the NO , HC, and CO emissions are accounted
-X
for and 68 percent of the PART (Table 1-4). Most of the remainder will be
inventoried during the third year of this program, which will be concerned
with mineral product, secondary metal, and wood product emissions.
The uncertainties of the 1975 and 1980 point source emissions
were computed and are presented in Table 1-5. Table 1-6 shows similar
data for 1976 and 1981. As shown, significant uncertainties in emission rate
predictions exist for CO from petroleum refineries. Expressed as a percent-
age of the nominal value of the predicted emissions, the uncertainty of 1975
CO emissions from refineries is approximately 35 percent. This large uncer-
tainty is due to the lack of substantiated emission factor data for fluid catalytic
cracking facilities. Refinements in data are expected to significantly reduce
this uncertainty in the updates planned for the third year of the study.
Significant quantities of NO , HC, and CO emissions are pre-
3t
dieted for stationary area source internal combustion (1C) engines which far
exceed the emissions attributed to present point source 1C engines. The dif-
ference in emissions is attributed to 1C engines whose usage, emission factor,
or size is too small to qualify them as point source emitters and consequently
are classified as area source emitters. The four highest polluting 1C engines
contributing to area source emissions were studied because many are in a
standby installation and, with a modest increase in usage, could become point
sources of significant quantities of emissions. These four offenders ave
(1) distillates, (2) crude-oil-fueled turbines, (3)diesel engines, and (4) gasoline -
fueled reciprocating engines. A detailed description of these area source
emissions is presented in Section 3.4. The gasoline engine contributes the
largest amount of NO , HC, and CO, particularly CO whose rate of 13 million
3f
tons per year is two orders of magnitude greater than that of any other area
source emission from 1C engines. Since the primary objective was to establish
an inventory of point source emissions, area source emissions are not included
in the basic inventory as summarized in Section 1. 3
1-9
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Table 1-3. 1975 DISTRIBUTION OF POINT SOURCE EMISSIONS
Percent of Total Point Source Emissions'
^urce Category
NO
x
HC
CO
PART
Steam Boilers
Internal Combustion Engines
Chemical Manufacturing
Petroleum Refineries
81
6
2
6
2
5
15
6
1
Neg
7
45
41
Neg
2
2
Total Initial Inventory
Other Point Sources
95
5
28
72
53
47
46
54
Total Point Sources
100
100
100
100
Neg is less than 0. 5%
1-10
-------
Table 1-4. 1976 DISTRIBUTION OF POINT SOURCE EMISSIONS
Source Category
Steam Boilers
Internal Combustion Engines
Chemical Manufacturing
Petroleum Refineries
Primary Metals
Point Source Evaporation
Percent
NO
X
82
7
2
6
Neg
Neg
et
of Total Point Source Emissions
HC
2
5
16
6
3
61
CO
1
Neg
8
49
35
Neg
PART
39
Neg
2
2
25
Neg
Total Emissions
Inventoried During
First and Second
Year of Study
Other Point Source
Emissions0
97
93
93
68
32
Total Point Source
Emissions
100
100
100
100
a"Neg" is defined as less than 0. 5%.
Based on data listed in the NEDS summary report, dated January 1, 1976.
1-11
-------
1-5. 1975 AND 1980 UNCERTAINTIES IN >OINT
SOURCE EMISSION RATES
Emissions, million tons/yra
Category
NO
x
HC
CO
PART
Steam Boilers
1975
1980
Internal Combustion Engines
1975
1980
Chemical Manufacturing
1975
1980
Petroleum Refineries
1975
1980
+ 0.42
-0.42
+ 0.85
-0.81
+0.39
-0. 14
+0.42
-0. 18
Neg
Neg
+0.03
-0.03
+0.03
-0.03
+0. 10
-0.02
+0. 12
-0.03
+0. 18
-0.08
+0.26
-0. 11
+0. 10
-0. 10
+0. 11
-0. 11
+0.04
-0.04
+0.05
-0.05
+0.08
-0.05
+0. 10
-0.07
Neg
Neg
+0.37
-0.37
+0.43
-0.43
+5.89
-5.89
+6.72
-6.72
+0.47
-0.47
+0.87
-0.87
Neg
Neg
Neg
Neg
+0.01
-0.01
+0.02
-0.02
Neg corresponds to the nominal emission equaling less than 1% of total
stationary source emissions.
1-12
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Table 1-6. UNCERTAINTIES IN 1976 AND 1981 POINT
SOURCE EMISSIONS
Source Category
Steam Boilers
1976
1981
Internal Combustion Engines
1976
1981
Chemical Manufacturing
1976
1981
Petroleum Refineries
1976
1981
Primary Metals
1976
1981
Evaporation
1976
1981
Emission
NO
X
+0.50
-0.50
+0.95
-0.90
+0.40
-0. 14
+0.43
-0. 18
Neg
Neg
Neg
Neg
+0. 03
-0. 03
+0.03
-0. 03
+0.00
-0. 01
+0.00
-0.01
Neg
Neg
Neg
Neg
Uncertainty, million
HC
+0. 10
-0.02
+0. 13
-0.03
+0. 19
-0. 06
+0. 28
-0. 13
+0.10
-0. 10
+0. 12
-0. 12
+0.04
-0.04
+0.05
-0.05
+0. 02
-0. 05
+0.04
-0. 12
+0.46
-0.45
+0. 58
-0.46
CO
+0.08
-0.06
+0. 11
-0.07
Neg
Neg
Neg
Neg
+0. 37
-0.37
+0.46
-0.45
+6.05
-6.05
+6.88
-6.88
+1.29
-1.29
+3. 65
-2. 58
Neg
Neg
Neg
Neg
tons/yr
PART
+0.53
-0.53
+0. 97
-0. 97
Neg
Neg
Neg
Neg
,Neg
Neg
Neg
Neg
+o. n
-0. H
+0. 02
-0. 02
+0.40
-0.29
+0.15
-0. 12
Neg
Neg
Neg
Neg
l"Neg" is defined as the nominal emission equaling less than 1% of total
stationary sources.
1-13
-------
The HC emissions lost to the atmosphere by evaporation were
estimated to be 4. 25-million tons in 1976 and are expected to be reduced to
2. 5-million tons in 1981. The projected reduction is primarily due to
improved storage facilities for petroleum products.
1.3 INVENTORY SUMMARY
The categories studied are classified and summarized under
the processes contributing the stationary source emissions of interest. In
able 1-7, the major process categories investigated are listed and defined
according to the NEDS Modified Source Classification Code (MSCC) and charge
rate unit. The 1975 and 1980 emissions are summarized by major process
category in Tables 1-8-a and 1-9-a, respectively. The respective uncertain-
ties for these emissions are given in Tables 1-8-b and 1-9-b. Similar data
are presented for 1976 and 1981 in Tables 1-10 and 1-11, respectively.
In these tables, three levels of summarization are defined by
the NEDS nine-digit MSCC number. The first, most general, summary level
is indicated by the first digit of the MSCC. The emissions listed in the first-
level summary categories are the sum of those in the second-level summary, j
and those in the second level are the sum of those in the third level. Second-
level categories are indicated by the second and third digits in the MSCC,
and the third-level summary categories by the numbers in the fourth, fifth,.
and sixth digits.
No charge rates are listed for the first level and only a few for
the second-level summary categories because these categories represent
different types of processes with different units of measure. For example,
the second-level summary category 101000000 represents all external com-
bustion for boilers used in electric generation including those burning coal in
tons per year, oil in thousands of gallons per year, and natural gas in mil-
lions of cubic feet per year. In some cases, third-level summaries involve ;
a single process type with the same unit, e.g., 101002000, bituminous coal
in tons per year. In such cases, the appropriate MSCC unit of measure is
shown in Table 1-7, and a charge rate for this unit is listed in Tables 1-8
through 1-11.
The major source categories summarized here are further
classified and detailed in Sections II through VII.
(Continued on page 1-83)
1-14
-------
Table 1-7. DEFINITION OF SUMMARY CATEGORIES
MSCC
Source Category
Charge Rate Unit
100000000
External Combustion (Boiler)
101000000
101002000
101004000
101005000
101006000
101007000
102000000
Electric Generation
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
Industrial
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
102002000
102004000
102005000
102006000
102007000
200000000
201000000
201001000
201002000
201003000
201999000
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
Internal Combustion
Electric Generation
Distillate oil
Natural gas
Diesel
Miscellaneous fuel
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
•
1000 gal/yr
Million cu ft/yr
1000 gal/yr
N.A.
202000000
Industrial 1C Engines
202001000
202002000
202003000
202004000
202999000
300000000
301000000
301002000
Distillate oil turbine
Distillate oil reciprocating
Natural gas turbine
Natural gas reciprocating
Miscellaneous fuels"
Industrial Processes
Chemical Manufacturing
Ammonia production with
methanator
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Tons/yr
1-15
-------
Table 1-7. DEFINITION OF SUMMARY CATEGORIES (Continued)
MSCC
301003000
301005000
301999000
303000000
303001000
30300ZOOO
303003000
303004000
303005000
303006000
303007000
303008000
303009000
303010000
303011000
303012000
303030000
303999000
306000000
306001000
306002000
306003000
306008000
306012000
Source Category
Ammonia production with CO absorber
Carbon black production
xvliscellaneous chemical manufacturing
Primary Metals
Aluminum reduction
Aluminum ore calcined
Coke metallurgical
Coke beehive
Copper smelters
Ferroalloy production (open furnace)
Ferroalloy production (closed furnace)
Iron production
Steel production
Lead smelters
Molybdenum
Titanium
Zinc smelting
Miscellaneous metallurgical processes
Petroleum Industry
Process heater
Fluid catalytic crackers
Moving bed catalytic crackers
Miscellaneous leakage
Fluid coking
Charge Rate Unit
Tons/yr
Tons/yr
Tons/yr
N. A.
Aluminum, tons/yr
Tons/yr
Coal, tons/yr
Coal, tons/yr
N.A.
Tons/yr
N.A.
Tons/yr
N.A.
N.A.
N.A.
Tons/yr
Tons/yr
N.A.
1000 bbl/yr
1000 bbl/yr
Capacity, 1000 bbl/yr
Feed, 1000 bbl/yr
1-16
-------
Table 1-7. DEFINITION OF SUMMARY CATEGORIES (Continued)
MSCC
400000000
401000000
401001000
401002000
401999000
402000000
402001000
402002000
402003000
402004000
402005000
402006000
402007000
402008000
402999000
403000000
403001000
403002000
403003000
403999000
406000000
406001000
406002000
Source Category
Point Source Evaporation
Cleaning Solvents
Dry cleaning
Degreasing
Miscellaneous solvent use
Surface Coating
Paint
Paper coatings
Varnish and shellac
Lacquer
Enamel
Primer
Fabric coatings
Oven coatings
Miscellaneous coatings
Petroleum Storage
Fixed roof
Floating roof
Variable vapor space
Miscellaneous storage
Petroleum Marketing and Transportation
Rail and truck transportation
Marine vessel transportation
Charge Rate Unita
N.A.
N.A.
Clothes, tons/yr
Solvent, tons/yr
Solvent, tons/yr
C oating , tons / y r
C oating , tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr j
Coating, tons/yr j
Coating, tons/yr ;
N.A.
N.A.
N.A.
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
aN. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
b Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
1-17
-------
Table 1-8-a. SUMMARY OF 1975 EMISSIONS AND CHARGE RATES
ANNUAL CHARGE
EXTERNAL COMBUSTION, BOILER CATEGORY PAGE 1
RATES AND EHISSIOHS PROJECTED TO 1975 RUN DATE- NAR 22*1977
00
MODIFIED
sec
100000000
101000000
101002000
101006000
101007000
102000000
102002000
18*881888
mmm
TACRP EHISSI
CSCC UNITS) NOX
7.591
6.237
389250000. 4.197
18210000. .567
0. 0«OQO
2993400. ,673
90390. ,000
1.354
57234000. .592
mm- -m
MSCC Source Category
ONS tHILLIONS OF TONS /
HC CO
.147 .371
.090 .252
.070 >199
0*000 0*000
.001 .025
NEGLIGIBLE NEGLIGIBLE
.057 .119
.023 .051
NEGLlB?iLE NEGLl2?SlE
Charge Rate Unit
fEAR)
PART
5.579
4.301
4.205
0*000
.022
NEGLIGIBLE
1.279
1.055
:H!
NEGLlEflLE
100000000 External Combustion (Boiler)
i
101000000 Electric Generation
101002000 Bituminous coal
101004000 Residual oil
101005000 Distillate oil
101006000 Natural gas
101007000 Process gas
102000000 Industrial
102002000 Bituminous coal
102004000 Residual oil
102005000 Distillate oil
102006000 Natural gas
102007000 Process gas
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
-------
Table 1-8-a. SUMMARY OF 1975 EMISSIONS AND CHARGE RATES (Continued)
INTERNAL COMBUSTION ENGINES
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1975
RUN DATE'
MODIFIED
SCC
200000000
201000000
201001000
201999000
TACRP
EMISSIONS (MILLIONS OF TONS /
PAGE 1
MAR 22,1977
YEAR*
CSCC UNITS)
1083100.
MSCC
200000000
201000000
201001000
201002000
201003000
201999000
NOX
.604
.244
.120
• Oil
• 017
Source Category
Internal Combustion
Electric Generation
Distillate oil
Natural gas
Diesel
Miscellaneous fuel
HC CO
.348 .067
.086 .016
.002 .010
•QQ1 »PPP
•331 .905
.083 .002
Charge Rate Unit
1000 gal/yr
Million cu ft/yr
1000 gal/yr
" N.A.a
PART
.017
• Oil
.008
Vooi
.-;•'<
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table i-8-a. SUMMARY OF 1975 EMISSIONS AND CHARGE RATES (continued)
INTERNAL COMBUSTION ENGINES
ANNUAL CHARGE RATES AND EMISSIOfcS PROJECTED TO 1975
RUN DAT
MO
DIFIED
202000000
)1000
202004000
202999000
TACRP
CSCC UNITS)
65953.
973960.
3470.
26201.
23828.
_ EMISSIONS (MILLIONS OF
NOX HC
.360
.004
.348
.000
.005
.003
261
000
089
000
000
172
TO
CO
.051
.002
:8S!
.002
.001
PAGE 2
MAR 22*1977
MS / YEAR)
PART
.006
.001
• ""
.000
.000
i
o
MSCC
Source Category .
202000000 Industrial 1C Engines
202001000 Distillate oil turbine
202002000 Distillate oil reciprocating
202003000 Natural gas turbine
202004000 Natural gas reciprocating
202999000 Miscellaneous fuels a
Charge Rate Unit
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table 1-8-a. SUMMARY OF 1975 EMISSIONS AND CHARGE RATES (Continued)
tSJ
INDUSTRIAL PROCESS* CHEMICAL MANUFACTURING
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1975 RUN DATE'
MODIFIED
SCC
301000000
301005000
301999000
TACRP
(SCC UNITS!
8WM88:
6054400.
151180000.
NOX
NEGLIGIBLE
IfElKfflf
NEGLIGIBLE
NEGLIGIBLE
EMISSIONS CMILHONS OF TONS /
HC CO
PAGE 1
MAR 22*1977
1TEAR)
1.030
2.625
.322
.518
2.241
.336
PART
NEGLIGIBLE
HfStiSIKf
NEGLIGIBLE
NEGLIGIBLE
MSCC
Source Category
Charge Rate Unit
300000000
Industrial Processes
301000000 Chemical Manufacturing
301002000 Ammonia production with Tons/yr
methanator
301003000 Ammonia production with CO Tons/yr
absorber
301005000 Carbon black production Tons/yr
301999000 Miscellaneous chemical Tons/yr
manufacturing
-------
Table 1-8-a.. SUMMARY OF 1975 EMISSIONS AND CHARGE RATES (Continued)
I
IV
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
ANNUAL CHARGE RATES AND EMISSIOKS PROJECTED TO 1975 RUN DATE'
MO
m
IEO
306000000
306001000
306002000
306003000
1500000*
108500.
"H8888:
NOX
.557
.507
.050
NEGLIGIBLE
fi
ttilt
ic"
ILLIONS OF
,407
.045
.170
.005
mu
J8"
PAGE 1
MAR 22,1977
1 ' ""W
.302
.034
16.300
.210
.095
.180
NEGLIGIBLE
NEGLIGEE
MSCC
Source Category
Charge Rate Unit
306000000 Petroleum Industry
306001000 Process heater
306002000 Fluid catalytic crackers
306003000 Moving bed catalytic crackers
306008000 Miscellaneous leakage
306012000 Fluid coking
N.A.a
1000 bbl/yr
1000 bbl/yr
1000 bbl
capacity/yr
1000 bblfeed/yr
aN.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table i-8-b. SUMMARY of 1975 EMISSIONS AND CHARGE RATES UNCERTAINTY
EXTERNAL
COMBUSTION, BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1975
MODIFIED
sec
100000000
101000000
101002000
101004000
101005000
101006000
101007000
TACRP
tSCC UNITS)
* 11708000.
11708000.
* 2111300.
— 2111300.
+ <^Ai*"g;
+ 590090*1
* 5???I8.
15220.
EMISS
NOX
* .417
- .418
+ .366
- .386
+ .348
- .348
* .094
— .0<24
* o:sa3
- 0.000
«• .139
* ri38
- toco
IONS (MILLI
HC
* .099
- .0,20
* .097
- .015
* .097
- .014
* .008
— .006
* olooo
I °*RR?
+ .001
NEGLfiFiLE
NEGLIGIBLE
PAGE 1
RUN DATE- NAR 22*1977
ONS OF
*
-
4,
—
•f
4-
* 0
- 0
*
NEGL
NEGL
TONS /
CO
.077
.052
.071
.048
.069
.046
.012
. 000
IG?|LE
IGIdLE
YEAR)
PART
* .471
- .471
+ .431
- .431
* .431
- .431
+ .008
— nna
* o:88E
- 0.000
* .004
NEGL!S?BLE
NEGLIGIBLE
MSCC
Source Category
Charge Rate Unit
100000000
101000000
101002000
101004000
101005000
101006000
101007000
External Combustion (Boiler)
Electric Generation
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million Cu ft/yr
-------
Table 1-8-b. SUMMARY OF 1975 EMISSIONS AND CHARGE RA.ES
UNCERTAINTY (Continued)
EXTERNAL COMBUSTION,
TACR AND EMISSION UNCERTAINTIES PROJECTED
BOILER CATEGORY
TO 1975 RUN
DATE* MAR
PAGE 2
22,1977
HONIED
102000000
TS)
102002000 +
102004000 +
102005000 *
102006000 +
102007000 *
1140100.
1140100.
838110.
838110.
!8!i!8:
142990.
142990.
NOX
.158
.160
.016
.013
,03f
.022
.190
.190
-* 'M
+
*
.093
.093
8060
.060
.<
.i
.000
.000
*
+
*
*
.010
.007
.006
.004
.012
.009
.008
.006
• .013
- .013
+ .006
- .006
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
MSCC
Source Category
Charge Rate Unit-
102000000
102002000
102004000
102005000
102006000
102007000
Industrial
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
Tons burned/yr
1000 gal/yr
1000?gal/yr.
Million cu ft/yr
Million cu ft/yr
-------
Table 1-8-b.
SUMMARY OF 1975 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
INTERNAL COMBUSTION ENGINES
TACR AND EH1SSIQN UNCERTAINTIES PROJECTED TO 1975
RUN DATE'
MODIFIED
SCC
200000000
201000000
TACRP
-------
Table i-8-b.
I
IV
SUMMARY OF 1975 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
INTERNAL COMBUSTION ENGINES
PAGE 2
IACK AND EMISSION UNCERTAINTIES PROJECTED TO 1975 RUN DATE- H
MODIFIED
sec
202000000
202001000
202002000
202003000
202004000
202999000
I
.
TACRP
CSCC UNITS)
«•
+ 6
•*•
•f
•f
'MSCC
202000000
202001000
202002000
202003000
202004000
202999000
*
22224. +
.llflot +
1172^ *
260551 *
2605*1
5925. +
5925.
EMISSIONS
NOX
'Mi -
• 001 *
57
*
!ooi +
^005
.001 +
.001
Source Category
Industrial 1C Engines
Distillate oil turbine
Distillate oil reciprocating
Natural gas turbine
^7
Natural gas reciprocating
Miscellaneous fuels
(MILLIONS
HC
•177
.045
.000
•8951
• 030
.016
.000
•JJJ
looo
.175
.043
OF TONS
CO
: :8tt
* .001
* ;§Jt
- Io08
* .002
* r881
- 1002
* .000
- .000
AR 22*1977
YfAR)
PART
* .005
- .004
+ .000
7 :88i
- .004
* .000
- .000
* . 000
« 9 \f \f W
- .000
+ .000
- . 000
Charge Rate Unit
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million
Million
cu ft/yr
cu ft/yr
Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table 1-8-b. SUMMARY OF 1975 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
INDUSTRIAL PROCESS* CHEMICAL MANUFACTURING PAGE 1
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1975 RUN DATE- MAR 22,1977
MOOTED
301000000
301002000
301003000
301005000
301999000
JACRP
UNITS)
m:
5*487.
1746*000.
NOX
EMISSIONS
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
rG
g
(MILLIONS OF
HC
.101
.101
.004
065
NS / YEAR)
+ .365
- .365
031
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
m
m
GJ
B
MSCC
Source Category
Charge Rate Unit
300000000
Industrial Processes
301000000 Chemical Manufacturing
301002000 Ammonia production with Tons/yr
methanator
301003000 Ammonia production with CO Tons/yr
absorber
301005000 Gen ban black production Tons/yr
301999000 Miscellaneous chemical Tons/yr
manufacturing
-------
Table 1-8-b. SUMMARY OF 1975 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
i
M
CO
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1975 RUN DATE*
MODIFIED
sec
306000000
306001000
306002000
306003000
306008000
306012000
tscc^
t
t
•f \
*
MSCC
306000000
306001000
306002000
306003000
306008000
306012000
S5B?TS, HOX EHISi
* .026
- .026
* ,025
- .025
18888: i :88!
us?: tfftKiitf
mm-, mmm
2199. NEGLIGIBLE
2199. NEGLIGIBLE
Source Category
Petroleum Industry
Process heater
Fluid catalytic crackers
IIONS IMILLIONS OF TON. /
H v CO
* .035 «• 5»890
- .035 - 5.890
4- .006 + .005
- .006 - .005
+ .009 + 5.890
- .009 - &.890
* tQOO * .011
•• .009 "• • 1 1 1
- r81J RlStlySti
NEGLIGIBLE NEGLISIBLE
NEGLIGIBLE NEGLISIBLE
Charge Rate Unit
N.A.a
1000 bbl/yr
Moving bed catalytic crackers 1000 bbl/yr
Miscellaneous leakage
Fluid coking
1000 bbl
capacity/yr
1000 bbl feed/yr
PAGE 1
MAR 22*1977
YEAR)
PART
+ .011
- .011
* .005
- .005
.002
.002
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-9-a. SUMMARY OF i960 EMISSIONS AND CHARGE RATES
I
r-J
ANNUAL CHARGE
EXTERNAL C
RATES AND EMISSIO
CflBUSTION, BOILER CATEGORY
hS PROJECTED TO 1980 RUN DATE'
PAGE 1
MAR 22*1977
MODIFIED TACRP EMISSIONS
SCC
-------
Table 1-9-a. SUMMARY OF 1980 EMISSIONS AND CHARGE RATES (Continued)
INTERNAL COMBUSTION ENGINES
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1980 RUN
ISC?*6BfTSI NOX ^SSIQNS JflUIOMS Of
• 568 .418 .0>6
.255 .104 .018
200000000
201000000
201001000
201002000
201003000
201999000
82909.
.012
.019
PAGE 1
- MAR 22*1977
S / *EAR>pART
.018
0
• 001
.100
:
.005
.002
013
• 002
.002
I
oo
o
MSCC
200000000
201000000
201001000
201002000
201003000
201999000
Source Category
Internal Combustion
Electric Generation
Distillate oil
Natural gas
Diesel
Miscellaneous fuel
Charge Rate Unit
1000 gal/yr
Million cu ft/yr
1000 gal/yr
N.A.a
''N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-9-a. SUMMARY OF 1980 EMISSIONS AND CHARGE RATES (Continued)
4627.
35626.
32923.
INTERNAL COMBUSTION ENGINES PAGE 2
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1980 RUN DATE" MAR 22,1977
MO§{?Ie° (ScPSSfTS) NO* EMISSIQMS SglUIONS OF JgNS / «*«„„
202000000 .313 ,3l% -Q%7 t()05
202003000
202004000
202999000
.001
.006
.00$
.001
.000
.237
.304
.003
.001
.001
.004
.000
• 000
• 000
I
UJ
MSCC
Source Category
202000000 Industrial 1C Engines
202001000 Distillate oil turbine
202002000 Distillate oil reciprocating
202003000 Natural gas turbine
202004000 Natural gas reciprocating
202999000 Miscellaneous fuels a
Charge Rate Unit
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
1 Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table 1-9-a. SUMMARY OF 1980 EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS, CHEMICAL MANUFACTURING
ANNUAL CHARGE RATES AND-EMISSIONS PROJECTED TO 1980 RUN OAfE'
MODIFIED
sec
301000000
181881888
301005000
301999000
I
1
\
1
(SCCTACu8?TS, NOK 6"ISSIONS
NEGLIGIBLE
6217000I NEGLIGIBLE
151180000. NEGLIGIBLE
MSCC Source Category
300000000 Industrial Processes
301000000 Chemical Manufacturing
30100ZOOO Ammonia production with
methanator
301003000 Ammonia production with CO
absorber
301005000 Carbon black production
301999000 Miscellaneous chemical
manufacturing
(MILLIONS OF TCNS / 1
HC Cl
1.126 2.?61
.*32 8 2.*369
.518 .336
Charge Rate Unit
Tons/yr
Tons /yr
Tons /yr
Tons/yr
PAGE 1
MAR 22»1977
YEAR)
PART
NEGLIGIBLE
Rfstisittf
NEGLIGIBLE
NEGLIGIBLE
-------
Table 1-9-a. SUMMARY OF 1980 EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED
MODIFIED
sec
306000000
306001000
306002000
306003000
306008000
306012000
TACRP
-------
Table 1-9-b. SUMMARY OF 1980 EMISSIONS AND CHARGE RATES UNCERTAINTY
EXTERNAL CCMBUSTION, BOILER CATEGORY
PAGE 1
I
oo
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980
HONIED
100000000
101000000
101002000
101004000
101005000
101006000
101007000
(SciA5KlTS
+ 30577000
30577000
* 4618700
4618700
+ 0
0
«• 2029500
1115800
+ 15220
15220
MSCC
100000000
101000000
101002000
101004000
101005000
101006000
101007000
) NOX ENISS">« M"'
* .853
- .808
* .798
- ,780
* . 7 71
. - ,771
+ .155
- .094
• * 0.000
. - 0,000
* .136
• - ,071
«• .000
. - .000
Source Category
* .121
- .028
«• .119
- ,019
RUN DA E- MAR 22*1977
.IONS OF T'.-. MS /
CJ
* .099
- .067
* .088
- .059
* ,118 * ,084
- .017 - ,057
+ .012 * .019
- .009 - .013
+ 0.000 * 0.000
- 0.000 - 0.000
* .001 + .019
NEGLIGIBLE NEGLlElBLE
NEGLIGIBLE NEGLIGIBLE
Charge Rate Unit
TEARIPART
+ .867
- .866
+ .812
- .811
+ .812
- .810
* .018
- .018
* 0.000
- 0.000
* ,015
NEGLIGIBLE
External Combustion (Boiler)
Electric Generation
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
-------
Table 1-9-b.
SUMMARY OF 1980 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
EXTERNAL COMBUSTION* BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980 RUN DATE-
PAGE 2
MAR 22,1977
MODIFIED
SCC
102000000
102002000
102004000
102005000
102006000
102007000
I
OJ
(Jl
TACRP
!SCC UNITS)
NOX
EMISSIONS
12611000.
12611000.
1686600.
1686600.
2072900.
2072900.
2648100.
1530900.
142990.
142990.
*
•
+
•
+
..
•f
—
+
_
+
—
• 3G3
.210
.171
.171
.148
.060
.096
.041
.177
.097
.000
.000
tMHLIONS
HC
«> .023
- .020
* .017
- .017
+ .013
- .009
* .009
- .006
+ .004
- .002
NEGLIGIBLE
NEGLIGIBLE
OF
- .031
/ YEAR)
PART
104
104
* .034
- .024
+ .016
- .011
* .011
- .008
* .025
- .013
NEGLIGIBLE
NEGLIGIBLE
* .302
- .302
* .019
- .019
* .016
- .016
* .024
- .014
NEGLIGIBLE
NEGLIGIBLE
MSCC
102000000
102002000
102004000
102005000
102006000
102007000
Source Category
Industrial
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
Charge Rate Unit
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
-------
Table 1-9-b. SUMMARY OF 1980 EMISSIONS AND CHARGE
UNCERTAINTY (Continued)
INTERNAL COMBUSTION ENGINES
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980
RUN DAT
PAGE I
MAR 32*1977
1
OJ
o
Moggieo ,
200000000
201000000
201001000 +
—
201002000 +
-------
Table 1-9-b. SUMMARY OF 1980 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
INTERNAL COHBUSTION ENGINES
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980
PAGE 2
RUN DATE" MAR 22*1977
MODIFIED
sec
202000000
202001000
202002000
202003000
202004000
202999000
H*
1
-J
TACRP
CSCC UNITS)
+
—
1
+
•
+
—
«•
—
49437.
tKiffc
2311.
2311.
26452.
26452.
14845.
14845.
—
*
—
+
+
^
+
—
+
•
NOK 6H1SSI°HS
.139 *
.102
.003
.003
IlBI
*000
.000
.005
.OC5
.002
• OC2
-
+
—
+
+
v
+
—
*
"
(MILLIONS OF
HC
.260 *
.110
.000
.000
:m
.000
.000
.000
.000
.258
.107
-
«•
—
*
+
«•
•f
•
+
"
TONS /
CO
.026
«013
.001
.001
:8H
.003
.002
.002
.002
.001
.001
YEAR)
«»
*
—
*
+
—
+
—
+
*•
PART
.005
.003
.001
.001
rSof
I 000
.000
.000
.000
.000
.000
MSCC
202000000
202001000
202002000
202003000
202004000
202999000
Source Category
Industrial 1C Engines
Distillate oil turbine
Distillate oil reciprocating
Natural gas turbine
Natural gas reciprocating
Miscellaneous fuels a
Charge Rate Unit
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
1 Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table 1-9-b.
SUMMARY OF 1980 EMISSIONS AND CHARGE RA'iES
UNCERTAINTY (Continued)
INDUSTRIAL PROCESS* CHEMICAL MANUFACTURING
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980 RUN DATf
I
00
MODIFIED
sec
301000000
301002000
301003000
301005000
301999000
TACRP
(SCC UNITS)
* 288470.
288470.
i mm-
+ 17464000.
17464000.
MSCC
300000000
301000000
301002000
301003000
301005000
301999000
EMISSIONS
NOX
NEGLIGIBLE +
NEGLIGIBLE
NEGLIGIBLE *
NEGLIGIBLE
NEGLIGIBLE *
NEGLIGIBLE
Source Category
Industrial Processes
Chemical Manufacturing
Ammonia production with
methanator
Ammonia production with CO
absorber
Carbon black production
Miscellaneous chemical
manufacturing
(MILLIONS OF
HC
.113
.113
.032
.032
-.m
1065
.065
1
+
•f
*
Charge
Tons/yr
Tons/yr
Trns/yr
Tons/yr
TONS / YEA
CO
.432 N
.432 N
• 001 N
.001 N
*8il tl
I 'til N
.'til N
.129 N
,129 N
Rate Unit
PAGE 1
MAR 22,1977
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Hfitiiilti
NEGLIGIBLE
NEGLIGIBLE
-------
Table 1-9-b.
SUMMARY OF 1980 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980 RUN DATE'
MODIFIED
SCC
306000000
306001000
306002000
306003000
306008000
306012000
PAGE 1
MAR 22*1977
TACRP EMISSIONS (MILLIONS OF TONS /
(SCC UNITS) NOX HC CO
+ .033 * .046 * 6.723
- .033 - .046 - 6.723
* •PJ? * -P,0,6, * «38£
- .032 - .007 - .Quo
* 168980. * .006 * .020 * 6»723
168980. - .006 - .020 - 6.723
* 21002. NEGLIGIBLE + .001 * .040
21002. NEGLIGIBLE - ,001 - .040
+ 1375200. NEGLIGIBLE * .041 NEGLIGIBLE
1375200. NEGLIGIBLE - .041 NEGLIGIBLE
+ 11998* NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE
11998. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE
YEAR)
PART
* .016
- .016
* -88$
- .006
* .014
- .014
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
*• .004
- .004
/
MSCC Source Category Charge Rate Unit
306000000 Petroleum Industry
306001000 Process heater N.A.a
306002000 Fluid catalytic crackers 1000 bbl/yr
306003000 Moving bed catalytic crackers 1000 bbl/yr
306008000 Miscellaneous leakage 1000 bbl
capacity/yr
306012000 Fluid coking 1000 bbl feed/yr
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table i-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES
EXTERNAL COMBUSTION, BOILER CATEGORY
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976 RUN 04TE'
PAGE 1
MAR 22*1977
MODIFIED
sec
100000000
101000000
101002000
101004000
101005000
181881888
102000000
mmm
i mmm
o 102007000
. TACRP EMISSIONS CMILLIONS OF UNS /
CSCC UNITS) NOX HC CO
7.373
6.038
403380000. 4.880
19940000. .620
0. 0.000
"HIM: :ffl
1.335
Imm ii»
1749300 .000
MSCC
100000000
101000000
101002000
101004000
101005000
101006000
101007000
102000000
102002000
102004000
102005000
102006000
102007000
.155 ,385
.094 .260
.073 .206
.020 .030
0.000 0.000
NEGLIGIBLE NEG'.lSlllJLE
.061 .126-
•9.?& •8§I
.019 .026
NEGLIGIBLE NEGLIGIBLE
YEAR)
PART
5.647
4.286
4.185
.080
0.000
1.361
•m
NEGLIGIBLE
Source Category Charge Rate Unit
External Combustion
Electric Generation
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
Industrial
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
(Boiler)
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES (Continued)
INTERNAL COMBUSTION ENGINES
ANNUAL CHARGE RATES AND ENISSIOKS PROJECTED TO 1976
PASE 1
RUN DATE* MAR 22>1977
'iHIED
C
EHISSXONS BILLIONS OF
200000000
201000000
mmm
201003000
201999000
i:
MSCC
200000000
201000000
201001000
201002000
201003000
201999000
mm:
76709.
Source
.597
.246
Ion
.017
Category
.362
.090
•88?
• 001
.041
.087
Charge Rate
.067
.016
oomcsj
-ooo
oooo
• ...
Unita
Internal Combustion
Electric Generation
Distillate oil
Natural gas
Diesel
Miscellaneous
fuel
1000 gal/yr
Million cu ft/yr
1000 gal/yr
N.A.a
N.A. (not applicable) is listed under "Charge Rate Unif'^where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATE., (Continued)
INTERNAL COMBUSTION ENGINES
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
MODIFIED
SCC
202000000
202001000
202002000
202003000
102999000
TACRP
CSCC UNITS)
68713.
944040*
3702.
28086*
25647,
NOX
.351
.004
.338
•or*
EMISSIONS (MILLIONS OF
HC
PAGE 2
RUN DATE" MAR 22*1977
3NS / YEAR)
• 0
.0
.272
.000
.086
.000
.002
.043
,003
.002
.001
PART
.005
001
004
00
0
MSCC
Source Category
Charge Rate Unit
202000000 Industrial 1C Engines
202001000 Distillate oil turbine
202002000 Distillate oil reciprocating
202003000 Natural gas turbine
202004000 Natural gas reciprocating
202999000 Miscellaneous fuels a
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PRCCESS, CHEMICAL MANUFACTURING
ANNUAL CHARGE RATHS AND EMISSIONS PROJECTED TO 1976 RUN DATE'
PAGE 1
MAR 22*1977
MODIFIED
SCC
301000000
301002000
301003000
301005000
301999000
TACRP
ISCC UNITS)
6301400.
2520900.
6086900.
151180000.
EMISSIONS (MILLIONS OF TONS /
NOX HC CO
NEGLIGIBLE
GIBLE
I
NEG
NEGLIGIBL
NEGLIGIBL
NEGLIGIBLE
1.089
.216
.032
.323
.518
2.652
.003
.048
2.267
.336
YEAR)
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
MSCC
Source Category
Charge Rate Unit
300000000
Industrial Processes
301000000
301002000
301003000
301005000
301999000
Chemical Manufacturing
Ammonia production with
methanator
Ammonia production with CO
absorber
Carbon black production
Miscellaneous chemical
manufacturing
Tons/yr
Tons/yr
Tons /yr
Tons/yr
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS, PRIMARY METALS
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976 RUN C *TE
PAGE I
MA* 22*1977
HOOjFJiO
303000000
303001000
303002000
303003000
303004006
303005000
303006000
303007000
TACRP
CSCC UNITS)
22082000.
8964000.
458400000.
1390000.
4333800.
2480000.
NOX
.013
NEGLIGIBLE
NEGLIGIBLE
(EGL1GIBLE
EMISSIONS (MILLIONS OF TONS / YEAR)
HC
.198
NEGLIGIBLE
NEGLIGIBLE
.184
.006
NEGLIGIBLE NEGLIGIBLE
CO
11.352
NEGLIGIBLE
NEGLIGIBLE
.056
.001
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
1.552
.115
.045
.088
.132
003
MSCC
Source Category
Charge Rate Unit
303000000 Primary Metals
N.A.
303001000 Aluminum reduction
303002000 Aluminum ore calcined
303003000 Coke metallurgical
303004000 Coke beehive
303005000 Copper smelters
303006000 Ferroalloy production (open furnace)
303007000 Ferroalloy production (closed furnace)
Aluminum, tons/yr
Tons/yr'
Coal, tons/yr
Coal, tons/yr
N.A.
Tons/yr
N. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
.number is made up of two of more MSCCs whose charge rates are different.
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS, PRIMARY METALS
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976 RUN DATE'
PAGE 2
MAR 22>1977
MODIFIED
sec
181881888
303010000
303011000
18181S888
303999000
TACRP
(SCC UNITS)
i
147490000.
6742000.
65000.
1554000.
31200000.
EMISS
NOX
NEGLIGIBLE
.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.001
MSCC Source Category
| 303008000 Iron production
303009000 Steel production
303010000 Lead smelters
303011000 Molybdenum
303012000 Titanium
303030000 Zinc smelting
IONS (MILLIONS OF TONS / Y
HC CO
NEGLIGIBLE 7*QS?
.008 4.271
.000 NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE ?2?i
.001 .002
Charge Rate Unita
N.A.
Tons/yr
N.A.
N.A.
N.A.
Tons /yr
303999000 Miscellaneous metallurgical processes Tons/yr
YEAR)
PART
.486
.093
.012
.013
NEGLIGIBLE
.005
.047
N. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up ot two or more MSCCs whose charge rates are different.
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
ANNUAL CHARGE RATES AND EMISSIOKS PROJECTED TO 1976 RUN OATE;
PAGE 1
MAR 22*1977
MODIFIED TACRP EMISSIONS (MILLIONS OF TONS / YEAR)
SCC CSCC UNITS) NOX HC CO PART
306000000 .522 .417 16.091 .291
306001000 .471 .047 .035 .092
306002000 1536000. .051 .172 15.663 .171
306003000 100800. NEGLIGIBLE .005 .194 NEGLIGIBL
306008000 26970000. NEGLIGIBLE .193 NEGLIGIBLE NEGLIGIBL
306012000 112000. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE .027
i MSCC
306000000
306001000
306002000
1 306003000
306008000
306012000
Source Category
Petroleum Industry
Process heater
Fluid catalytic crackers
Moving bed catalytic crackers
Miscellaneous leakage
Fluid coking
aN.A. (not applicable) is listed under "Charge Rate
vv*i*-vt 1-t£k •*• A a TV* .a/3 A nr\ f\f 4*«j>rt r\t* TV* fM*>0 TVX.Qf*'. f**. a txrVioo A f*
Charge Rate Unit a
N.A.
1000 bbl/yr
1000 bbl/yt
1000 bbl
capacity/yr
1000 bbl feed/yr
Unit" where the MSCC
It at* or » vst-fAes av*A Alffe*t»£*t\4-
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBCN EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
RUN DATE'
PAGE 1
MAR 23,1977
MODIFIED
sec
400000000
401000000
401001000
401002000
401999000
TACRP
CSCC UNITS)
41850.
114460.
115650.
NOX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
EMISSIONS (MILLIONS Of TONS / fEAR)
HC
4.238
.132
.004
.103
.025
CO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
.010
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
MSCC
400000000
401000000
401001000
401002000
401999000
Source Category
Point Source Evaporation
Cleaning Solvents
Dry cleaning
Degreasing
Miscellaneous solvent use
Charge Rate Unita
N.A.
N.A.
Clothes, tons/yr
Solvent, tons/yr
Solvent, tons/yr
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES (Continued)
oo
HYDROCARBON EVAPORATION PAGE 2
ANNUAL CHARGE RATES AND EMIS$IQ^S PROJECTED TO 1976 RUN OATf* MAR 22*1977
MODIFIED
sec
402000000
402001000
281881888
*8!88J888
4020. 06000
402007000
402008000
402999000
j
TACRP EHISS
«SCC UNITS) NOX
15354000. NEGLIGIBLE
438000* NEGLIGIBLE
"H*W: REftiSHtf
Mm- giffiBtf
170640. NEGLIGIBLE
1500900. NEGLIGIBLE
MSCC Source Category
402000000 Surface Coating
402001000 Paint
402002000 Paper coatings
402003000 Varnish and shellac
402004000 Lacquer
402005000 Enamel
402006000 Primer
402007000 Fabric coatings
402008000 Oven coatings
402999000 Miscellaneous coatings
IONS C MILLIONS OF TONS / t
HC CO
2.076
.224
:!»•
•m
.104
.202
NEGLIGIBLE
NEGLIGIBLE
fliEtiiild
jjittiElgti
NEGLIGIBLE
NEGLIGIBLE
Charge Rate Unit /
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tCms/yr
Coating, tons/yr
Coating, tons/yr
Coating* tons/yr
Coating* tons/yt
Coating* tons/yr
PART
.010
NEGLIGIBLE
a
NEGLIG
010
BLE
-------
Table 1-10-a. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES (Continued)
i
*.
vD
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
PAGE 3
RUN OATE« MAR 22*1977
YEAR)
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
MODIFIED
sec
403000000
403001000
403002000
403003000
403999000
406000000
406001000
406002000
t
tSCC UNITS)
14860000.
15000000.
200530000.
61932000.
118600000.
MSCC
403000000 Petroleum
403001000 Fixed roof
EMISS
NQX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Source Category
Storage
IONS (MIL
HC
1.652
1.318
.200
.065
.069
.378
.237
.141
403002000 Floating roof
403003000 Variable vapor space
403999000 Miscellaneous storage
406000000 Petroleum
Marketing and Transportation
406001000 Rail and truck transportation
406002000 Marine vessel transportation
LIONS OF TONS / t
CO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Charge Rate Unita
N.A.
N.A.
N.A.
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
NEGLIGIBLE
NEGLIGI
BLE
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-10-b. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
EXTERNAL COMBUSTION* BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN >ATE<
PAGE 1
HAR 22*1977
1
1 T*
LT1
0
MODIFIED
sec
100000000
101000000
101002000
101004000
101005000
101006000
101007000
TACRP
(SCC UNITS)
* 15024000.
15024000.
+ 2516400.
2516400.
* 0.
* 875870?
* 8IilI8i
15220.
1
+
-
!
*
*
*
—
EMISS
NOX
1 500
.463
.463
.416
.416?
.103
.103
0.000
°:?7&
:m
.000
IONS CHILLI
HC
* • 18?
* .102
- .016
* .101
- .015
+ .009
- .006
* 0.000
- 0.000
* .001
NEGLt8?lLE
NEGLIGIBLE
ONS OF TONS /
CO
* •081
- .056
+ .074
- .050
* .072
- .048
«• .014
- .009
+ 0.000
•• 0.000
* • 012
NEGLIGIBLE
NEGUG BLE
YEAR)
+
+
-
+
-------
Table 1-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
EXTERNAL CCMBUSTION* BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE'
PAGE 2
MAR 22*1977
MODIFIED
sec
102000000
102002000
102004000
102005000
102006000
102007000
TACRP
(SCC UNITS)
•••«• 7378300.
; mm:
; mmk
1049700.
+ 1226100.
1226100.
* 142990.
142990.
•f
*
*
7
—
+
_
•*>
•
EN
NQX
:ti$
.089
• 069
.101
*iil
1 066
• 1 16
.000
.000
ISSIONS CHILLIONS OF TONS /
HC
* .017
- .014
+ .011
* loll
+ :J8I
- loos
— m Oo2
NEGLIGIBLE
NEGLIGIBLE
CO
- :8il
+ .023
* :81t
* ;88?
- 1006
+ .017
- .014
NEGLIGIBLE
NEGLIGIBLE
YEAR)
PART
- lilt
* .209
; :*H
* .'Sis*
- loos
- ^011
NEGLIGIBI
NEGLIGIBI
(Jl
MSCC
Source Category
Charge Rate Unit
102000000
102002000
102004000
102005000
102006000
102007000
Industrial
Bituminous coal
Residual oil
Distillate oil
Natural gas
Process gas
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
-------
Table 1-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
I
Ul
INTERNAL COMBUSTION ENGINES
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
MODIFIED TACRP EMISS
SCC ISCC UNITS) NOX
200000000
201000000
201001000 *
201002000 *
201003000 +
201999000
'MSCC
200000000
: 201000000
201001000
201002000
201003000
201999000
+ .396
- *144
* .379
- .126
3339400. * .372
1125600. - .124
417950. * .072
115800. - .022
15352. + .003
15352. - .OC2
4- .003
- .003
Source Category
Internal Combustion
Electric Generation
Distillate oil
Natural gas
Diesel
Miscellaneous fuel
IONS (MILLIONS OF
HC
+ .194 4-
- .060
* .015 +
- .014
* .005 +
- .002
* .002 *
- .001
+ .000 4-
- ,000 -
* .014 *
- .014
Charge Rate
TONS i
:o
.038
.013
.030
.010
• 029
.010
.003
.000
.002
.001
.000
.000
Unita
1000 gal/yr
Million cu ft/yr
1000 gal/yr
N.A.
PAGE 1
RUN C 4TE" MAR 22*1977
YEAR)
PART
* .025
- .009
+ .024
- .008
+ .024
- .008
* .001
- .000
* .001
- .001
*• .001
- .001
a
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table i-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
INTERNAL COMBUSTION ENGINES
TACR AND EHIS
MODIFIED
SCC
202000000
202001000
202002000
202003000
202004000
202999000
PAGE 2
ON UNCERTAINTIES PROJECTED TO 1976 RUN DATE-
TACRP
ISCC UNITS)
27605.
27605.
623450.
192420.
1399.
1399.
26110.
26110.
7676.
7676.
EMISSIONS
NOX
* . 1 16 *
- .068
+ .002 *
- .002
* . 1 16 *
- .068
* .000 *
- .000
* .005 «•
- .005
+ .001 +
- .001
(MILLIONS OF
HC
.193 +
.058
.000 *
.000
.031 *
.017
.000 *
m-»
+
.000
.191 +
.055
TONS
CO
.024
.009
.001
.001
.024
.009
.002
,00 1
.502
.002
.000
.000
MAR 22,1977
/ YEAR]
*
~
+
—
*
+
«•
*
•
*
—
I
PART
.005
.004
.000
.000
.005
.004
.000
?T .fc jr
.000
.000
.000
.000
I
Ul
MSCC
Source Category
Charge Rate Unit
202000000
202001000
202002000
202003000
202004000 •
202999000
Industrial 1C Engines
Distillate oil turbine
Distillate oil reciprocating
Natural gas turbine
Natural gas reciprocating
Miscellaneous fuels a
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table 1-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
i
Ul
INDUSTRIAL PRCCESS, CHEMICAL MANUFACTURING
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN r
MODIFIED
sec
301000000
301002000
301003000
301005000
301999000
.
TACRP EMISSIONS
ISCC UNITS) NOX
*
«•
*
*
—
NEGLIGIBLE *
NEGLIGIBLE
231770. NEGLIGIBLE +
231770. NEGLIGIBLE
551?5: HEhKtttf -
226980. NEGLIGIBLE +
226980. NEGLIGIBLE
i l?tt*888: gfftittlti •
MSCC
300000000
301000000
301002000
301003000
301005000
301999000
Source Category
Industrial Processes
Chemical Manufacturing
Ammonia production with
methanator
Ammonia production with CO
absorber
Carbon black production
Miscellaneous chemical
manufacturing
(MILLIONS OF
HC
. 101 +
.029 *
.029
:88t ^
.072 *
.072
.065 *
.065
Charge Rate
Tons/yr ^
Tons/yr
Tons /yr
Tons/yr
TONS /
CO
:in
.001
.001
;81i
13*3
.3^3
Unit
PAGE 1
ATE« MAR 22*1977
YEAR)
PART
NEGLIGIBL!
NEGLIGIBL!
NEGL
NEGL
Nift
NEGL
NEGL
Hilt
GIBLE
GIBLE
a
8LI
BL1
-------
Table 1-10-b.
i
ui
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
INDUSTRIAL PROCESS* PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE'
PAGE 1
MAR 22*1977
MODIFIED
sec
303000000
303001000
303002000
303003000
303004000
303005000
303006000
303007000
TACRP
(SCC UNITS}
+ 8828500.
3899300.
+ 715940.
24758000^
+ 132570.
132570.
+ 933990.
933990.
+ 569650.
5696504
MSCC
EMISS
NOX
* .002
- .010
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
- looi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Source Category
303000000 Primary Metals
303001000 Aluminum
303002000 Aluminum
reduction
ore calcined
303003000 Coke metallurgical
303004000 Coke beehive
303005000 Copper smelters
303006000 Ferroalloy
303007000 T^r^alloy
IONS (MILLIONS OF TONS /
HC CO
«• .018 + 1.293
- .052 - 1,294
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
T' • 0 1 9 * » O 0 5
- .051 - .027
* .001 + .000
- .001 - .000
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
Charge Rate Unit
N.A.
Aluminum, tons/yr
Tons/yr
Coal, tons/yr
Coal, tons/yr
N.A.
VEARI
PART
+ .402
- .294
+ .214
- »339
* .029
- .021
* .051
- .054
* .142
- ,075
+ .002
- .002
production (open furnace) Tons/yr
production (closed
furnace)
aN. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES
(Continued)
xICERTAINTY
INDUSTRIAL PROCESS, PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE*
PAGE 2
MAR 22*1977
MODIFIED
sec
303008000
303009000
303010000
303011000
303012000
303030000
303999000
TACRP
(SCC UNITS)
* 12158000.
12158000.
+ 1010100.
1010100.
+ 9999.
9999.
i mm:
4- 4386300.
4386300.
EMISS
NOX
NEGLIGIBLE
NEGLIGIBLE
+ .002
- .010
' .000
™* .0 00
KfcGL 1 v IBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
+ .000
- .001
[QNS (MULI
HC
NEGLIGIBLE
NEGLIGIBLE
+ .002
- .008
+ .000
*" .000
NEGL GiBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL GIBLE
NEGLIGIBLE
NEGLIGIBLE
+ .000
- .000
ONS OF ONS /
i a
+ 1,047
- 1.047
+ .760
- .760
NEGLIGIBLE
NEGLIGIBLE
NtGLIGIBLfc
NEGLIGIBLE
+ .001
- .001
NEGLIGIBLE
NEGLIGIBLE
+ .000
- .001
+ .297
* '. 039
- .042
+ .006
T • '
- .003
NEGLIGIBLE
NEGLIGIBLE
4- .001
- .001
+ .008
- .008
MSCC
303008000
303009000
303010000
303011000
303012000
303030000
303999000
Source Category
Iron production
Steel production
Lead smelters
Molybdenum
Titanium
Zinc smelting
Miscellaneous metallurgical processes
Charge Rate Unita
N.A.
Tons/yr
N,A.
N.A.
N.A.
Tons/yr
Tons/yr
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
Ul
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE'
MODIFIED
sec
306000000
306001000
306002000
306003000
306008000
306012000
TACRP EMISSIONS (MILLIONS OF TONS /
(SCC
+
«•
4-
+
—
*
MSCC
306000000
306001000
306002000
306003000
306008000
306012000
UNITS) NOX
* .026
- .026
* .026
44790. * loSI
44790. - .003
4707. NEGLIGIBLE
35&m: mmm
358570. NEGLIGIBLE
3225. NEGLIGIBLE
3225. KEGLIGIBLE
Source Category
Petroleum Industry
Process heater
Fluid catalytic crackers
HC CO
* .037 * 6.047
- .037 - 6.047
* .006 + .005
+ .010 * 6.047
- .010 - 6.047
* .000 * .013
+ IS?? NEGLiSilLE
- .035 NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
Charge Rate Unita
N.A.
1000 bbl/yr
Moving bed catalytic crackers 1000 bbl/yr
Miscellaneous leakage
Fluid coking
1000 bbl
capacity/yr
1000 bbl feed/yr
PAGE 1
MAR 22,1977
/EAR)
PART
+ .011
- .011
+ .005
- .005
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
NEGLIG
Hfitii
NEGLIG
- 1002
BLE
Ki
BLS
-------
Table 1-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
n(WEO
-------
sO
T?bie 1-10-b. SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
HYDROCAR8CN EVAPORATION PAGE 2
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN OAT£» MAR 22,1977
r"R'«RT
-* :8o°I
NEGLIGIBLE
NEGLIGIBLE
nuuiMfci)
SCC (SC
402000000 +
402001000 +
402002000 +
402003000 +
402004000 *
402005000 +
402006000 +
402007000 *
402008000 +
«.
402999000 +
MSCC
402000000
402001000
402002000
402003000
402004000
402005000
402006000
402007000
402008000
402999000
TACRP
C UNITS)
3233QOQ.
3211400.
38745,
38745.
3219300.
31HIJJ;
26919.
11094.
11094.
44162.
44162.
87689.
87689.
106620.
106620.
27605.
27605.
253400.
253400.
NOX ENISSIDMS
HStttiltf i
NEGLIGIBLE +
NEGLIGIBLE
NEGLIGIBLE +
l||if{sl8U -
M:l»H 5 IDLC +
NEGLIGIBLE
NEGLIGIBLE <•
NEGLIGIBLE
NEGLIGIBLE +
NEGLIGIBLE
NEGLIGIBLE +
NEGL G BLE
NEGL 6 BLE +
NE6LIG BLE
NEGL GIBLE +
NEGLIGIBLE
NEGLIGIBLE +
NEGLIGIBLE
Source Category
Surface Coating
Paint
Paper coatings
Varnish and shellac
Lacquer
Enamel
Pri/ner
Fabric coatings
Oven coatings
Miscellaneous coatings
(MILLIONS OF JONS /
HC CO
.269 NEGLIGIBLE
.253 NEGLIGIBLE
.027 NEGLIGIBLE
.027 NEGLIGIBLE
.214 NEGLIGIBLE
:4?i Biitietitt
.019 NEGLIGIBLE
.010 NEGLIG BLE
.010 NEGLIGIBLE
.026 NEGLIGIBLE
.026 NEGLIGIBLE
.093 NEGLIGIBLE
.093 NEGLIG BLE
.119 NEGLIGIBLE
.119 NEGL GIBLE
•018 NEGLIGIBLE
.018 NEGLIGIBLE
.040 NEGLIGIBLE
.040 NEGLIGIBLE
Charge Rate Unit
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
NEGL
mt
NEGL]
NEGL
NEGL
[G
[g
61
G:
GJ
[BLE
itf
BLE
BLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
NEGLIG
.002
.002
BLE
BLE
BLE
BLE
BLE
BLE
BLE
-------
Table 1-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE
PAGE 3
MAR 22,1977
MODIFIED
SCC
403000000
403001000
403002000
403003000
403999000
TACRP
CSCC UNITS)
371080
8246200.
NOX
EMISSIONS (MILLIONS OF TOfS / /EAR)
NEGLIGIBLE
NEGLIGIBLE
•i
ill
6]
i1
NEGLIGIBLE
HC
* .352
- .351
* .079
; :8H
* :W4
- .047
CO
NEGLIGIBLE
NEGLIGIBLE
NEGl
NEGL
N
N
GJ
8
PART
NEGLIGIBLE
NEGLIGIBLE
Ni
N!
Ni
\
NEGLIGIBLE NEGLIGIBLE
MSCC
403000000
403001000
403002000
403003000
403999000
Source Category
Petroleum Storage
Fixed roof
Floating roof
Variable vapor space
Miscellaneous storage
Charge Rate Unita
N. A.
N. A.
N. A.
1000 gal/yr
1000 gal/yr
aN. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-10-b.
SUMMARY OF 1976 EMISSIONS AND CHARGE RATES UNCERTAINTY
(Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE'
PAGE 4
MAR 23,1977
MODIFIED
SCC
406000000
406001000
406002000
TACRP
(SCC UNITS)
17011000.
17011000.
7161400.
7161400.
15430000.
15430000.
EMISSIONS (MILLIONS OF TONS
NOX HC CO
/ YEAR)
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
*£GLIGIBLE
* .087
- .088
* .082
- .082
* .028
- .031
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
MSCC
Source Category
Charge Rate Unit
406000000 Petroleum Marketing and Transportation 1000 gal/yr
406001000 Rail and truck transportation
.406002000 Marine vessel transportation
1000 gal/yr
1000 gal/yr
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGF PATES
EXTERNAL CCNBUSTION. BOILER CATEGORY
ANNUAL CHARGE RATES AND 6MISSIO>S PROJECTED
MOOTED
100000000
101000000
101002000
mmm
mmm
102000000
102002000
102004000
102005000
18188*888
• selNHKTsi MOX EN:SSI
5.877
4.766
474040000. 4.609
28590000. .120
0. 0.000
1.091
100540000. .816
16000000. .096
9340000. .056
2080000. .123
1749300. .000
; 1
MSCC Source Category
TO 1981 RUN DATE' HAR
ONS (MILLIONS OF TONS 1 ft
.195 .457
.115 ,300
.085 .242
0.033 0.000
NEGLtSfJLE NEGLIGIBLE
.081 .157
.040 .089
.024 .032
.014 .019
NEGLIGIBLE NEGLIGIBLE
1 i
Charge Rate Unit
PAGE 1
22,1977
:AR>
5.620
4.057
3.929
NEGLIGIBLE
1.563
1.290
.184
.070
NEGLIGIBLE
100000000 External Combustion (Boiler)
101000000 Electric Generation
101002000 Bituminous coal
101004000 Residual oil
101005000 Distillate oil
101006000 Natural gas
101007000 Process gas
102000000 Industrial
102002000 Bituminous coal
102004000 Residual oil
102005000 Distillate oil
102006000 Natural gas ,
102007000 Process gas
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
To is burned/yr
1000 gal/yr
1000 g-al/yr
Million cu-ft/yr
Million cu ft/yr
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES (Continued)
INTERNAL COMBUSTION ENGINES
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
RUN DATE'
MODIFIED
sec
200000000
201000000
201001000
201002000
201003000
201999000
TACRP
(SCC UNITS)
1
MSCC
200000000
201000000
201001000
201002000
201003000
201999000
313100.
280980.
84459.
Source
EMISSIONS
NOX
.560
.257
.145
.080
.012
.020
Category
(MILLIONS OF
HC
.432
.107
.002
.000
.001
.104
Charge Rate
TONS /
CO
.065
,019
.012
.000
.005
.002
Unita
Internal Combustion
Electric Generation
Distillate oil
Natural gas
Diesel
Miscellaneous
fuel
1000 gal/yr
Million cu ft/yr
1000 gal/yr
N.A.
PAGE 1
MAR 22,1977
YEAR)
PART
.018
.013
.009
.000
.002
.002
*N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES (Continued)
INTERNAL COMBUSTION ENGINES
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
PAGE 2
RUN D, TE* MAR 22*1977
MODIFIED TACRP
SCC ISCC UNITS)
202000000
202001000 82513.
181881888 79tMJ:
? 02004000 37511.
02999000 34742.
MSCC
202000000
202001000
202002000
i 202003000
| 202004000
! 202999000
NOX
.304
.005
•P. 9.1
.005
Source Category
Industrial 1C Engines
Distillate oil turbine
Distillate oil reciprocating
Natural gas turbine
Natural gas reciprocating
Miscellaneous fuels a
5 (MILLIONS OF TONS /
.325 .046
.000 .002
•QZ? »23£
.001 .004
•001 .003
.250 .001
Charge Rate Unit
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
1 Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
.005
.001
-------
Table 1-ii-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PRCC6SS, CHEMICAL MANUFACTURING PAGE 1
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981 RUN DATE- MAR 22,1977
MODIFIED
SCC
301000000
iscI*S8!Tsi
NQX ENISSIONS 5cBIUIONS OF cTs
NEGLIGIBLE
RmitHt
1.135
2.788
:ffl
YEAR)
PART
NEGLIGIBLE
mtmm
Ul
MSCC
Source Category
Charge Rate Unit
300000000
301000000
301002000
301003000
301005000
301999000
Industrial Processes
Chemical Manufacturing
Ammonia production with
methanator
Ammonia production with CO
absorber
Carbon black production
Miscellaneous chemical
manufacturing
Tons/yr
Tons/yr
Tons /yr
Tons/yr
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RAT1 (Continued)
INDUSTRIAL PROCESS* PRIMARY METALS
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981 RUN DATE-
PAGE 1
MAR 22»1977
MODIFIED
SCC
303000000
303001000
303002000
303003000
303004000
303005000
303006000
303007000
TACRP
tSCC UNITS*
23362000,
937*000.
458400000.
1390000.
4127300.
2680000.
NOX
.013
EMISSIONS (MILLIONS OF ONS / YEAR)
MC
.198
NEGLIGIBLE
NEGLIGIBLE
.184
.006
CO
6.657
NEGLIGIBLE
NEGLIGIBLE
.002
NEGLIGIBLE .— .„„*
HSHEittf OfftiifKf flfitigfft
. NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.056
.001
PART
.710
.039
.009
.032
.056
NEGLIGIBLE
NEGLIGIBLE
.001
i
o^
cr-
MSCC
Source Category
303000000 Primary Metals
Charge Rate Unita
N.A.
303001000 Aluminum reduction
303002000 Aluminum ore calcined
303003000 Coke metallurgical
303004000 Coke beehive
303005000 Copper smelters
303006000 Ferroalloy production (open furnace)
303007000 Ferroalloy production (closed furnace)
Aluminum, tons/yr
Tons/yr
Coal, tons/yr
Coal, tons/yr
N.A.
Tons/yr
aN. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS* PRIMARY METALS rAi,E 2
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981 RUN DATE- MAR 22,1977
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES ontinued)
i
c^
00
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981 RUN DATE'
PAGE 1
MAR 22*1977
MODIFIED
SCC
306000000
306001000
306002000
306003000
306008000
306012000
TACRP EMISSIONS
(SCC UNITS) NOX
,347
(MILLIONS OF TQ*> /
HC CO
.462 10.3J1
.290 .058 .039
1728000. .058 .182 10.168
62300* NEGLIGIBLE .003 *li5
30570000. NEGLIGIBLE .221 NEGLIGIBLE
122000. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE
MSCC Source Category
306000000 Petroleum Industry
306001000 Process heater
Charge Rate Unit a
N.A.
YEAR)
PART
.224
.079
.115
NEGLIGIBL
NEGLIGIBL
.030
306002000 Fluid catalytic crackers 1000 bbl/yr
306003000 Moving bed catalytic crackers 1000 bbl/yr
306008000 Miscellaneous leakage 1000 bbl
capacity/yr
306012000 Fluid coking 1000 bbl feed/yr
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
RUN DATE'
PAGE 1
MAR 22»1977
MODIFIED
J v \*
400000000
401000000
401001000
401002000
401999000
TACRP
(SCC UNITS)
43000.
114560.
130690.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
2.425
.111
.001
.096
.014
CO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
.012
NEGLIGIBLE
NEGLGIBLI
BL
BL
II E Wt i w 1
NEGLIGJBLI
NEGLISlr
MSCC
400000000
401000000
401001000
401002000
401999000
Source Category
Point Source Evaporation
Cleaning Solvents
Dry cleaning
Degreasing
Miscellaneous solvent use
Charge Rate Unita
N.A.
N. A.
Clothes, tons/yr
Solvent, tons/yr
Solvent, tons/yr
N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
PAGE 2
RUN DATf* MAR 22*1977
EMISSIONS (MILLIONS
OF TONS / fEARI
5CC
402000000
4-8f88i888
402003000
mnm
402006000
402007000
402008000
402999000
(SC
1
MSCC
402000000
402001000
402002000
402003000
402004000
402005000
402006000
402007000
402008000
402999000
C UNITS) NOX
2989000. NEGLIGIBLE
t.mm: mimm
401970. NEGLIGIBLE
siHU: m&m
1294500. NEGL GIBLE
1692700. NEGLIGIBLE
220940. NEGLIGIBLE
1693600. NEGLIGIBLE
Source Category
Surface Coating
Paint
Paper coatings
Varnish and shellac
Lacquer
Enamel
Primer
Fabric coatings
Oven coatings
Miscellaneous coatings
HC CO PART
1.506 NEGLIGIBLE .012
*133 NEGLIGIBLE NEGLIC
•9?& 8i£!-ii»i§l-i NiP.H
.110 NEGLlGiBLfc NtGLli
.344 NEGLI? BLE NEGL (
.239 NEGLIGIBLE NEGLK
.067 NEGLIGIBLE NEGLIC
.143 NEGLIGIBLE .(
Charge Rate Unit
Coating, tons/yr
C oating , tons / yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
JIBLE
* T D 1 C
1 Srfc
»I8LE
ilBLE
5I8LE
ilBLE
)12
-------
Table 1-11-a. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES (Continued)
HfDPOCARBCN EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
RUN DATE'
MODIFIED
sec
403000000
403001000
4Q3002QQQ
403003000
403999000
406000000
406001000
406002000
T
(SCC
ACRP
UNITS)
32360000.
15000000.
196900000.
if!
MSCC
403000000
403001000
403002000
403003000
403999000
406000000
406001000
406002000
loW:
EMISSIONS
NOX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
flfftttiftE
(MILLIONS OF TONS /
HC CO
.505
.082
1069
.303
:ffl
Source Category
Petroleum Storage
Fixed roof
Floating roof
Variable vapor space
Miscellaneous
storage
Petroleum Marketing and Transportation
Rail and truck
Marine vessel
transportation
transportation
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
flfftffiftf
Charge Rate Unita
N.A.
N.A.
N.A.
1000
1000
1000
1000
1000
gal/yr
gal/yr
gal/yr
gal/yr
gal/yr
PASE 3
MAR 22,1977
/EAR)
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
N. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number itt made up of two or more MSCCs whose charge rates are different.
-------
Table 1-11-b. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES
UNCERTAINTY
EXTERNAL COMBUSTION* BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
PAGE
RUN D/TE- MAR 32*1977
OF
'""'
PART
100000000
101000000
101002000
101004000
101005000
101006000
101007000
+ 51921o8.
5192100.
* 0,
+ 7318500^
; 10?lli8:
15220.
* .954 *
- . 8 99
* .894 «•
- .873
.126 * .105
.030 - .070
.123 «> .092
.323 - .062
- "all - *&fi - *8I?
* Jl78 * 1013 * *Q20
- .023 - .010 - .014
+ 0.000 + 0.000 + 0.000
- 0.000 - 0.000 - 0,000
* .083 * .001 + .021
- .032 - .001 - .009
+ .000 NEGLIGIBLE NEGLIGIBLE
• .000 NEGLIGIBLE NEGLIGIBLE
MSCC Source Category
100000000 External
101000000 Electric
Combustion (Boiler)
Generation
101002000 Bituminous coal
101004000 Residual oil
101005000 Distillate oil
101006000 Natural gas
101007000 Process gas
Charge Rate Unit
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
- rl?!
* .913
- .913
i :!tt
i- .021
- .021
* 0.000
- 0.000
* .017
NEGLIGIBLE
NEGLIGIBLE
-------
Table 1-11-b.
SUMMARY OF 1981 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
EXTERNAL COMBUSTION, BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN DATE'
PAGE 2
MAR 22,1977
MODIFIED
SCC
102000000
102002000
102004000
102005000
102006000
102007000
TACRP
ISCC UNITS)
4
+
+
14080000.
14080000.
1832900.
iliUtfc
2344200.
3013100.
1373000.
142990.
142990.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
i :!?* i 'Ml
.197
.197
.165
- .022
* .166
- .081
4 .000
- .000
4 .018
- .018
4 .013
4 .037
- .027
4 .016
+
- .006
4 .005
NEGLIGIBLE
NEGLIGIBLE
.009
.027
- .012
NEGLIGIBLE
NEGLIGIBLE
+ .327
- .328
+ .021
.018
.027
NEGLIGIBLE
NEGLIGIBLE
MSCC
Source Category
Charge Rate Unit
102000000
102002000
102004000
102005000
102006000
102007000
Industrial
Bituminous coal
Residual .oil
Distillate oil
Natural gas
Process gas
Tons burned/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
-------
Table 1-ii-b. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
INTERNAL COMBUSTION ENGINES
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN 01 fE<
PAGE 1
MAR 22*1977
MODIFIED
sec
200000000
201000000
201001000
201002000
201003000
201999000
TACRP
(SCC UNITS)
* 3518700.
1313100.
i mm:
+ 19658.
19658.
'
EMI
NOX
§5
4
* .399
- .147
4 .392
- .145
- l81t
4 to03
- .003
4 .OC6
- .006
SSIONS
4
—
4
-•
+
•
4
4
•
4
••
(MILLIONS OF
HC
.279 4
.127
.030 4
.029
.005 4
.002
Io8S -
1 000 4
.000
.029 4
.029
JJNS /
ca
§41
18
.031
.012
.031
.012
-.m
.002
.001
.001
.001
YEAR]
4
•
4
—
4
—
t
4
»
4
"•
i
PART
.026
.010
.026
.010
.026
.009
• 99 \
Tooi
.001
.002
.002
MSCC Source Category
200000000 Internal Combustion
201000000 Electric Generation
201001000 Distillate oil
201002000 Natural gas
201003000 Diesel
201999000 Miscellaneous fuel
Charge Rate Unit
1000 gal/yr
Million cu ft/yr
1000 gal/yr
N.A. "
N.A. (not applicable) is listed under "Charge Rate Unit" Jvhere the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table 1-11-b.
SUMMARY OF 1981 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
INTERNAL COMBUSTION ENGINES
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE'
n°W™
202000000
202001000
202002000
202003000
202004000
202999000
299230.
2540.
2540.
26568.
26568.
mil:
NOX
.146
.111
.110
.000
. oco
.005
• 005
• 002
.002
SIONS (HILLIONS OF
4-
4-
(H
.277
.123
13
NS
.027
.014
4- .001
; :8!t
- .014
4- .003
- .002
4- .002
- .002
4- .001
- .001
PAGE 2
MAR 22*1977
' '""'PAST
4- .005
- .003
'MSCC
202000000
202001000
202002000
202003000
202004000
202999000
Source Category
Industrial 1C Engines
Distillate oil turbine
Distillate oil reciprocating
Natural gas turbine
Natural gas reciprocating
Miscellaneous fuels
Charge Rate
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Unit
Although this cate<"~>rv is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table 1-li-b.
SUMMARY OF 1981 EMISSIONS AND CHARGE xvATES
UNCERTAINTY (Continued)
INDUSTRIAL PRCCESS* CHEMICAL MANUFACTURING
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN
MODIFIED
sec
301000000
301002000
301003000
301005000
301999000
TACRP EMISSIONS (MILLIONS
(SCC UNITS) NOX HC
I H
MSCC
300000000
301000000
301002000
301003000
301005000
301999000
HftiS
311020. NEGLIG
74077. NEGLIG
241910. N6GLIG
241200. KSGLIG
464000. NEGLIG
464000. NEGLIG
IBLE * .113
IBLE - .117
I8LE «• .034
BE + 1 005
IBLE - .005
8LE * .093
:BLE - .091
IBLE + .065
IBLE - .065
Source Category Charge
OF sONS /
CO
- ^452
* .001
* 1438
- .431
Rate Unit
Industrial Processes
Chemical Manufacturing
Ammonia production with Tons/yr
methanator
Ammonia production with CO Tons/yr
absorber
Carbon black production Tons/yr
Miscellaneous chemical Tons/yr
manufacturing
PAGE 1
MAR 22»i977
YEAR)
PART
Nf
N!
NEGLIGIBLE
G]
lit,
-------
Table 1-11-b.
SUMMARY OF 1981 EMISSIONS AND CHARGE RATES
UNCERTAINTY (Continued)
INDUSTRIAL PROCESS* PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN DATE'
PAGE 1
MAR 22*1977
MODIFIED
sec
303000000
303001000
303002000
303003000
303004000
303005000
303006000
303007000
+
+
+
TACRP
(SCC UNITS)
8970700.
4222000.
HW8:
68177000.
68177000.
158690.
158690.
952170.
952170.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
.003
.010
NEGLIGIBLE
NEGLIGIBLE
BftKHt!
NEGLIGIBLE
BLE
BLE
BLE
gGL
NEGL
NEGL
fiftt
NEGL
NEGL
_.
g:
G:
G:
BLE
BLE
.043
.116
NEGLIGIBLE
NEGLIGIBLE
+ 3.647
- 2.575
NEGLIGI3LI
NEGLIGI3L1
Ni£LiGI3LE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
+ .0'
- .1.
* .0(
- .Oi
NEGLIG
NEGLIG
mil
NEGLIG:
NEGLIG]
%2
L6
51
13
:BLE
BLE
BLE
BLE
8LE
BLE
.01;
,03'
.000
,000
GIBLI
GIBll
NEGL
NEGL
NEGL]
NEGL
NEGLIGIBLI
NEGLIGIBLE
* .151
- .124
+ .096
- .022
(8
9
* .011
- .011
+ .056
- .056
+ .076
- .076
* .026
- .018
* .001
- .001
MSCC
Source Category
Charge Rate Unit
303000000 Primary Metals
N. A.
303001000 Aluminum reduction
303002000 Aluminum ore calcined
303003000 Coke metallurgical
303004000 Coke beehive
303005000 Copper smelters
303006000 I erroalloy production (open furnace)
303007000 Ferroalloy production (closed furnace)
aN, A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
Aluminum, tons/yr
Tons/yr
Coal, tons/yr
Coal, tons/yr
N. A.
Tons/yr
-------
Table 1-11-b.
SUMMARY OF 1981 EMISSIONS AND CHARGE L.iTES
UNCERTAINTY (Continued)
I
~J
00
INDUSTRIAL PROCESS* PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN OAT=«
PAGE 2
MAR 22,1977
"°8KKD .001
NEGLIGIBLE NEGLIGIBLE - .001
* .000 «• .000 * .013
- .001 - .002 - .013
Charge Rate Unit
N.A.
Tons /yr
N.A.-
N.A.
N.A.
Tons /yr
processes Tons/yr
aN.. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
-------
Table i-U-b. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN DATE'
MAR
PAGE 1
22,1977
MODIFIED
SCC
306000000
306001000
306002000
306003000
306008000
306012000
TACRP
(SCC UNITS!
201800.
201800.
29161.
25161.
1642900.
16*2900.
14323.
14323.
NOX
EMISSIONS (MILLIONS OF TONS / YEAR)
HC
CO
* .034
- .034
* .034
- .034
+ .007
- .007
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* .049
- ,049
* .007
- .007
+ .023 .
- .023
* .001
- .001
+ .042
- .043
NEGLIGIBLE
NEGLIGIBLE
+ 6.377
- 6.877
*• .007
- .007
«• 6.877
- 6.877
* .047
- .047
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
* .017
- .017
* .007
- .007
«• .015
- .015
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
+ .004
- .004
MSCC
Source Category
Charge Rate Unit
306000000 Petroleum Industry
306001000 Process heater
306002000 Fluid catalytic crackers
306003000 Moving bed catalytic crackers
306008000 Miscellaneous leakage
306012000 Fluid coking
N.A.
1000 bbl/yr
1000 bbl/yr
1000 bbl
capacity/yr
1000 bbl feed/yr
''N.A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of l«*o or more MSCCs whose charge rates are different.
-------
Table 1-ii-b. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATF*
MODIflED
SCC
TACRP
ISCC UNITS*
EMISSIONS (MILLIONS OF TONS
NOX HC CO
I
00
o
400000000
401000000
401001000
401002000
401999000
+
*
*
MSCC
400000000
401000000
401001000
401002000
401999000
33470.
20053.
100730.
97631.
32003.
32003.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGklG BLE
NEGLIG BLE
NEGLIGIBLE
NEGLIGIBLE
KEGLIG BLE
NEGLIGIBLE
«• .580
- .459
+ .094
- .089
+ .006
- .001
* .093
- .088
+ .015
- .014
Source Category
Point Source
Evaporation
Cleaning Solvents
Dry cleaning
Degreasing
Miscellaneous solvent use
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Charge Rate Unita
N. A.
N.A.
Clothes, tons/yr
Solvent, tons/yr
Solvent, tons/yr
PAGE 1
MAR 22*1977
/ YEAR)
PART
«• .003
- .003
NEGLIGIBLE
NEGLIGIBLE
aN. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
number is made up of two or more MSCCs whose charge rates are different.
NEGL
NEGL
NEGL
NEGL
NEGL
6L
BLi
BLI
BLL
Bit
NEGLIGIBLE
-------
Table 1-11-b. SUMMARY OF 1981 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
oo
TACR AND EMISSION
IED
HYDROCARBON EVAPORATION
UNCERTAINTIES PROJECTED TO 1981
RUN DATE'
402000000
402001000
402002000
402003000
402004000
402005000
402006000
402007000
402008000
402999000
•*•
*
4
*
RP
INITS)
6845000.
6138800.
76850.
76850.
6826800.
6118500.
iiliS:
fin;:
mil:
ItttiS:
mm-.
58855.
58855,
432910.
432910.
EMISSIONS (MILLIONS OF TONS
NQX HC CO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGI8L1
NEGLIGI8LI
EB1
NEG
mm
mm
mm
M
NE
N|
NE
N!
NEGLIGIBLE
II
[BLE
* .518
- .402
* .138
- .105
* .260
- .146
NEGLIGIBLE
NEGLIGIBLE
PAGE 2
MAR 22*1977
/ fEAR)
PART
* ,003
• .003
NEGLIGIBLE NEGLIGIBLE
H i :8il H
+ .080
- .066
i :J||
* Io52
* Io95
- .095
EGLIGIBLI
EGLIGIBLI
HiititJI
NEGLIGIBLi
NEGLIGIBLf
NEGLIGIBLi
NEGLIGIB
NEGLIGIB
N(
R!
D!
»!
I R
ILIGI
ml
LE
LE
mm\
iitftil
NEGLIGIBLE
NEGLIGIB
NEGLIGIBLI
NEGLIGIBLE
NEGLIGIBLE
* ,003
- .003
MSCC
Source Category
Charge Rate Unit
402000000 Surface Coating
Coating, tons/yr
402001000
402002000
402003000
402004000
402005000
402006000
402007000
402008000
402999000
Paint
Paper coatings
Varnish and shellac
Lacquer
Enamel
Primer
Fabric coatings
Oven coatings
Miscellaneous coatings
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
tons /yr
tons/yr
tons/yr
tons/yr
tons/yr
tons/yr
tons/yr
tona/yr
tons/yr
-------
I
00
406001000
406002000
Table 1-11-b. SUMMARY OF 1981
TACR AND EMISSION UNCERTAI
MODIFIED
403000000
403001000
403002000
403003000 +
403999000 +
406000000 +
EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
HYDROCARBON EVAPORATION PAGE 3
NTIES PROJECTED TO 1981 RUN DATE' MAR 22*1977
EMISSIONS {MILLIONS OF TONS / YEAR)
814980.
814980.
18111000.
15000000.
40178000.
20606000.
15906000.
O
O
504600
NOX
NEGLIGIBLE
NEGLIGIBLE
ill
NEGL]
NEGLI-,
NEGLIG1
NEGLIGIBLE
Kiitiiiltf
NEGLIGIBLE
* .163
- .167
.025
.077
.084
.069
152
GLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
ttigtigitti m
NEGLI^
NEGLIi
NEGLIS
[BLE
BLi
BL!
N£(
NT
NEGL
gliirf
GIBLE
GIBLE
[GIBLi
NEGLIGIBLE NEGLIGIBLE
fltftigmt Riitisiiti
- .102
NEGLIGIBLE
mmmi
NEGLIGIBLE
NEGLIGIBLE
mwm
NEGLIGIBLE
MSCC
Source Category
Charge Rate Unita
403000000 Petroleum Storage
N. A.
403001000
403002000
403003000
403999000
Fixed roof
Floating roof
Variable vapor space
Miscellaneous storage
N. A.
N. A.
1000 gal/yr
1000 gal/yr
406000000 Petroleum Marketing and Transportation 1000 gal/yr
406001000 Rail and truck transportation
406002000 Marine vessel transportation
1000 gal/yr
1000 gal/yr
N. A. (not applicable) is listed under "Charge Rate Unit" where the MSCC
— .-.-~,Wi,_ ;„ r^-^Ao ,,TI ,-,* *wr» <->T- m<->i-«* 'MKC~.CZa \vtiose charse rates are different.
-------
1>4 DATA ACQUISITION
1*4'1 Data Selected for Study
It was determined at the outset, by EPA, that this study
w° e restricted to stationary sources of emissions and that the emis-
sions of interest were oxides of nitrogen (NO ), carbon monoxide (CO),
hydrocarbons (HC), and particulate matter (PART). It was also agreed
that only point sources (as opposed to area sources) of emissions would
be studied. A point source, as defined by the National Emissions Data
System (NEDS), is a single stack or geographical point from which more
than 100 tons of a given identified air pollutant are discharged annually into
the atmosphere. The NEDS is described in detail in Ref. 1-1. The pro-
cesses which contribute to the atmospheric emissions studied and reported
here are described in Refs. 1-2 and 1-3.
The categories of emission sources initially selected for
study were determined from the NEDS nationwide emissions report (Ref.
1-4). The order of priority was based largely on the desire to study as
many stationary sources of the four emissions in as little time as possible.
Table 1-1Z shows the emissions from the categories selected for study. The
values are as reported in the NEDS Nationwide Emissions Summary,
January 10, 1975 (Ref. 1-4).
Table 1-12 shows that stationary area sources represent
from 13 to 30 percent of the emissions of interest. The categories selected
for study represent from 78 to 100 percent of the four point source emissions
identified in Ref. 1-4.
Of the categories inventoried in the first year of this study,
utility and industrial boilers and process gas combustion were studied
together and are reported in Section II under the more general category
"external combustion (boiler)." The process gas combustion category was
included in this study because an earlier NEDS nationwide emissions
summary (emissions as of December 19, 1973) indicated that nearly
1-83
-------
Table 1-12. STUDY LIST OF EMISSIONS x
Source Category
Utility Boilers
Industrial Boilers
Process Gas Combustion
Stationary 1C Engines
Petroleum Industry
Chemical Manufacturing
Evaporation
Primary Metals
Mineral Products
Secondary Metals
Wood Products
Point Source Emissions Selected
for Study
Remaining Point Source Emissions
Total Area Source Emissions
Total Stationary Source Emissions
Data extracted from Ref. 1-4,
Internal combustion (1C) engines.
Percent of Total Stationary
Source Emissions
NO
X
48.4
9.6
0.9
2.6
22. 6
1.1
-
0.1
1.4
0. 1
0.1
86.9
-
13. 1
100.0
HC
0.8
0.9
_
0.5
9-7
22.3
30.8
1.1
0.1
-
0.2
66.4
3.6
30.0
100.0
CO
0.8
1.0
_
0.1
13.9
18.4
-
24.3
0. 1
4.1
2.8
65.5
18.0
16.5
100.0
PART
23.1
9.8
0. 1
0.1
6.6
1.5
0.1
10. 1
25.4
1.1
2.9
80.8
4.7
14.5
100.0
1-84
-------
n a^ NO^ from stationary sources originated from process gas
ion. This information was supported by the large process gas com-
ustion rates listed in Ref. 1-4. Study of the actual data stored in the NEDS
( rom a data tape) showed that large errors in the original data for two users
o process gases accounted for nearly all of the previously reported nation-
wide process gas usage rates and, therefore, for nearly all of the reported
x emissions in this category. These errors were reported, checked, and
confirmed by the NEDS personnel, and greatly reduced NO emissions are
now as reported in Table 1-12.
The stationary internal combustion engines category, although
contributing only small quantities of emissions (Ref. 1-4), was chosen
because the NOx emissions could be very large, depending on the usage
rates of a large population (Ref. 1-5) of gasoline-fueled engines, each of
which is too small to be classed as a point source. Although emissions from
point sources in this category are small, the data are summarized, along
with a discussion of this critical area source problem, in Section III.
The chemical manufacturing and petroleum refinery cate-
gories were selected because of the high emissions of NO , CO, and HC.
ji
These categories are reported in Sections IV and V, respectively.
Although the categories under study have been referred to
as NEDS categories, the NEDS was not the only source, or even in so:ne
cases the major source, of original data. Extensive reviews of the litera-
ture were also conducted to obtain other original data as well as the
rationale for projection of the data into the future. The data obtained, con-
sisting of necessary calculations, sources, and results, are different for
each of the general categories studied, and discussions of these data are
contained in each of the following sections of this report. The NEDS data
acquisition and evaluation techniques were generally common to all
categories studied.
1.4.2 Preliminary NEDS Data Evaluation
In each study, a computer tape of all point source data
stored in the NEDS for the categories of interest were requested from EPA.
1-85
-------
Initially, the data contained on the tape were analyzed (by computer)
to determine the significant Source Classification Code (SCC). The NEDS
SCC is listed and described in Appendix A. 2 of Ref. 1-1. This summary of
emissions by the NEDS SCC was reviewed to determine those categories
containing the bulk of the four emissions. In most cases it was found that
a small numb"-*- of SCC categories accounted for nearly all of the emissions
^_ each type in the general cate^^ry chosen for study. Therefore, the total
of emissions of some types tor the entire general category chosen for study
was comparatively insignificant. Considering the rather large ranges of
uncertainty in the emissions from other major categories, it was not con-
sidered cost-effective to study these small categories. A general measure
used to rule out study of certain emissions within a general category or to
rule out study of certain SCCs altogether was based on one percent of the
total stationary point source emissions. If the sum of any one of the four
selected air pollution emissions over the entire general category was less
than one percent, emissions of that pollutant were neglected. In certain
groups of SCCs, none of the four emissions exceeded one percent, and these
SCCs were neglected.
Reference 1-1 lists all the SCCs represented on the NEDS
data tape in each of the general categories selected for study. Each data
section in this report shows those SCCs studied. The SCCs listed in the ".'
appropriate category in Ref. 1-1 but not listed in the corresponding data
section of this report were neglected for the above reasons. In cases
where any of the four air pollutants were negligible, the data printout
indicates "negligible."
The SCCs which were considered significant for one or more
of the emissions were then reviewed for data entries indicating excessive
process charge rates or emissions. The most commonly used technique to
check charge rates was to review the process state of the art, select a
large processing plant, and execute a computer search for point sources
with listed charge rates greater than this expected maximum. If such cases
were discovered, all of the data for that plant and point source were printed
1-86
-------
ur er review. Many cases were found, in this manner, where the
charge rates were 100 to 1000 times that considered reasonable for a
ge plant (in some cases even larger than the entire national capacity). In
mos categories, no equivalent reliable check could be devised, however,
for charge rates listed too low. After correction of the data for charge rates
listed too high, the corrected total was compared with other original data
from the literature.
Erroneously recorded emissions were checked by comparing
emission factors calculated from the NEDS tape data on emissions and
charge rates against the latest emission factors recorded in Ref. 1-2.
Some errors in the listed emissions were uncovered in this manner. A more
common error, however, resulted from the accepted practice of calculating
the emissions from the best estimate of emission factors and the charge
rate,,instead of from actual measurements. Since most of the data currently
stored in the NEDS was entered in the 1970 through 1972 time period,
emission factors were approximately those listed in Ref. 1-3. Corrections
in emission factors between the Ref. 1-3 listing and the subsequent listing
in Ref. 1-2 in some cases increased or decreased the emission factors by
factors of as much as 75 and 40, respectively.
1.4.3 Data Coding
The NEDS data categories are identified by an eight-dij.;it
number called the SCC. Where possible and where one or more emissions
in a given SCC were large, a further detailed breakdown of the data in that
SCC was effected. To facilitate handling of this more detailed data and yet
maintain close correspondence with the established NEDS SCC data coding
system, a modified SCC (MSCC) system was initiated for this study. A
ninth digit was added to all of the eight-digit NEDS SCCs to form the MSCCs
used in this study. All of the NEDS SCCs, then, appear in this study with
an additional zero in the last place of a nine-digit code number. Where
additional breakdown of data in a NEDS SCC was possible and desirable, the
last place in the nine-digit code of this study shows a nonzero digit. For
example, the NEDS SCC category 1-01-002-02 identifies raw, original data
1-87
-------
stored for the category: external combustion, boiler (1-xx-xxx-xx);
electric generation (1-01-xxx-xx); bituminous coal (i-01-0u2-xx); fired as
pulverized coal in dry-bottom boilers of capacity greater than 100 million
Btu/hr (1-01-002-02). This same general category is'identified in this
study by the MSCC 101002020. This MSCC, in this study, however, is con-
sidered a *~"rth-level summary because the additional breakdowns
101002021 through 101002024 nave been included to divide those data into
the boiler firing types: tangential, opposed, single-wall, and vertical,
respectively. These are now the data levels, and the MSCC 101002020
represents the sum of the emissions and charge rates of the four data SCCs.
Where practical the process assigned to each MSCC was the same as that
assigned by the NEDS to the corresponding SCC. In any case, the process
corresponding to each MSCC is defined in the first table of the respective
sections.
Although the data coding system used in this study
closely parallels that of the NEDS system, the data actually stored and used
in this study were acquired from a number of sources (including NEDS). The
original data base being accumulated in the data storage and handling pro-
gram at The Aerospace Corporation, then, represents a careful and
judicious sum from other sources as well as NEDS.
1. 5 DATA HANDLING AND STORAGE
The sheer volume of data being generated in this study
immediately dictates the use of a computer system for storage and handling^
After only the first year of study, 102 MSCC categories have been defined
for storage of significant data. In each of the MSCCs, 40 separate
bits of information must be entered into storage. In any particular MSCC,
a particular storage location may contain data either in the form of a
number or an indication that the particular data are negligible. Thus, a
total of 4080 data entries have already been entered into the program.
The general form of the data storage and handling program
is based on two major considerations:
1-88
-------
a- The data acquired from various sources represent
different points in time. Particularly because of the
rapidly changing energy picture, much of those data
may have changed considerably between the time of
acquisition and the time of this study. Data acquired
and stored in general categories at the beginning of
this study will be three years older at the time of
the first planned update. Users of the data need to
have available an estimate of emissions in the time
period of implementation of control systems (i.e.,
in the future) rather than at the time of planning.
b. Complete and accurate original data are difficult to
acquire. As a result, little good data are available,
and data from several sources are often widely
discrepant. As estimates of future emissions are
highly desirable, it is important to know how uncer-
tain these projections are.
1.5.1 Data Projections
In response to the need for current and future emissions
estimates as well as a set of values upon which these.estimates and projec-
tions can be evaluated as to their accuracy, a data storage and handling
program was developed. As in the NEDS summary system, emissions of
each of the four air pollutants NO , CO, HC, and PART are calculated
5x
from charge rates and emission factors:
Emissions = Emission Factor X Charge Rate (1-1)
For all four of the emissions in a single SCC, the charge
rate is the same and is fundamental data in itself. For that reason, storage
space is available for three values of the charge rate (with the appropriate
year of the data) for each MSCC.
For NO , CO, and HC emissions, the appropriate emission
3t
factors are entered directly and used with the charge rates as in Eq. (1-1)
to calculate emissions. As such, these emission factors directly reflect
the average degree of control of emissions in all processes represented by
the MSCC. Since the degree of control may change with time, either because
1-89
-------
of more effective control or more widespread application of the same degree
of control, the emission factor must be projected into the future indepen-
dently of the charge rates.
PART emissions, however, are normally controlled by
special hardware. Since these are recognizable pieces of hardware with
relatively v/**11-Qstablished PART collection efficiencies, both the
Collector efficiency and the degree of application of such collectors to
processes represented in the MSCC can be determined. The emission
factors in Eq. (1-1) for PART emissions, then, are calculated from an
uncontrolled emission factor for the process, a function of the average
collector efficiency, and the average degree of application of this average
collector:
PART Emission Factor = Uncontrolled Emission Factor X
(1 - Collector Efficiency) X
Fraction of Application of the
Collector (1-2)
It is assumed that the uncontrolled PART emission factor is fundamental
to the process and will not change with time. Both the average collector
efficiency and the degree of application of this average collector, however,
can change with time, and both must be projected independently into the
future.
Thus, six time dependent variables must be entered into the
program storage in order to calculate emissions of the four air pollutants
of interest: the latest charge rate, the three controlled emission factors,
the PART collector efficiency, and the degree of application of the PART
collector. Because of the widely varying sources of these data, they hardly
ever represent the same period in time. Therefore, the original data
cannot be meaningfully combined directly to calculate emissions. The data
1-90
-------
ge and handling program allows for three separate years of record for
(1) the latest charge rate, (2) all three controlled emission factors and the
PART control efficiency, and (3) the degree of PART control application.
Whenever emissions are calculated, according to Eqs. (1-1) and (1-2),
these time-dependent variables must be projected from their individual
years of record to the same date._
The projection of these six time-dependent variables into
the future required a time-dependent projection equation. In light of the
large uncertainties in the original data and the usual uncertainties of the
future, no more sophisticated equation than a straight line is justified.
Thus, for each of the six time-dependent variables, a linear slope with time
(a time derivative) must also be determined from appropriate rationale
(e.g., control equation efficiency and degree of application) and stored in
the data storage and handling program. All calculations of emissions thus
start with the original data for the six time-dependent variables, use the
six appropriate linear slopes to project these variables to some common
time, and then calculate emissions from the projected values according to
Eqs. (1-1) and (1-2). In this report, the charge rate and emission raw data
base are generated by projecting all of the data to the current year. A fur-
ther projection is made for five years into the future.
1. 5. 2 Data Uncertainties
The second major consideration in the development of the
data storage and handling program relates to the uncertainties in the data.
As related in Section 1. 4. 1, data have been found that were in error by two
and three orders of magnitude. Differences between independent original
sources of the same data are often as large as factors of two. The recent
wide variations in charge rates with time, resulting first from the impact
of environmental considerations and from the energy shortage, make projec-
tions into the future uncertain. If users of the data reported here intend to
give weight to certain emissions projected for different sources, then it
becomes important that the user have values of the uncertainty in those
emissions.
1-91
-------
Even an estimate of the uncertainties in the data is difficult
because of the lack of data. Adequate data are not available rom a suffi-
cient number of original sources that a reasonable statistical estimate of
uncertainty can be made. The use of small data sample statistics results
in unrealistically large uncertainties. In most cases, only two sources
(and sometimes only one source) are available.
Usually, however, certain engineering methods can be
followed in estimating realistic bounds on some given data or time-dependent
slope from better-known data. For example, current levels of total elec-
trical demand and total installed electric-generating capacity are reasonably
widely studied and well documented. By using engineering judgment to set
various realistic upper and lower bounds on less well-documented data,
such as a breakdown of electric-gene rating capacity into fuels, firing types^
and plant sizes, an engineering estimate of a reasonable uncertainty range
around the data on charge rates in large pulverized coal-fired, electric-
generating boilers can be obtained. It may also be possible, from a descrip-
tion of a particular study or survey, to make an engineering estimate of the
degree of completeness and accuracy of the results. Some cases remain
where no data other than a single estimate from the literature and the
corresponding NEDS data are available. In such cases, there is no
alternative other than to take the data as the average of the two available
estimates and the uncertainty range as the difference between the two.
Some fairly clear limits exist, or are defined here, on
projections into the future. In most cases, Aerospace familiarity with the
basic processes generating or controlling emissions is sufficient that lower
limits on emission factors can be estimated with reasonable confidence, at
least for the near future. These lower limits are stored in the data storage
and handling program, and the program will not allow the NO , CO, or HC
3C
emission factors (minus the uncertainty) to drop below these limits.
Similarly, upper limits are set on PART collector efficiencies. The degree
of application of a collector cannot exceed 1.0. Because of the social
1-92
-------
pressure in all areas to reduce air pollution, the assumption was made in
is program that the maximum value of a projected emission factor (the
projected nominal value plus the projected uncertainty) cannot exceed the
current maximum value (i.e., no increase in emission factors). Of course,
no charge rates or emissions, including uncertainties, are allowed to be
negative. Limits such as those discussed in this paragraph can result in
unsymmetrical uncertainties in projected data levels. For example, the
1975 NO emission for MSCC 101002000 is
1-046 x 1Q6 Tons
X 10
-0.348 Year*
The above discussion outlines the methods used and problems
encountered in generating engineering estimates of uncertainty in the data
shown in this report. The fact that it is so difficult to generate these esti-
mates underlines the need to provide the user with the documentation of the
uncertainty of these data. These uncertainties are not statistical quantities.
It is nece,ssary, however, to combine the uncertainty estimates of charge
rate, emission factor, collector efficiency, control equipment application .
data, and the derivatives of these with time slopes, to establish the
uncertainties of emission data projected into the future. In the data storage
and handling program, these are treated as statistical quantities (standard
deviation). The resulting uncertainties in the projected emissions are
considered engineering estimates.
1.6 REFERENCES
1_1. Guide for Compiling a Comprehensive Emission Inventory,
revised, APTD-1135, U- S. Environmental Protection
Agency, Research Triangle Park, North Caroline
(March 1973).
1_2. Compilation of Air Pollutant Emission Factors, 2nd ed. ,
AP-42, U.S. Environmental Protection Agency, Research
Triangle Park, North Carolina (April 1973).
1-93
-------
1-3. Compilation of Air Pollutant Emission Factors, AP-42,
U.S. Environmental Protection Agency, Research Triangle
Park, North Carolina (February 1972).
1-4. Nationwide Emissions Summary, National Emissions Data
System, U.S. Environmental Protection Agency, Research
Triangle Park, North Carolina (January 10, 1975). ;
1-5. W. U. Roessler, et al., Assessment of the Applicability of Auto-
motive Emission Control Technology to Stationary Engines,
EPA-65012-74-OM, The Aerospace Corporation, El Segundo,
California (July 1974).
1-94
-------
SECTION II
EXTERNAL COMBUSTION IN BOILERS
2. 1 INTRODUCTION
The external combustion (boiler) category of stationary
emission sources includes all of the fuels burned in stationary boilers for
the purpose of generating steam for electric generation and various other
industrial purposes. According to the National Emissions Data System
(NEDS) nationwide emissions report of January 10, 1975 (Ref. 2-1), this
category, at least in the 1970 to 1973 time period, represented the largest
single stationary source of both oxides of nitrogen (NO ) and particulate
3C
(PART) emissions. NO emissions of over 8 million tons per year repre-
•cV
sented about 59 percent of NO emissions from all stationary sources and
X.
about 36 percent of NO emissions from all sources inventoried by the NEDS.
j^
PART emissions of over 5 million tons per year represented about 33 per-
cent of PART emissions from all stationary sources and 31 percent of this
air pollutant emitted from all sources. Hydrocarbon (HC) and carbon mon-
oxide (CO) emissions from sources in this category represented less than
two percent, each, of those from all stationary sources. The external com-
bustion (boiler) category was the first to be studied in this continuing inven-
tory because of the large NOX and PART emissions.
A wide range of fuels is burned in external combustion boilers,
including the following:
a. Coal: anthracite, bituminous, and lignite
b. Oil: residual and distillate
2-1
-------
c. Gas: natural and processed
d. Wood
e. Bagasse
f. Coke
g. Liquified petroleum gas
h. Other minor fuels
Of the NO and PART generated from the external combustion of these fuels,
.X
for electric generation and various industrial purposes, in single sources
emitting more than 100 tons per year of these air pollutants (point sources),
the combustion of bituminous coal is by far the largest fuel source. More
than 58 and 88 percent of the NO and PART, respectively, from the exter-
j^
nal combustion, boiler category result from the combustion of bituminous
coal. Other fuel combustion which contributes significantly to the emission
of NO and PART includes that of natural gas and oil.
j^
At the time that the fuels to be studied in this portion of the
inventory were selected, the then existing NEDS emission summary (Ref, 2-2,
I
dated December 19, 1973) indicated that process gas combustion in industrial
boilers and heaters was the source of 2. 6 million tons per year of NO and
13 x 1
resulted from the annual combustion of more than 2X10 cu ft/year of suchl
gaseous fuels. This fuel category, therefore, was included in those to be
studied. During the study, it was found that large errors in the fuel usage
(annual charge rate) data submitted by two companies accounted for over
90 percent of the listed annual process gas combustion and more than 80 per-
cent of the listed NO emissions from process gas combustion. These errors
X.
have subsequently been corrected in the NEDS data bank. The NEDS emis-
sions inventory of January 10, 1975 (Ref. 2-1) indicates only about 11,000
tons per year of NO from combustion of process gas. Since this fuel cate-
3C
gory was studied, however, it is included in the projections in this section
even though the emissions are small or negligible. No significant effort was
made to estimate future changes in process gas usage rates or emission
factors.
2-2
-------
The fuels selected for study in this inventory were bituminous
coal, residual and distillate oil, natural gas, and process gas. These five
fuels account for 96 and 92 percent, respectively, of the NO and PART gen-
.X
erated from external combustion, electric generation, and industrial point
sources. All other fuels except lignite and wood represent sources of less
than one percent of these pollutants. Lignite represents the source of just
over one percent of the pollutants from this category and was neglected.
Wood combustion represents the source of nearly two percent and more than
four percent of the NO and PART, respectively, from this category. The
^^
more general category of wood products, including wood combustion, also
represents a significant source of CO emissions. As a result, study of the
more general categories related to wood use was not neglected but was
deferred to a later date.
2.2 SUMMARY
The NEDS Source Classification Code (SCC) for external com-
bustion (boiler) point source categories was modified according to the fuels
utilized in utility and industrial boilers and inventoried by this study.
Table 2-1, therefore, identifies the source categories studied according to
the Aerospace-developed Modified Source Classification Code (MSCC) and
presents the total annual charge rate projected (TACRP) unit for each
A summary of the 1975 and 1980 emissions and charge rates
for the external combustion (boiler) categories was compiled and is given in
Tables 2-2-a and 2-3-a, respectively, and in Tables 2-4-a and 2-5-a for
1976 and 1981. The uncertainties in the emission and charge rate data for
1975 and 1980 are given in Tables 2-2-b and 2-3-b, respectively, and in
Tables 2-4-b and 2-5-b for 1976 and 1981.
2.3 APPROACH
Study of fuel usage, emission factors, and projection data in
the external combustion (boiler) category was initiated in this study solely
from the available literature. In many areas, however, the available data
did not provide a sufficient breakdown of firing types nor sufficient multiple
sources to evaluate data accuracy (or uncertainty). As a result, a computer
(Continued on page 2-40)
2-3
-------
Table 2-1. Definition of External Combustion (Boiler) Proces,-
INJ
i
MSCC
101000000
101002000
101002010
101002020
101002021
101002022
101002023
101002024
101002030
101002040
101002050
101002060
101002070
101002080
101002090
101002100
101002110
101002120
101004000
101004010
101004011
101004012
Source Category
Utility Boilers
Bituminous coal
>10Q MMBtu/hr pulverized wet
>100 MMBtu/hr pulverized dry
Tangential firing
Opposed firing
Single -wall firing
Vertical firing
>100 MMBtu/hr cyclone
>100 MMBtu/hr spreader stoker
>100 MMBtu/hr overfeed stoker
10 to 100 MMBtu/hr pulverized wet
10 to 100 MMBtu/hr pulverized dry
10 to 100 MMBtu/hr overfeed stoker
10 to 100 MMBtu/hr underfeed stoker
<10 MMBtu/hr overfeed stoker
<10 MMBtu/hr underfeed stoker
<10 MMBtu/hr pulverized dry
Residual oil
>100 MMBtu/hr general
Tangential firing
Opposed firing
TACRP Unit
Tonj/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
-------
Table 2-1. Definition of External Combustion (Boiler) Processes (Continued)
i
m
MSCC
101004013
101004014
101004020
101004030
101005000
101005010
101005020
101005030
101006000
101006010
101006011
101006012
101006013
101006014
101006020
101006030
101007000
101007010
10100-7020
101007030
Source Category
Single-wall firing
Vertical firing
10 to 100 MMBtu/hr generala
<10 MMBtu/hr general
Distillate oil
>100 MMBtu/hr general
10 to 100 MMBtu/hr general
<10 MMBtu/hr general
Natural gas
>100 MMBtu/hr general
Tangential firing
Opposed firing
Single wall firing
Vertical firing
10 to 100 MMBtu/hr general
<10 MMBtu/hr general
Process gas
>100 MMBtu/hr general
10 to 100 MMBtu/hr general
<10 MMZLu/hr general
TACRP Unit
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yri
1000 gal/yr;
1000 gal/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
-------
Table 2-1. Definition of External Combustion (Boiler) Processes (Continued)
to
MSCC
102000000
102002000
102002010
102002020
102002030
102002040
102002050
102002060
102002070
102002080
102002090
102002100
102002110
102002120
102002130
102004000
102004010
102004020
102004030
Source Category
industrial Boilers
Bituminous coal
>100 MMBtu/hr pulverized wet
>100 MMBtu/hr pulverized dry
>100 MMBtu/hr cyclone
>100 MMBtu/hr spreader stoker
10 to 100 MMBtu/hr overfeed stoker
10 to 100 MMBtu/hr underfeed stoker
10 to 100 MMBtu/hr wet pulverized
10 to 100 MMBtu/hr dry pulverized
10 to 100 MMBtu/hr spreader stoker
<10 MMBtu/hr overfeed stoker
<10 MMBtu/hr underfeed stoker
<10 MMBtu/hr dry pulverized
<10 MMBtu/hr spreader stoker
Residual -oil -fired
>100 MMBtu/hr residual-oil-fired
1 to 10 MMBtu/hr residual-oil-fired
<10 MMBtu/hr residual-oil-fired
TACRP Unit
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
-------
Table 2-1. Definition of External Combustion (Boiler) Processes (Continued)
tv
MSCC
102005000
102005010
102005020
102005030
102006000
102006010
102006020
102006030
102007000
102007010
102007020
102007030
Source Category
Distillate-oil-fired
>100 MMBtu/hr distillate-oil-fired
10 to 100 MMBtu/hr distillate-oil-fired
<10 MMBtu/hr distillate-oil-fired
Natural-gas-fired
>100 MMBtu/hr natural-gas-fired
10 to 100 MMBtu/hr natural-gas-fired
<10 MMBtu/hr natural-gas-fired
Process gas-fired
>100 MMBtu/hr process gas-fired
10 to 100 MMBtu/hr process-gas-fired
<10 MMBtu/hr process-gas-fired
TACRP Unit
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
.Million British thermal units (MMBtu).
-------
Table 2-2-a. 1975 EXTERNAL COMBUSTION EMISSIONS AND CHARC , RATES
EXTERNAL CCMBUSTION, BOILER CATEGORY
PAGE 1
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1975
RUN DATE* MAR 22*1977
MODIFIED
SCC
101002000
101002010
101002020
101002021
101002022
101002023
101002024
101002030
101002040
101002050
L002060
^r •
8
1002070
002080
002090
002100
mm
101004000
101004010
101004011
101004QI2
101004013
101004014
101004020
101004030
101005000
101005010
101005020
101005030
TACRP
ISCC UNITS)
389250000.
45830000.
277100000.
146060000.
58780000.
57900000.
14360000.
54080000.
4200000.
1810000.
190000.
165580
8:
18210000.
17960000.
7184000.
5200000.
5200000.
376000.
240000.
10000.
0.
8:
0.
EMISSIONS (MILLIONS OF TQfS / 1TEAR)
NOX HC
4.897
.573
2.716
.974
.781
.769
.191
1.5C9
.031
.013
.002
.015
.003
.017
.000
O.i
.667
.658
.160
.232
.232
.034
.009
.000
0.000
8;
.070
.007
.050
.022
.009
.009
.011
.008
.002
.001
.000
.000
.000
:88J
0.000
.000
.018
.018
.007
.005
.005
.000
.000
.000
0.000
8
0.000
0.000
CO
.1^9
a39
.073
.029
.029
.007
.027
.004
.002
,000
.001
.000
°*°J9
• 001
.027
.027
.011
• 008
.008
.001
.000
.000
0.000
ft.rtftn
olooo
PART
4.205
.826
2.940
1.550
.624
.614
.152
.210
.088
.026
.007
.023
.006
°*82R
.055
.073
.072
.029
• 021
.021
. 002
I 000
0.000
«.ooo
. 000
0. 000
-------
Table 2-2-a. 1975 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES (Continued)
ANNUAL CHARGE
EXTERNAL
RATES AND EMISSI
CCM8USTION, BOILER CATEGORY
0*S PROJECTED TO 1975 RUN DATE'
PAGE 2
MAR 22*1977
MODIFIED
sec
101006000
101006010
101006011
101006012
101006013
' 101006014
! 101006020
| 101006030
i
j 101007000
i
101007010
mmm
102002000
102002010
102002020
102002030
181881818
102002060
02002070
02002080
02002090
02002100
02002110
18I881H8
102004000
102004010
102004020
TACRP
-------
Table 2-2-a. 1975 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RA ES (Continued)
EXTERNAL COMBUSTION* BOILER CATEGORY PAGE 3
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1975 RUN DATE- MAR 22*1977
MODIFIED
sec
102004030
102005000
102005010
wnm
102006000
1
102006010
!•• mmm
,1 102007000
° 102007010
103007020
102007030
TACRP
CSCC UNITS!
530000.
7060000.
5186000.
35200dO.
2060000.
mm-.
1749300.
1257000.
464000.
28260.
EMISS
NOX
.013
.169
.124
• 3C3
.177
•PJ2
.046
.OCO
.000
.000
.000
IONS (MILLIONS
HC
.001
.011
.008
.005
.003
•8R3-
.001
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
OF TONS /
CQ
.001
.014
.010
•m
.030
.oid
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
YEAR!
PART
.006
.053
.039
.032
.019
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 2-2-b. 1975 EXTERNAL COMBUSTION UNCERTAINTIES
EXTERNAL C
TACR AND EMISSION UNCERTAINTIES
MODIFIED
SCC
TACRP
(SCC UNITS)
OMBUSTIQN, BOILER CATEGORY
PROJECTED TO 1975 RUN DATE
EMISSIONS (MILLIONS OF
NOX
HC
TONS
CO
PAGE i
MAR 22,1977
/ YEAR)
PART
101002000
101002010
101002020
101002021
101002022
101002023
101002024
101002030
101002040
101002050
101002060
101002070
101002080
101002090
101002100
101002110
101002120
1
4
«•
4
4
.
4
4
4
•
4
4
.
4
•
4
4
•
4
•
4
4
4
—
4
11706000.
11708000.
4651900.
4651900.
9643300.
9643300.
8365000.
8365000.
3360300.
ff|?f§jj:
822190*.
822190.
4686100.
468&l5o.
632460.
632460.
172050.
172050.
29732.
HBi:
78102.
63245.
63249.
156200.
156200.
0.
8:
0.
mm*
4
4
«.'
4
4
.
4
"4
4
-
4
4
~
4
«p
4
4
—
4
•
1
4
4
—
4
.348
.348
.099
.099
:lil
.166
.166
.134
illl
^033
.033
• 218
.218
.006
.006
.002
.002
.001
.001
.003
.003
.001
• 0 01
1002
.000
0.000
0.000
.003
4
4
"
4
4
•
4
4
4
—
4
4
«•
4
—
4
4
•»
4
•
4
4
4
—
*•
:8?l
.005
.004
:8H
.017
.011
.068
:B||
!ooa
.001
.006
:88J-
.002
.001
.001
.000
*000
• 000
.000
• 000
• 001
.001
.000
.000
0.000
0.000
.000
4
+
•
1
4
—
4
*
4
•
+
4
•
4
—
4
4
•
4
«•
4
4
4
—
4
.069
.046
.017
.012
:8*i
.055
.037
.022
:8fl
*005
.004
.020
.014
.003
.002
• 001
.001
.000
.000
.001
eOOO
• 555
.000
• 002
.001
.000
.000
0.000
0.000
.001
4
4
—
4
4
»
4
4
4
•
4
4
•
4
—
4
4
•
4
•
4
4
4
—
4
•M
.271
.271
:!il
.282
. 282
• 113
m
.028
.028
.063
:§??
.027
.011
.011
.004
.004
.003
•Q93
.002
.002
• 009
.009
.000
.000
0.000
0.000
.042
-------
Table 2-2-b. 1975 EXTERNAL COMBUSTION UNCERTAINTIES (C<
EXTERNAL COMBUSTION, BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1975
RUN DATE*
PAGE 2
MAR 23,1977
HOggKO
101004000
101004010
101004011
101004012
101004013
101004014
101004020
101004030
101005000
101005010
101005020
101005030
101006000
101006010
101006011
TACRP
CSCC UNITS)
* 2111300.
2111300.
«• 2111309.
2111300.
* 1464800.
; itttuB:
i
4-
—
4-
—
+
••
4-
*
4-
4
4-
—
4-
—
4-
—
+
•
imm:
ln&3245t
63245.
0.
0.
0*
0.
0.
0.
8:
0.
8:
0.
590090.
590090.
589870.
589870.
265350.
265350.
EMISSIONS INILLIONS OF TONS /
NOX HC CO
* .094 4> .008 4- .012
- .094 - .006 - .008
* .094 4- .008 4- .012
- .094 - .006 - .008
+ .041 4> .036 * .009
~ «Qii * »QQi - »QQ6
+ .060 * Zoo? * :oo6
; :8I8
- .059
4- .008
- .008
* .001
- .001
4- .000
- .000
• o.oco
- 0.000
i 8:888
• 0.000
~ 0.000
+ 0.000
- 0.000
+ .139
- .139
* .139
- .139
* .034
- .034
; ;gg|
- .003
+ .000
- .000
4- .000
- ,000
4- .000
* .000
4- 0.000
- 0.000
i 8:888
+ 0.000
- 0.000
«• 0.000
- 0.000
4- .001
- .001
+ .001
- .001
• .000
- .000
;
;
-
4-
•
4>
—
+
—
+
4-
4-
-
4,
•
4-
-
4-
—
.004
.ooA
.00
.000
.000
.000
.000
.000
.000
0.000
0.000
£•999
0.000
0.000
0:000
0.000
.012
.009
.012
.009
.005
.004
YEAR!
4-
4-
4-
4>
4-
-
4-
•
4-
—
4-
-
4-
4-
^
-
+
-
1,
—
4-
—
PART
.008
.008
.008
.008
.006
• QQ6
• 004
tu04
.004
.000
.000
0.000
0.000
0.000
0.000
0.000
0.000
8:888
0.000
8:888
0.000
.00*
.00,
.004
.004
,002
. 002
-------
Table 2-2-b. 1975 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
Cs)
EXTERNAL
TACR AND EMISSION UNCERTAINTI
CCMBUSTION* BOILER CATEGORY
ES PROJECTED TO 1975 RUN
MODIFIED
SCC
101006012
101006013
101006014
101006020
101006030
101007000
101007010
101007020
101007030
102002000
102002010
102002020
102002030
102002040
102002050
102002060
4
*
4
—
4
4
-
+
—
4
"
4
—
4
—
4
—
*
4
_
•f
•*•
-
TACRP
(SCC UNITS)
427930.
30575 0.
305Z50.
30594^
16000,
16000.
1400.
1400.
15220.
15220.
15220.
NEGLliflfg-
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
6431600.
6431600.
796490.
796490.
4Q9140X).
4091400.
1486600.
1486600.
049500*
4049500.
106300.
106300.
884080.
884080.
EMISS
IONS
NOX
*
1
4
-
^
*
-
4
—
109
s no
J5!
811
016
004
8oO
000
000
000
* .000
NEC LJ
,000
tGlBLE
*
+
;
-
^
*
-
(MILLIONS
HC
001
888
000
QQQ
000
looo
NEGLIGIBLE
NEGL
iGisie
NEGLIGIBLE
Milt
{iflti
Klitfliiti NifLililti
NEGLIGIBLE
* .075
NEGL
+
- .075
* .014
*
- .014
4 .041
*
IGIBLE
.013
.010
.001
.000
• 001
- .041 - .001
> .046
; :83!
^ «
035
4 .001
- .001
* .007
+
*
—
*
4
- ,007
.001
:m
.009
.000
:88?
.002
OF TONS /
CO
«• .009
•_ A A t*
.UOo
4 ,006
* :88!
- .000
* »QQQ
* looo
- Tooo
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mmm
mmm
NEGLIGIBLE
+ .020
- ,014
* .002
- .001
4 .003
- .003
4 .002
; :m
_ . 012
4 .001
- -OQI
4 .003
- .002
PAGE 3
DATE» MAR 22,1977
YEAR)
PART
00
000
*
4-
*
- .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mmim
NEGLIGIBLE
* .190
- .190
.020
.020
.039
.089
.011
005
022
022
-------
Table 2-2-b. 1975 EXTERNAL COMBUSTION UNCERTAINTIES (C, dnued,
EXTERNAL C
TACR AND EMISSION UNCERTAINTIES
CMBUSTION, BOILER CATEGORY
PROJECTED TO 1975 RUN
DATE'
PAGE 4
MAR £2*1977
MODIFIED
sec
102002070
102002080
102002090
102002100
102002110
102002120
N 102002130
£ 102004000
102004010
102004020
102004030
102005000
i
102005010
102005020
102005030
102006000
TACRP
EMISSIONS {MILLIONS OF
CSCC UNITS!
4
—
4
4
4
—
4
—
4
4
4
—
4
•
4 -
•
4
—
4
-
4
4
.»
4
—
4
34409.
34439.
ttttH:
1811388:
34409^
12000.
12000.
8:
im*.
H 40100.
40100.
1062800.
1062800.
409140.
409140.
53073.
53073.
838110.
838110*
807220.
mm:
223730.
27724.
27724.
?8SiI8:
4
—
4
4
4.
_
4
—
4
4
4
-
4
<•»
4
— •
4
-
4
-
4
4
<•
4
—
4
NOX
.001
.001
• Q 5^
i81?
Toco
.000
.000
.oco
8:888
:881
?3
3
.083
.083
.042
.042
• OC6
.006
.060
.060
.057
*8fl
I013
.002
:8I4
+
•»
1
*
4
_
4
—
+.
4
4
•
+
—
4
— .
4
—
4
-
4
;
—
4
—
4
HC
.000
.009
:88t
.000
.000 -
.000
8:888
:888
•°iQ
.007
.009
.006
.005
.003
.001
.000
.006
.004
.006
\m
.001
.000
.000
•881
. WU«.
4
«•
1
-------
Table 2-2-b. 1975 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION, BOILER CATEGORY
to
i
TACR AMD EHISSION UNCERTAINTIES PROJECTED TO 1975
RUN DATE* MAR
PAGE
22*1977
MODIFIED
SCC
102006010 +
102006020 +
102006030 7
102007000 +
102007010 +
102007020 *
102007030 *
TACRP
(SCC UNITS)
8010*
_8010.
310540.
310540.
180280.
180280*
142990.
142990.
m
68100.
68100.
2800.
2800.
NOX
EMISSIONS (MILLIONS OF TONS / YEAR)
4- .030
- .032
* .017
- .018
4- ,000
- .000
.000
.000
.000
.000
4-
4-
HC
•RR1
.002
.001
- .001
4- .001
- .000
NEGLIGIBLE
NEGLIGIBLE
HfSHiMi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
CO
4- .006
4- *004
- .003
NEGLIGIBLE
NEGLIGIBLE
mmm
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
4-
4-
.003
.003
.002
.002
NEGLIGIBLE
NEGLIGIBLE
mmmi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 2-3-a. 1980 EXTERNAL COMBUSTION EMISSIONS AND CHAR J RA1ES
tv
i
EXTERNAL COMBUSTION* BOILER CATEGORY
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1980 RUN DATE
EMISSIONS (MILLIONS OF TONS
MODIFIED
sec
101002000
101002010
101002020
101002021
101002022
101002023
101002024
101002030
101002040
101002050
101002060
101002070
101002080
101002090
101002100
101002110
101002120
101004000
101004010
101004011
101004012
101004013
101004014
101005000
101005010
101005020
101005030
TACRP
(SCC UNITS)
459910000.
45830000.
338100000.
178210000.
71730000.
70650000.
17510000.
63030000.
4200000.
1810000.
190000.
1910200.
4400^0.
2350000.
30000.
0.
2020300.
26860000.
26610000.
10644000
770000
770000
0.
0.
0.
0.
NOX
4.688
.458
2.716
.975
.781
t769
.191
1.423
.025
.011
•891
.015
.003
.014
.000
0.000
.016
.245
.243
.059
.085
.085
.013
HC
.083
.007
.061
.027
'.013
.009
.002
.001
• 000
.000
.000
.001
.000
0.000
.000
.027
.027
.011
.008
•999
.001
PAGE 1
MAR 22,1977
YEAR)
'.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
CO
.234
.023
.169
.089
.036
.035
.009
.03
,00s
.002
.000
.001
.000
.002
.000
0.000
.001
.040.
.040
.016
.012
PART
4.001
.660
2.979
1.570
'. til
.154
.188
.066
.020
.005
.024
.005
.017
.000
0.000
.037
.107
.106
.043
.031
1
• 0(
0.000
0.000
0.000
0.000
0. 000
0.000
0.000
0.000
-------
Table 2-3-a. 1980 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES (Continued)
ANNUAL CHARGE
MODIFIED
SCC
101006000
101006010
101006011
101006012
101006013
101006014
101006020
101006030
101007000
18188ms
101007030
102002000
102002010
102002020
102002030
1020020*0
102002050
102002060
102002070
102002080
102002090
102002100
102002110
102002120
102002130
102004000
10200*010
102004020
EXTERNAL
RATES AND EHISS
TACRP
(SCC UNITSI
1986900.
1991000.
516000*
803000.
574000.
58000.
33000.
2900.
90390.
NEGLlI?!??*
NEGLIGIBLE
93319000.
8190000.
11330000.
10600000.
*!«8888:
7620000.
410000.
1170000.
10769000.
470000.
170000.
0.
590000.
15350000.
9700000.
4970000.
COMBUSTION* BOILER CATEGORY
IONS PROJECTED TO 1980 RUN DATE
NOX
.124
.122
.018
.056
.040
.008
.002
.000
.000
EMISSIONS (MILLIONS OF TONS
HC CO
.793
.082
.091
.240
.242
.011
.046
.004
,009
.065
.002
.000
0.000
• OC3
.138
.087
.045
.001
.001
.000
.000
.000
.000
.000
.000
.017
.017
.004
.007
.005
.000
.000
.000
PAGE 2
MAR 22*1977
/ YEAR)
PART
.015
.015
.004
.006
.004
.000
.000
.000
NEGLIGIBLE NEGLIGIBL
.037
.001
.002
.002
NEGLIGIBLE
1.287
.102
.192
.040
NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLI
.082
.004
.006
.005
.040
.002
.008
.000
.001
.011
.002
.001
0.000
.003
.031
.019
.010
.004
.000
.000
.005
.001
.000
0.000
.001
.023
.015
.007
.092
:8i2
.149
.003
.002
0.000
.005
.177
.112
.057
-------
Table 2-3 -a. i960 EXTERNAL COMBUSTION EMISSIONS AND CHARGE
£S (Continued)
IV
i
H»
00
EXTERNAL COHBUSTIONt BOILER CATEGORY
ANNUAL CHARGE
MOg^IED
102004030
102005000
102005010
102005020
102005030
102006000
102006010
102006020
102006030
102007000
102007010
102007020
102007030
RATES AND EMISSIONS
mlNffifrSI
680000.
8960000.
6586000.
2134000.
240000.
2320000.
1360000.
609000.
351000.
1749300,
1257000.
464000.
28260.
PROJECTED
NOX EMISSJ
.006
.061
.059
.019
.002
.147
.086
.039
.022
.000
.000
.000
,000
TO 1980
[QNS (MILLI
,001
.013
.010
.003
.000
.003
.002
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
RUN DATE* HAR
ONS OF TONS / Yf
.001
.018
.013
,004
.000
.0 :o
.012
.005
.003
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PAGE 3
22*1977
'AR)PART
.008
.067
.049
.016
.002
.021
.012
.005
.003
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 2-3-b. 1980 EXTERNAL COMBUSTION UNCERTAINTIES
EXTERNAL COMBUSTION, BOILER CATEGORY
ts>
I
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980
RUN DATE'
PAGi 1
MAR 22,1977
MODIFIED
SCC
TACRP
(SCC UNITS)
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
101002000
101002010
101002020
101002021
101002022
101002023
101002024
101002030
101002040
101002050
101002060
101002070
101002080
101002090
101002100
101002110
101002120
*
«•
*
+
—
*
—
•f
_
+
_
•f
—
*
—
+
4
_
•+
•
•f
—
+
•f
«.
+
_
•f
+
30577000.
30577000.
14835000.
14835000,
23282000.
23282000.
20194000.
20194000.
8108100.
8108100.
8032200.
8032200.
1989100.
1989100.
12952000.
12952000.
§•
.
500100.
98508.
98508.
215870.
215870.
mm-.
431740.
431740.
0.
0.
0.
0.
288620.
288620.
*
•
f
•f
-
*
—
+
•
• *
«•
+
—
+
—
*
*
«•
+
—
+
—
•»•
+•
•
+
—
*
•»•
.771
.771
.218
.218
.486
.486
.321
.321
.256
.256
.253
.253
.063
.063
.556
.556
.015
.015
.005
.005
.001
.001
.005
.005
\m
.005
.005
.000
.000
0.000
o.oco
.006
• OC6
+
-
*
+
-
*
—
+
-.
»
>.
+
-
*
—
+
*
•
*
-.
*
—
+
*
<•
+
—
•f
*
.118
.017
.006
.004
.113
.016
.021
.014
.082
.006
.081
•P.P5
.010
.001
.008
.005
jjjgf
• 001
.001
.000
.000
.000
.000
:888
.001
.001
.000
.000
0.000
0.000
.000
.000
*
-
+
•f
—
•f
—
•f
—
•f
—
•f
-
+
—
+
+
•
*
—
+
—
+
•»•
«»
•f
-.
*
-------
Table 2-3-b. 1980 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL C
TACR AND EMISSION UNCERTAINTIES
CHBUSTION, BOILER CATEGORY
PROJECTED TO 1980 RUN DATE'
PAGE I
MAR 22»1977
ro
MODIFIED
sec
101004000
101004010
101004011
101004012
101004013
101004014
101004020
° 101004030
101005000
101005010
101005020
101005030
101006000
101006010
101006011
TACRP
(SCC UNITS!
* 4618700.
4618700.
* 4618700.
4618700.
*• 3175500.
3175500.
+ 2403000.
?403000.
* ?337900.
£337900.
i mi:
i 8:
i
«.
—
•f
*
1
i mil
8:
0.
0.
8:
0.
0.
0.
0.
88:
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
* .155 *• .012 + .019 + .018
- .094 - .009 - .013 - .018
* .155 * .012 * .019 + .018
- .094 - .009 - .013 - .018
+ .068 * .009 + .013 + .013
- .027 - .006 - ,009 - .013
+ .098 * .006 + .010 * .010
- .063 - .005 - .007 - .010
* .098 * .006 * .0/0 + .009
- .063 - .005 - .007 - .009
+ .014 * .000 + .001 * .000
.Oil - .000 * .000 - .000
i :88I - :888 i :888 i 8:888
t
* 0
* 0
18
+ 0
- 0
* 0
- 0
:
+ 2028700. «•
1115300.
+ 911540. +
516000.
-.888
• oco
.000
:888
:888
.000
.000
:W
:ii!
.033
.018
^ •
•• .
* 0.
- 0.
18:
i8:
* 0.
- 0.
* .
~ .
T •
™ .
* .
"* .
888
909
090
888
888
000
000
m
881
009
000
t
•*•
"•
1
*
•f
•f
*
1
• flRft
.000
0.900
0.000
0.000
0.000
0.000
0.000
0.000
0.900
:8K
'.oil
.908
.004
18:
* 0*
- 0.
-*8:
M:
+ 0.
- 0.
+ .
" •
f .
" .
* *
~ .
888
000
000
000
000
000
000
000
000
Eoi
015
008
007
004
-------
Table 2-3-b. 1980 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION, BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980
RUN DATE'
PAGE 3
MAR 22*1977
MODIFIED
sec
101006012 4
101006013 4
101006014 4
101006020 +
101006030 4
101007000 4
101007010 4
101007020
101007030
102002000 *
102002010 *
102002020 *
102002030 4
102002040 *
102002050 4
102002060 4
TACRP
fSCC UNITS)
1472300.
mm:
58000.
56000.
33000.
4900.
2900.
15220.
15220.
15220.
SittiSltt
MEGLIGI3L
mm:
2226900.
2226900.
3977800.
288620?
288620.
1811188:
NOX
.106
EMISSIONS {MILLIONS OF T'lNS / YEAR)
i :8i9
- .008
i :8ffi
4 .000
- .000
4 .000
NEGLtSfiJLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
i :1»
.036
.036
.049
49
20
4
4
4
4
• ! .
*
.004
.004
HC
.001
.1
4
4
4
- .000
4 .000
- ,000
4 .000
- .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mimt
NEGLIGIBL
4
-
4
4
001
001
002
001
001
CO
.014
Nl
N!
:88?
.000
.001
.000
.000
.000
ELIGIBLE
illGIBLE
NEGLIGIBLE
fl
N
N
N
lit
[it!
:GL]
GIBLI
GIBLJ
.0
.0
14
14
4
4
*
4
.003
.002
:88?
.004
'.001
.001
PART
4 .011
* :88I
- .000
4 .000
- .000
* .000
- .000
NEGLIGIBLE
NEGLIGIBLE
GIBLE NEGL
NEGLIGIBLE
Riiti
Nf
Nf
tIBL
IBL
GIBLE
4 .039
- .039
4 .104
- .104
4 .021
•
Ion
- .012
-------
Table 2-3-b. 1980 EXTERNAL COMBUSTION UNCERTAINTIES (Continued*
EXTERNAL C
TACR AND EMISSION UNCERTAINTIES
CHBUSTION, BOILER CATEGORY
PROJECTED TO 1980 RUN DATE'
PAGE 4
MAR 22*1977
MODIFIED
sec
102002070
102002080
102002090
102002100
102002110
102002120.
102002130
102004000
102004010
102004020
102004030
102005000
102005010
102005020
102005030
4
4
4
—
4
«.
4
<•»
4
~
4
-
4-
— •
4
4
*
4
4
—
4
«W
4
«•»
4
TACRP
CSCC UNITS)
100020.
100020.
580000
580000
3002900
3002900
100020
100020
42000
42000.
0.
0.
197020.
197020.
1636600.
1686*00.
1608 600.
50060o!
500600.
79882.
79832.
2072900.
2072900.
1983000.
• OA3QOO.
600050.
600050.
70113.
70113,
4
4
1
_
4
_
4
•
4
~
4
-
4
•»
4
4
—
4
4
—
4
«
4
_
4
EMISS
NOX
.002
.002
.005
*028
.028
.001
• 001
.000
.000
0.000
0.000
.003
.002
.148
.060
:W
.067
.027
.009
.004
.096
.041
.091
. 0 39
• 029
.013
.003
.001
IONS
4
4
4
•
4
•
4
«•
4
—
4
—
4
•
4
4
"
4
4
—
4
~
4
•
4
(MILLIONS
HC
.000
.000
.000
.000
.004
.004
.000
.000
.000
.000
0.000
0.000
.001
.001
.013
.009
•PJi
.008
.006
.004
• QQ3-
• 001
.009
.006
.008
806
03
.902
.000
.000
OF
4
4
4
—
4
•
4
•
4
•»
4
•
4
^
4
4
•
4
4
"•
4
«•
4
«•
4
TONS /
CO
.OOi
.00'
.00
1009
.006
.001
.001
.000
.000
0.000
O.C 30
.002
• 002
.016
.011
:8t»
.007
.005
:881
• Oil
.008
• 010
.008
I002
.000
.000
YEAR)
4
4
4
—
4
••
4
•"
4
«•
4
^
•4
"*
4
4
•
4
4
~
4
*•
4
•
4
PART
.007
.007
• 012
• 012
.092
.093
.002
.002
.001
.001
0.000
0.000
.004
.003
.019
.019
:81i
1006
.006
.001
.001
.016
.016
.015
• 015
.005
• C ;
.001
.001
102006000
t :8?t
-------
Table 2-3-b. i960 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
t\>
i
102006010
102006020
102006030
102007000
102007010
102007020
102007030
TACRP
CSCC UNITS)
EXTERNAL COMBUSTION, BOILER CATEGORY
RUN DATE"
jr
«•
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980
NOX
2363500.
1360000.
1033800.
609000.
598020.
351000.
1
125700.
68100.
2800.
2800.
EMISSIONS (MILLIONS OF
HC
.158
- .086
* .069
- .039
000
* .00*
- .002
+ .002
- .001
- n
RHtigiiti
NEGLIGIBLE
• .000
* .000
- .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.010
.005
PAGE 5
MAR 22,1977
' """P.RT
«• .021
- .012
* .009
- .005
i :88!
HiEtKilti
NEGLIGIBLE
NEGL
NEGL
NEGL
GIBLE
GIBLE
GIBLE
mmm
NEGLIGIBLE
NEGL
NEGL
NEGL
GIBLE
GIBLE
GIBLE
-------
Table 2-4-a. 1976 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES
EXTERNAL CCMBUSTION, BOILER CATEGORY PAGE 1
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 19T6 RUN DATE- NAR 22*1977
MODIFIED
sec
101002000
101002010
101002020
101002021
101002022
101002023
101002024
101002030
101002040
101002050
101002060
• 101002070
" 101002080
*" 101002090
101002100
181881118
101004000
101004010
18188*81;
18188*811
18188*818
101005000
101005010
101005020
201005030
TACRP
(SCC UNITS)
403380000.
45830000.
289300000.
152490000.
61370000.
60450000.
14990000.
55870000.
4200000.
1810000.
190000*
1635600.
440000.
2350000.
30000.
1728708:
19940000.
19690000.
1128888:
57000QO.
414000.
240000.
10000*
0.
0.
0.
0.
EMISSIONS
NQX
4.880
.550
2.733
.981
.766
.774
.192
1.500
.030
.013
.002
.015
.OC3
.017
.000
0.000
.016
.620
.613
:I8
:ll!
:m
0.000
0.000
0.000
0.000
(MILLIONS
HC
.073
.007
.052
.023
.009
.009
.011
.008
.002
.001
.000
.000
.000
.001
.000
°:888
.020
.020
•88!
.006
:888
• 999
• 000
0.000
0.000
o.ogo
0.000
OF TONS /
CO
.206
.023
.145
.076
1030
.007
.OL3
.004
.002
.000
.001
.000
.002
.000
°:88?
.030
.030
:8il
•Ml
:888
0.000
0.000
0.000
0.000
YEAR)
PART
4.185
.793
2.966
1.563
.629
.620
.154
.207
.084
.025
.007
.024
.006
.022
.000
°:8?i
.080
.079
:8!i
:8§l
:88i
0.000
0.000
0.000
o.ooo
-------
Table 2-4-a. 1976 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES (Continued)
tv
i
ANNUAL CHARGE
MODIFIED
SCC
101006000
101006010
urnmi
101006013
101006014
101006020
101006030
101007000
101007010
102002000
1020020*0
181881818
immu
102002110
102002120
102002130
10200*000
10200*010
10200*020
EXTERNAL
RATES AND EMISS
TACRP
-------
Table 2-4-a. 1976 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RA US (Continued)
to
ANNUAL CHARGE
EXTERNAL C
RATES AND EMISSIO
CMBUSTION* BOILER CATEGORY PAGE 3
*S PROJECTED TO 1976 RUN DATE- HAR 22*1977
MODIFIED
sec
102004030
102005000
102005010
102005020
102005030
102006000
102006010
mmm
102007000
102007010
102007020
102007030
TACRP
CSCC UNITS*
560000.
7440000.
5466000.
1774000.
200000.
3280000.
1920000.
361000.
499000.
1749300.
1257000.
464000.
28260.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
.012
.156
.115
.037
.004
.267
.156
:8fl
.000
:888
.000
.001
.011
.008
.003
.000
.005
.003
*&£}
• 001
NEGLIGIBLE
Bittitiltf
NEGLIGIBLE
.001
.015
.011
.004
.000
.028
.016
-.m
NEGLIGIBLE
Ristfgitti
NEGLIGIBLE
.006
.056
.041
.013
.002
.030
.017
.008
NEGLIGIBLE
flfttiEiiti
NEGLIGIBLE
-------
Table 2-4-b. 1976 EXTERNAL COMBUSTION UNCERTAINTIES
N
IV
-J
EXTERNAL CCMBUSTION, BOILER CATEGORY PAGE 1
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE« MAR 22*1977
"°?&IEO 4
0. .000
101002110
101002120
4
+
—
0
0
138920
138920
.
•
4 0.000 4
- o.ooo
. 4 .003 4
•
- .OC3
.
•
0.
0.
•
.
m
101
013
018
012
0*1
m
005
003
001
881
002
002
001
001
888
888
888
001
001
000
000
000
000
000
000
*
4
-
+
^,
4-
4
_
+
-
4
+
—
4
—
i
t
4>
4
•
*
•
+
•
4-
—
:81!
.066
.044
.057
fg
3
;8J|
!oi5
.006
.004
:8II
*003
.002
.001
.001
:888
• OuO
.000
.002
.001
.000
.000
0.000
0.000
.001
.000
»
4-
-
4-
_
4-
4-
•
4-
-
4-
*
—
•f
—
4
1
4-
4
•
4
•"
4
—
4
—
9 £ ^f. O
• fc f O
.385
.385
.334
• 334
. 134
zHI
.133
.033
.033
:8ti
*030
.030
.011
.011
.004
.004
:88!
:88i
.009
.009
.000
.000
0.000
0.000
.044
.044
-------
Table 2-4-b. 1976 EXTERNAL COMBUSTION UNCERTAINTIES (Coi .nued)
EXTERNAL CCMBUST10N, BOILER CATEGORY
i
oo
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE'
MODIFIED
sec
101004000
j
1 101004010
101004011
101004012
101004013
101004014
101004020
101004030
101005000
101005010
101005020
101005030
101006000
101006010
101006011
TACRP
CSCC UNITS)
+ 2516400.
2516400.
- Illltoo:
* 1740000.
; mm:
1295600.
i HiSf :
i 8:
+ 0.
0.
i 8:
i 8:
8:
* 0.
0.
+ 875870.
875870.
: 8?iit8:
+ 393580.
393580.
NOX
EMISSIONS
.103
.103
.045
.045
.066
.066
.065
.065
.008
.008
*000
.000
i«:
i 8:888
«• O.OCO
- 0.000
* 0.000
- 0.000
.176
.176
* .043
- .043
(MILLIONS OF TONS
HC CO
• .009
- .006
i :m
• .006
- .004
+ .004
- .003
• .000
- ;ooo
* .000
- .000
* 0.000
. 0.000
«• 0.000
- 0.000
* ,001
- .001
+ .000
- .000
* .014
- .009
* .014
- .009
* .009
- .006
+ .007
- .005
* ,
+ .
> .000
- .000
* .000
- .000
i 8:888 i 8:888
PAGE 2
MAR 22*1977
/ YEAR)
PART
+ 0.000
- 0.000
+ 0.000
- 0.000
* 0.000
- 0.000
+ .012
- .010
.006
.005
+ .010
- .010
* .007
- .007
* .005
- .005
* *&R1
+ 1000
- .000
* 0.000
- 0.000
+ 0.000
- 0.000
i8:
'.000
(.000
+ 0.000
- 0.000
* 0.000
- 0,000
.003
.003
-------
Table 2-4-b. 1976 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
CO
I
EXTERNAL COMBUSTION, BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE'
PAGE 3
HAR 22*1977
MODIFIED
SCC
101006012
101006013
101006014
101006020
101006030
101007000
101007010
101007020
101007030
102002000
102002010
102002020
102002030
102002040
102002050
102002060
TACRP
CSCC UNITS)
111118:
11118:
45398.
45398.
um:
,15220.
NEGLIGIBLE
7378300.
7378300.
1055900.
1055900.
1929400.
1929400.
5064200.
138920,
EMISSIONS (MILLIONS OF TONS /
NOX HC CO
YEAR)
•f
*
H
020
020
4- .000
• .000
NEGLIGIBLi
NEGLIGIBLI
Bit I? Iff
NbbL(6 loul
4- .089
- .089
* .017
- .017
.059
.059
.044
- .002
000
- .000
.011
.011
.001
.000
. i
.001
.001
.010
looo
.<
.1
001
001
N
NEGLIGIBLE NEGLIGIBLE
itiSffll
EGLIGIBLE
;LIGIBLi N
iCIGlBLfc N
GIBLE
GIBLE
EGLIGIBLE
.023
.016
.002
.002
— •»
4- .003
- .002
4- .021
i :8&i
- .001
PART
000
000
BHHEftti
Nc&L1bloLc
NEGLIG
EGLIG
EGLIG
EGLIG
EftH
BLE
BLE
BLE
BLE
* .209
- .209
* .024
- .024
* »°|2
4- toi3
- .013
4- .164
; :tti
- ,006
-------
Table 2-4-b. 1976 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION* BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE*
PAGE 4
MAR 22*1977
MODIFIED
sec
102002070
102002080
102002090
102002100
102002110
102002120
102002130
| 102004000
102004010
102004020
102004030
102005000
102005010
102005020
102005030
102006000
TACRP
(SCC UNITS!
* 46518.
46518.
4- 438630.
433630.
4- 2218500.
2218500.
* 46518.
; mil:
18000.
* 0.
0.
4- 86348.
86348.
i 11*1888:
4- 1136500.
1136500.
4- 420290.
420290.
4- 5C682.
56682.
* 1049700.
1049700.
* lpo§8Rp.
— 1008000.
+ 290690.
350631
+ 1226100.
1226100.
EMISSIONS (MILLIONS OF TONS /
NOX HC CO
4- .001 + .000 * .0 0
- .001 - .000 - .0 1
* .004 4- .000 *• .r ;0
* *019 * .004 * ?008
• .019
+ .OC1
* *88J
- toco
4- 0.000
• °'SS9
4- .001
- .001
^ :i8i
4- .090
- .090
* .045
- ,045
«• .006
- .006
4- .066
- .066
4- .062
«» • 0 ^y?
* .020
- I002
* .108
- .116
•
+
7
«»
4-
;
—
4>
«.
•
4-
*
"
t
4-
*•
*
*
4-
.004
.000
.000
.000
.000
0.000
°»888
.000
.000
:8o7
.009
.006
• 005
.003
.001
.000
.007
.005
.002
•.m
.000
.003
.002
«.
+
»
»»
4-
;
—
1
•
•
*
4-
—
4-
4-
^*
4-
I
4-
.005
.001
.901
cOOO
.000
o.ooo
0 000
.001
.001
:8o3
.012
.008
.006
.004
.001
.001
.008
.006
•881
. 006
.003
.002
.000
.000
.017
.014
YEAR!
4-
—
+
4-
«•
4-
4-
—
1
4.
—
1
4-'
-
1
4-
••>
4-
:
4-
PART
*. 010
.010
.086
.086
.001
:88l
.001
0.000
°:0°8i
.002
:8il
.013
.013
.005
.005
.001
.001
.008
.008
•S8i
. uuo
.002
- * A
.000
.000
.011
.011
-------
Table 2-4-b. 1976 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
I
CO
EXTERNAL CCMBUSTIQN, BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE-
PAGE 5
HA* 22*1977
NOggKO
102006010
102006020
102006030
102007000
102007010
102007020
102007030
TACRP
!SCC UNITS)
1109100.
125700.
68100.
2800.
2800.
NOX
EMISSIONS (MILLIONS OF TONS / YEAR}
+ .097
- .105
* .040
+
-
*
HC
.003
.002
.001
- -QSl
* .001
- .ol
•.m afftijEHtf
.000 NEGLIGIBLE
•.m mimti
.000 NEGLIGIBLE
•OCO NEGLIGIBLE
.000 NEGLIGIBLE
CO
* .015
- ,012
+ .007
- .003
flfgtttfiti
NEGLIGIBLE
mtimti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
+
PART
.010
010
004
Hiftittiti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 2-5-a. 1981 EXTERNAL COMBUSTION EMISSIONS AND CHAR ~" RAT
EXTERNAL COMBUSTION* BOILER CATEGORY
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981 RUN DATE*
MAR
PAGE 1
38*1977
OJ
MODIFIED
SCC
101002000
101002010
101002020
101002021
101002022
101002023
101002024
101002030
101002040
101002050
101002060
101002070
101002080
101002090
101002100
101002110
101002120
101004000
101004010
101004011
18188*811
101004014
m 004020
004030
101005000
101005010
101005020
101005030
TACRP
CSCC UNITS)
474040000.
45830000.
350300000.
184640000.
74320000.
73200000.
18140000.
6*t 320000.
4 '.00000.
1810000.
190000.
1978800.
440000.
2350000.
30000.
0.
2093200.
28590000.
28340000.
11336000.
604000.
0.
0.
£•
0*
EMISSIONS (MILLIONS OF TONS
NQX HC CO
4.609
.435
2.690
• 966
.774
.762
.189
1.400
.024
.010
.002
.015
.000
0.000
.016
.120
.119
.041
•
.005
•R2J
.000
0.000
0.000
0.000
0.000
.085
.007
.063
.028
.011
.011
.014
.010
.002
.001
.000
.000
•Ml
.000
0.000
.000
.029
.028
.011
• UUO
.001
.000
.000
0.000
0.000
0.000
0.003
YEAR)
.242
.023
.175
.092
.037
,037
.009
.0-1
.OCt
.002
.000
.001
.000
.002
.000
0.000
.001
.043
.043
.017
:8H
.001
.000
.000
0.000
0.000
0.000
0.000
PART
3.929
.626
2.960
1.560
.628
.618
.153
.182
.062
.018
.004
.024
.005
.016
.000
0.000
.032
.114
.113
.045
.002
,0*»*
.0./0
0.000
0.000
0.000
0.000
-------
Table 2-5-a. 1981 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES (Continued)
ts)
1
OJ
OJ
EXTERNAL COMBUSTION, BOILER CATEGORY
ANNUAL CHARGE RATES ANO EMISSIONS PROJECTED TO 1981 RUN DATE'
PAGE 2
MAR 22,1977
MODIFIED
sec
101006000
101006010
umm
mmm
mmm
101007000
101007010
101007020
101007030
102002000
102002010
102002020
102002030
102002040
102002050
102002060
mmm
102002090
102002100
102002110
102002120
102002130
102004000
102004010
102004020
TACRP
-------
Table 2-5-a. 1981 EXTERNAL COMBUSTION EMISSIONS AND CHARGE R, JES (Continued)
EXTERNAL COMBUSTION* BOILER CATEGORY
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
RUN OATE<
PAGE 3
MAR 22,1977
MODIFIED
sec
102004030
102005000
102005010
102005020
102005030
102006000
102006010
102006020
102006030
102007000
181887828
102007030
TACRP
(SCC UNITS)
710000.
9340000.
6866000.
2224000.
250000.
2080000,
1220000.
346000.
31-4000.
1749300.
1257QQQ.
464000.
28260.
EMISS
NOX
.004
• 056
.041
.013
.002
.123
.072
.032
.019
.OCO
.000
.000
.000
IONS (MILLI
HC
.001
.014
.010
.003
.000
.003
.002
.001
.000
NEGLIGIBLE
Hietmiti
NEGLIGIBLE
ONS OF TONS /
CO
.001
.019
.014
.004
.001
.018
.010
.005
.003
NEGLIGIBLE
NiEtismi
NEGLIGIBLE
YEAR}
PART
.008
.070
.051
.017
.002
.019
.011
.005
.003
NEGLIGIBLE
ffiftifilki
NEGLIGIBLE
-------
Table 2-5-b. 1981 EXTERNAL COMBUSTION UNCERTAINTIES
i
OJ
EXTERNAL CCMBUSTION, BOILER CATEGORY
TACR AND EHISSION UNCERTAINTIES PROJECTED TO 1981
MODIFIED
sec
101002000
101002010
101002020
101002021
101002022
101002023
101002024
101002030
101002040
101002050
101002060
101002070
101002080
101002090
101002100
101002110
101002120
<
4
-
4
*
4
•
4
*
I
—
4
-
1
4
»
+
—
1
•f
—
*
*^
*
—
4
7
_
1
TACRP
SCC UNITS)
34654000.
34654000.
16919000.
16919000.
26300000.
26300000.
22813000.
22 813000.
9159200.
3itt!88:
9074100*
2247200.
2247200.
14709000.
14709000.
2408300.
2408300.
568860.
568860.
mm-.
245150.
245150.
240830.
Z * 0 o «* Q •
490310.
490310.
0.
8:
0.
327570.
327570.
NOX
.872
.872
RUN DATE'
EMISSIONS (MILLIONS OF TONS
.549
.549
.362
.362
.269
4
4
- .285
* .071
- .071
4
4
4
.017
.017
.005
• OC5
.006
• OC6
.006
.006
.000
- 0.000
4 .006
- .006
4
4
HC
.123
.018
.122
.0
16
.022
.014
.085
. <
.002
* .002
- .002
+ .001
- .001
4 .000
• .000
4 .001
- .001
4 .000
- .000
4 0.000
- 0.000
4 .000
- .000
CO
.087
.059
.019
.014
.070
.048
.028
005
4 .004
- .003
4 .001
- .001
4 .001
- .001
4 .002
- .001
4 .000
- .000
4 0.000
- 0.000
4 .001
- .001
PAGE 1
MAR 22*1977
' ""'PART
.913
.913
.334
.334
.844
. •
144
.732
.732
.295
072
- . '
4 .045
- .044
4 .012
- .011
'.006
,006
4 .008
- .010
4 .000
- .000
4 0.000
- 0.000
* .030
- .032
-------
Table 2-5-b. 1981 EXTERNAL COMBUSTION UNCERTAINTIES (d. ..tinued)
u>
o
EXTERNAL COMBUSTION, BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE'
PAGE 2
MAR 22*1977
MODIFIED
sec
101004000
101004010
101004011
101004012
101004013
101004014
i
101004020
j 101004030
:
101005000
101005010
101005020
101005030
101006000
101006010
101006011
TACRP
CSCC UNITS)
+ 5192100.
5192100.
+ 5192100.
5192100.
4- 3567900.
3567900.
* 2703800.
; '4lml:
100000.
§,
•
0.
* 0.
0.
i 8:
+ 0.
0.
*• 0.
0,
- fft!i88:
+ 2317600.
1002800.
+ 1041300.
464000.
EMISSIONS
NOX
4>
••
4-
4
—
+
I
-
4-
4-
-•
4.
•
*
4-
—
t
1
•f-
-
4-
—
.178
.023
:JIf
.078
.013
:4H
.112
:8B
.003
,Ag3
°:888
0.000
0.000
0.000
8:888
o.oco
o.oco
0.000
0.000
.083
.032
.063
.032
.028
.012
+
•*
*
*
•
*-•
*
-
+
;
—
* 0
- 0
i8
* 0
- 0
* 0
- 0
!
+
—
*
-
(MILLIONS
HC
.013
.010
:8i3
.009
.007
.007
.095
.007
:m
.000
.000
1880
.000
.000
.000
:889
.000
.000
.000
.000
:o°81
.001
.001
.001
.000
OF
^
—
1
+
•
•f
;
—
4.
;
-
4-
"
i
V
—
*
:
4-
—
4.
—
TONS /
CO
.020
.014
.020
.014
»014
loio
.Df 7
.0 0
•ggjf
!ooo
.000
:888
.000
0.000
0.000
8:888
0.000
0.000
0.000
0.000
:8§i
.021
.009
.009
.004
YEAR)
4.
•
:
4.
.
4-
;
—
4
;
-
4
•
4-
4
—
t
4-
+
—
4
•
PART
.021
.021
I021
.014
.014
.011
:8H
!ooo
0.000
8:888
0.000
0.000
0.000
8:888
0.000
0.000
0.000
0.000
'oda
.017
.008
.008
.003
-------
Table 2-5-b. 1981 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
ro
i
EXTERNAL COMBUST ION, BOILER CATEGORY
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN OATE<
PAGE 3
HAR 32,1977
MODIFIED
SCC
101006012 *
101006013 +
10100601* +
101006020 +
101006030 +
101007000 +
101007010 +
101007020
101007030
102002000 *
102002010 *
102002020 *
102002030 *
102002040 *
102002050 *
102002060 *
TACRP
CSCC UNITSI
64000.
29000.
5600.
2600.
15220.
15220.
15220.
15220.
SiiHiiiti
14080000*
14080000.
2529900.
2529900.
m
45122
45122
\\
NOX
:88
EMISSIONS (MILLIONS OF TONS / YEAR)
.002
.001
.000
.000
.000
.000
.000
.000
fcEGLIGIBLI
NEGLI
GIBLI
+ ,1S7
- .197
* .042
- .042
+ h38
- .138
HC
000
000
000
- .000
NEGlIGIBLi
NEGLIGI8L!
NEGLIGIBLI
NEGLIGI8LI
NEGLIGIBU
NiGLIGIBLi
NEGLI6IBL
NEGLIGIBU
+ .018
- .018
.001
.001
.1
tool
.001
*
+
+
+ .003
- ,003
CO
.0
.0
.00]
- .000
NEGLIGIBLE
NEGLIGIBLE
Ni
Nf
* .037
- .027
* .004
- .003
*
.
* .005
- .004
* .007
- .005
PART
*
*
.000
•LI
•LI
000
IBLi
IBLI
Ni
Ni
Ni
Nf
N
N{
NEGLIGIBLI
NEGLIGIBLI
+ .327
- .328
+ .044
- .044
+ .023
- .023
.044
.048
-------
Table 2-5-b. 1981 EXTERNAL COMBUSTION UNCERTAINTIES (Cc dnued)
EXTERNAL COMBUSTION* BOILER CATEGORY
PAGE
CO
I
00
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE* MAR 22*1977
MODIFIED
sec
102002070
102002080
102002090
102002100
102002110
102002120
102002130
102004000
102004010
102004020
102004030
102005000
102005010
102005020
102005030
<
4
•
4
—
4
— .
4
—
1
4
4
—
4
4
_
4
—
4
-
4
-
*
4
_
4
TACRP
SCC UNITS)
113770.
113770.
624820.
624820.
3248600.
3248600.
113770.
113770.
48000.
48000.
0.
224398*
224890.
mms:
1753200.
1753200.
527580.
527580.
87002.
87002.
2344200.
2344200.
?iU888:
680730*
680730.
Hilt:
EMISSIONS (MILLIONS OF TONS /
NQX HC CO
4
•»
4
•m
4
.
4
—
4
4
^
•
4
4
_
4
—
4
—
4
—
4
4
—
4
.002
.002
.006
• 0 06
.031
.031
.001
.001
.000
.000
0.000
O.QQQ
. UC 3
.002
:4II
.146
.026
.075
.013
.010
.002
.105
.022
.021
.032
.007
:881
4
•
4
_
4
.
•f
-.
4
4
;
—
t
«.
_
4
—
4
—
4
—
*
4
—
1
.000
.000
.000
.000
.004
.004
.000
.000
• OQQ
olooo
°:88?
.001
:8Ji
.012
.008
.006
.004
.001
.001
.009
.006
• QQ?
.003
* 9^2
!o8o
4
•
4
_
4
••
4
—
1
4
4
mm
1
4
•
4
—
4
—
4
—
4
4
•»
t
.000
.000
.001
.000
.009
.006
.001
.001
:8*1
0.0 *0
°:88i
.002
:81S
.015
.011
.007
.005
.001
.001
.011
.009
*8oi
*003
.003
looo
YEAR)
PART
4 .007
- .008
4 .013
- .013
4 .092
- .096
4 .003
- .002
i :881
* 0.000
4 °!88?
- .004
i :8!1
* .020
— • 020
4 * 006
— .006
4 .001
- .001
4 .018
- .018
i :W
4 .LuJ»
- ,005
* .QQi
- .001
102006000
i :8fl
-------
Table 2-5-b. 1981 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
to
I
OJ
EXTERNAL CCNBUSTION* BOILER CATEGORY PAGE 5
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN DATE- MAR 22*1977
YEAR)
PART
* .024
- .011
* .011
- .005
+ .006
- .003
mmim
NEGLIGIBLE
Nfstfsfitf
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
MODIFIED
sec
102006010
102006020
102006030
102007000
102007010
102007020
102007030
TACRP
(SCC UNITS)
«• 2686900.
1220000.
«• 1180200.
546000.
+ 682640.
314000.
* tt!H8:
* 125700.
681 Oo!
+ 2800.
2800.
*•
*
1
*
EMISS
NOX
.166
.072
.073
.032
.042
.019
•282
.000
.000
-.m
.000
.000
.000
IONS (MILLIONS OF TONS /
HC CO
* .004
- .002
* .002
- .001
+ .001
- .000
mmm
NEGLIGIBLE
mum
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* .024
- .010
+ .011
- .005
* .006
- .003
MlirJilSrJ
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
tape was obtained from the NEDS data bank containing card ir ages of all
stored point source data for utility and industrial boilers, SCC 1-01-001-01
through 1-02-999-99 (see Ref. 2-3 for definition of terms and SCC categor-
ies). It was necessary to write computer programs to extract, summarize,
and check the data contained on this tape. Much of the literature search and
literature data analyses were completed by the time the NEDS tape data be-
came one in which complete data acquisition and projection was first accom-
plished from existing sources in the published (and some unpublished) litera-
ture. The NEDS tape data was used as a second data source, both to accom-
plish a further breakdown of some of the larger source categories into more
detailed firing types and to provide a means of estimating the accuracy, or
uncertainty, of the data.
In the special case of process gas combustion, the situation
was reversed in that little or no data existed in the literature but the NEDS
data indicated large fuel usage rates and NO emissions. In that case, only
.X
the NEDS tape data were examined in detail, and uncertainties were derived
from that data analysis alone. As discussed in Section 2. 1, the errors found
were sufficiently large to reduce that category to negligible proportions.
The SCC external combustion (boilers) category was subdivided
according to the fuels selected for study within this category, which are rep-
resented by 58 MSCC categories. In order to accomplish the type of linear
projections into the future, with cited uncertainties, as described in Section 1, a
total of 39 distinct input numbers had to be generated for eachMSCC. Thus, for
this category alone, a total of 2, 262 separate data entries had to be considered.
In general, initial efforts were made, from data in the litera-
ture, to estimate current values of fuel usage rates and emission factors.
The NEDS data were used to improve and confirm these estimates, provide
further breakdowns into finer categories, and estimate uncertainties in cur-
rent data levels. Methods of projecting data into the future could only be
derived from the literature and othler unpublished data sources. All data
sources were also used to estimate uncertainties in the projection methods
and the resulting levels projected .to 1980. The resulting data level
2-40
-------
estimates and uncertainties were then used to derive the linear slopes and
the uncertainties in these slopes.
Since the literature search and analyses of data from the liter-
ature provided a major source of current data and the only source of projec-
tion data and methods, these data and analyses are discussed in depth in Sec-
tion 2. 3. In most cases, the data finally used in the projections were reviewed
and somewhat modified (or established)by subsequent comparison with NEDS
tape derived data. A discussion of the NEDS data is contained in Section 2. 4.
2.4 DATA ANALYSIS FROM LITERATURE
Data in the literature can be divided into the source categories
of utility boilers and industrial boilers. Data concerning these two sources
are sufficiently different, both in depth and type, that separate data sources
and analyses were necessary to derive the desired data. Further, PART
control equipment efficiency and degree of application data represented a
special effort. Therefore, studies in these three areas were generally con-
ducted separately.
2.4. 1 Fuel Usage, NOY, HC, and CO Emissions in and
from Utility Boilers
An Edison Electric Institute (EEI) survey (Ref. 2-4) of : everal
hundred utility steam generator units provided data on boiler firing type, fuel
type, and unit megawatt electrical design capacity. This survey provided the
basis for a proportional breakdown of burner firing types categorized as fol-
lows: tangential, opposed wall, front or back wall, cyclone, and vertical.
The sample contained in the EEI survey was sufficiently large to be deemed
representative of the overall utility industry.
Since many utility stations were shown to have multifuel oper-
ating capability, a further time-related refinement was required. Annual
fuel usage statistics for multifuel-fired plants were sampled (Ref. 2-5). The
sample size chosen for analysis of these data was arbitrarily limited to utili-
ties with power capability exceeding ~400 MW. This was done for reasons of
manageability. The average proportions of annual usage of each fuel as
2-41
-------
reported for these stations (coal/oil, oil/gas, coal/oil/gas) /ere acquired.
In the analysis, data were weighted to account for differences in fuel heating
values. The proportional statistics for adjusted fuel consumption and break-
down by firing type were then used to develop a summary breakdown ex-
pressed as the percent of total energy output.
The total estimated 1973 electrical energy output of the United
States was 1.88 X 10 kW-hr (Ref. 2-6). The fossil-fueled steam electric
energy value of 1. 43 X 10 *2 kW-hr is about 76 percent of the total annual
output (Refs. 2-7 and 2-8). An average plant net heating rate of 10, 350 Btu/
kW-hr was selected as representative of the industry (Refs. 2-9 and 2-10).,
This equals an electrical conversion efficiency of 33 percent, a figure which
is somewhat below the most efficient of recently installed large units but which
conservatively accounts for many of the older units still in operation.
With these factors, tables were derived for electrical and heat
energy generation by firing type. The heating values for coal, oil, and gas,
taken as 25 X 10 Btu/ton, 142,800 Btu/gal, and 1050 Btu/cu ft, respectively,
enabled the determination of fuel consumption by firing type.
Emission factors published by the Environmental Protection
Agency (EPA) (Ref. 2-11) are given in pounds of pollutants per unit fuel
usage and are categorized by source. Additional data on tangential-fired
furnace emissions were obtained from other sources. (Refs. 2-12 and 2-13).
The product of fuel usage multiplied by the appropriate emission factor (CO,
HC, NO ) provided the detailed data breakdown for the stationary power plant
JL
emission inventory by boiler firing type.
Projections of emissions for 1980 involved establishment of
expected fuel usage figures for that year (Ref. 2-8). However, current
drastic changes in socioeconomic conditions may strongly affect actual over-
all electric energy demand in 1980 as well as the fuel mix used to supply
that demand. The differences between current fuel usage and the 1980 usage
estimates represent new construction.
Boiler construction figures by firing type were not readily
obtainable in the short time span of the study. Speculative consideration
2-42
-------
was given to recent trends showing that Combustion Engineering, supplier
of tangential furnaces, has shown increasing market penetration and is cur-
rently reported (Ref. 2-14) to be controlling about 43 percent of the new
boiler market. In addition, multifuel firing capability, already in common
practice, tends to favor a shift in this direction with coal remaining as the
predominant fuel, especially in view of uncertainties in the future availability
of oil and gas. Thus, the 1980 fuel usage breakdown, reflecting these
considerations, is based on the assumption that one half of the new con-
struction for fuel consumption (coal, oil, and gas) will be allocated to
tangential-fired units, and the remaining one half will be proportioned as
in 1973. The incremental fuel usage values were summed to the 1973
usages to obtain 1980 projections.
The new construction is expected to fulfill the EPA national
emissions requirements already legislated (Ref. 2-15). It is further antici-
pated that improvements in existing units will be forthcoming. Exploratory
efforts concerning the feasibility of reduced NO by means of combustion
modifications have shown promise in several investigations (Refs. 2-12,
2-16, and 2-17). Therefore, slightly lower emission factors were assumed
for NO emitted from existing facilities. Other studies which have been con-
ducted in this field are reported in Refs. 2-18 through 2-20.
For all coal-fired furnaces, it was assumed that the 19bO NO
x
emission factors could be reduced by 25 percent from the 1973 factors listed
in Ref. 2-11. NO emission factors estimated for coal in 1980, were
13. 5 Ib/ton for all pulverized firing and 41 Ib/ton for cyclone furnaces. The
1973 NO emission factors for gas and oil, converted to parts per million
X.
(PPM) in the flue gas, are 273 for oil and 238 for gas in tangential-fired
boilers and 572 for oil and 476 for gas in other firing types. Recent efforts
to reduce NO emissions in utility boilers indicate that simple, practical
combustion modifications can reduce NO emissions in both gas- and oil-
fired utility boilers at least to 200 parts per million. On the assumption
that this technology is currently available and will be widely implemented
3 A
by 1980, NO emission factors of 36 lb/10 gal of oil and 250 lb/10 cu ft
.X
of gas in all firing types were estimated.
2-43
-------
Although there is little well-documented info mation in the
technical literature, the popular media and personal observation of some
public and private utilities indicate that natural gas may disappear as a fuel
for electric generation well before 1980. Many utilities are already experi-
encing long seasonal periods during which natural gas fuels are not available.
Even the highly publicized Alaskan natural gas supply, when fully developed,
is expected to deliver less than 10 percent of the current demand in utility .
and industrial boilers alone. For these reaspns, projected natural gas usage
in utility and industrial boilers was estimated to decrease at a slope (and
slope uncertainty) which indicates zero usage as early as 1978. Consider-
ing the unsubstantiated quality of this type of popular data, however, the
uncertainty in this negative slope is large. The projected electrical demand
which would have been supplied by natural gas combustion was shifted to coal-
burning utilities and coal- and oil-burning industrial boilers.
In general, HC and CO emissipns from external combustion
boilers are low and usually well below the limits of any foreseen regulations.
For this reason, no effort was made to project changes in HC and CO emis-
sion factors. In all cases in this category, HC and CO slopes were con-
sidered equal to zero.
2.4.2 Fuel Usage, NO , HC, and CO Emissions in and from
.X n "" '"" ™«IN™««I«««^^
Industrial Boilers
The three major pieces of information needed to calculate the
industrial boiler emissions are the installed boiler capacity, the consump-
tion of each type of fuel, and the emission factors. Within the time con-
straints of this study, only a limited literature search and a survey of poten-
tial information sources were possible. For boiler capacity data, the only
source located was Ref. 2-21, in which were several tables based on infor-
mation in Ref. 2-22. In those tables, industrial boiler capacities were
given for 1967, with projections to 1975 and 1980, in terms of total steam
generation in pounds per hour. An estimate was made of the breakdown of
the 1967 total capacity into three size categories: 10 to 100, 100 to 250, and
2-44
-------
250 to 500 KPPH.* Sales data from Refs. 2-23 and 2-24 were used to project
how the total capacity would be divided into these three size ranges in 1973
and 1980.
The Ehrenfeld 1967 data given in Ref. 2-18 also included coal,
oil, and natural gas annual consumption for the industrial boilers. Using
heating values for the coal (25 X 10 Btu/ton), oil (6 X 10 Btu/bbl), and gas
(1050 Btu/cu ft) and assuming 1000 Btu/lb heat content of steam, it was pos-
sible to relate capacity data in heat output per hour to the annual heat input.
A factor of 3800 was derived, an average factor, in hours per year at rated
capacity operation. Lacking any later data along these lines, this factor was
used for all subsequent year calculations to relate boiler capacities to heat
input and thus to total annual fuel consumption.
Next, the total fuel consumption derived for 1973 and 1980
was divided among coal, oil, and gas. The boiler population data in Ref. 2-23
(for 1972) were used to estimate the 1973 fuel usage split. Although these
data are boiler number percentages rather than capacity percentages, there
are sufficient size categories that the two percentages should not be widely
different. For 1980, Battelle is currently working on such an estimate,
taking into account the energy supply situation; however, results were not
available in time for this study. Therefore, a best estimate was made on
the basis that the use of coal would show a sharp rise, both from new joilers
and conversion of existing units, with a smaller rise in oil consumption and
a decrease in natural gas use^ A rough guideline was the fuel breakdown
given in Ref. 2-23 for 1950 when coal was widely used in industrial boilers.
A further consideration was the greater tendency toward coal in large units
compared to the smaller sizes.
With boiler capacities and fuel consumption estimates in hand,
the emissions of NO , CO, and HC for 1968 and 1973 were calculated using
3£
the emission factors of Ref. 2-11. Emission factors for NO from gas-fired
ji.
boilers, given in Ref. 2-11 for industrial boilers, range from 120 to 230 lb/
10 cu ft from the smallest to the largest boilers. Rather than trying to
KPPH = thousands of pounds of steam per hour.
2-45
-------
interpolate and use multiple factors, an arithmetic average < f 175 was applied
to the total gas consumption. Since NO emissions from natural gas combus-
x ;;
tion represent only about 20 percent of th^ total, an error in using an average
emission factor should not significantly affect the total emissions.
In estimating probable NO emission factors for 1980, it was
JC
noted that there are currently no NO regulations for industrial boilers
X ; -
other than for new units larger than 250 milliqn Btu/hr heat input but that
some sort of control appears likely in the near future. Much of the NO
'>' 3£
control technology developed for utility bc-ilers should be directly applicable,
but the larger question concerns the degree to which new regulations will be
met in industrial boilers by 1980. For tfye 1980 projections, it was assumed
that the NO emission factors for coal firings will be reduced by 25 percent
•*».
(as in the case of utility boilers) but that NO emissions from gas and oil,-
I J^
firings will be reduced by 50 percent, rattier fchan the 58 to 65 percent re~
duction which appears likely for utility boilers. A summary of the 1973 NO
emission factors and those assumed in thj,s study for 1980, for both utility
and industrial boilers, is as follows: ,
Emission Factor
Fuel
Coal
Oil
Natural Gas
Emission
Factor
Unit
Ib/ton
Ib/ton
Ib/ton
lb/1000 gal
lb/1000 gal
Ib/million cu ft
lb/ million cu ft
Utilitie s
1973
18
55
-
50
105
300
600
1980
13.5
41
-
36
36
250
250
Industrial
1973
18
55
15
40
80
180
180
1980
13.5
41
11.25
20
40
90
90 _
As in the utility boiler category,
rently satisfactory, and the 1980
those of Ref. 2-11.
Stoker
Tangential
Other 'I
Tangential
Other 1
HC and CO emissions were considered cur-
emissipns factor used were unchanged from
2-46
-------
2.4.3
PART Emissions from Utility and Industrial Boilers
The PART emission category is different from those of NO
CO, and HC in that PART emissions are not only a function of the fuel type
but are also strongly dependent on the PART control equipment used. PART
emissions from gas- and oil-fired utility and industrial boilers represent
less than seven percent of the total from these sources. As a result, only
PART emissions from coal-fired boilers were examined in detail. For these
coal-fired boilers, the PART emission factors can be classified in the gen-
eral pulverized coal category and the more specific firing categories of stoker
and cyclone. For each of these categories, the annual PART emissions can
be calculated from the product of five factors: (1) coal usage rates, (2) aver-
age weight percent of ash in the coal, (3) ash factors, (4) average collector
efficiencies, and (5) fraction of total plants using the collectors to control
PART emissions. Data for each of these factors were obtained, respectively,
from (1) the reference sources and analyses discussed in the previous sections
plus Refs. 2-26 through 2-29 in the utility boiler area, (2) Ref. 2-25, (3) Ref.
2-11, (4) Ref. 2-25, and (5) Ref. 2-29 for utility boilers and Ref. 2-25 for
industrial boilers. The values of percent ash, ash factors, collector effi-
ciencies and control application [factors (2) through (5)] used to calculate 1967
to 1973 PART emissions in this analysis were as follows:
Utility Boilers
Boiler
Type
Pulverized
Stoker
Cyclone
Ash
Factor3-
16
13
3
Ash
11.9
11.2
11.8
Collector Control
Efficiency Application
0.92 0.97
0.80
0.91
0.87
0.79
Net
Control
0.89
0.70
0.72
Industrial Boilers
Pulverized
Stoker
Cyclone
16
13
3
10.6
10.2
10.3
0.85
0.85
0.82
0.95
0.62
0.91
0.81
0.53
0.75
lThe ash factor multiplied by the percent of ash yields the uncontrolled
emission factor.
2-47
-------
For projections to 1980 in the utility boiler area, the
assumption, based on data in Ref. 2-27, was that new construction would
be 85 percent of the pulverized category, 15 percent of the cyclone firing
type, and no new stoker construction. Application of control equipment to
new construction was assumed to be 100 percent.
In the industrial boiler area, EPA standards of perform-
ance for new stationary sources (Ref. 2-30) require control efficiencies of
about 0.988 (based on allowable emissions of 0.1 Ib/millionBtu and an average
coal ash content of 10. 4 percent), but these standards currently apply only
to boilers with a capacity greater than 250 million Btu/hr heat input. It was
assumed, therefore, that all new construction of boilers greater than 250
million Btu/hr capacity would be 100 percent controlled by the efficiency
rate of 0.988. No regulations for industrial boilers of smaller capacity are
currently forecast, and the control efficiencies and application (net control)
therefore, were assumed to be the same in 1980 as in 1973.
Since PART emissions from gas- and oil-fired boilers, both
utility and industrial, together represent a small fraction of those from coal-
fired boilers, little effort was made to estimate changes in control efficien-
cies or control applications. Even on the assumption of 100 percent uncon-
trolled gas- and oil-fired utility and industrial boilers, the PART emissions
from gas- and oil-firing projected to 1980 represent less than 7 percent of
the projected total from these sources. PART emissions from gas- and oil-
fired utility boilers were considered uncontrolled in all time periods. Con-
trols for industrial boilers were treated the same except that new construc-
tion in the capacity range greater than 250 million Btu/hr were assumed to
meet the EPA standards of performance for new stationary sources as given
in Ref. 2-26.
2.5 NEDS DATA ANALYSIS
The NEDS data are stored in a large number of SCC by type
of source (external combustion boiler, electric generation and industrial),
by fuel (e.g., bituminous coal, lignite), and to some degree by firing types
2-48
-------
(e.g., pulverized wet, cyclone, stoker) (Table A. 2 of Ref. 2-3). These
data represent a more detailed breakdown than was available in the litera-
ture for the boilers of this study. The NEDS data also contain a large amount
of detail on primary and secondary PART control equipment, categorized by
control equipment identification codes (Table A. 3 of Ref. 2-3), which does
not appear to be available anywhere else. For these reasons, it was con-
sidered desirable to obtain a magnetic tape of data stored in the NEDS sys-
tem for analysis. The availability of these in-house data on tape allowed
extensive computer analysis and represents a powerful tool for emis-
sion inventories and other studies. A comparison of some of the totals,
such as fuel usage and emissions, with data from other sources indicated
that the NEDS data were considerably more comprehensive. In all cases,
totals from various sources agreed as well as can be expected with the NEDS
data. The NEDS data were initially accumulated and stored over the time
period from about 1969 to 1972. Data available from other sources tend to
represent time periods from about 1968 to 1973. Comparing the NEDS data
with interpolated data for the same time period and considering the probable
accuracies of these other sources, the NEDS data appear to be in good
agreement.
Two significant problems with the NEDS tape data were found
during this study. Significant errors of unknown origin can exist in some of
the stored data. It appears that a single individual can submit data that are
grossly in error and this error can enter into and remain in the NEDS data
bank, undetected, grossly affecting all summary uses of the data. Annual
CO emissions from coal-fired utility boilers were found to be more than a
factor of five (more than 3 X 10 tons) too high. Two individuals submitting
data in the process gas combustion area may have entered fuel usage data
(total of several point sources within their plant) which were too high by fac-
13
tors of as much as 1000 (a total error of more than 2 X 10 cu ft/yr). Such
excessively high values can be detected with relative ease by screening the
data for charge rates (fuel usage) larger than that of a very large plant. For
2-49
-------
excessively small values, however, Aerospace was unable o develop
reliable, consistent methods for detecting errors or even to assure that
zero values were not valid. The best overall checks found in this study
involved correcting excessively high values and comparing the corrected
totals against data from other sources, if available. These problems led
to rather large estimates of the uncertainty of the final data.
The data stored in the NEDS were generated by many primary
sources over a period of several years. In many cases, the emissions rig-
corded were calculated from fuel usage rates and the then-current listing of
emission factors. Most of the emission factors used in compiling the NEDS
data are listed in the 1972 compilation (Ref. 2-3JL). From the 1972 compila-
tion to the 1973 compilation (Ref. 2-11), there were some very large changes;
Those important to this study are listed below:
Emission Factor Ratio,
Fuel Plant Type Emission 1973/1972
Coal
Oil Utility CO 75.0
20.0
Natural Gas Utility NO,, 1.538
0.025
42.5
0.075
42.5
The changes in emission factors between these two compilations do not
represent real changes in emissions but are more likely errors in the 1972
compilation, the first of its kind ever issued. In some cases, the emissions
found in the NEDS tape data analyses could be brought into line with data
from other sources by applying the above emission factor corrections. In
the case of CO from all fuels, however, the emission totals from the NEDS
tape analysis could not be brought into agreement with either the other sources
in the literature or the NEDS nationwide emissions reports, even when these
corrections were made.
2-50
Plant Type
None
Utility
Industrial
Utility
Utility ;
Utility
Industrial
Industrial
Emission
_
CO
CO
NOX
HC
CO
HC
CO
-------
Because of these problems, only the NEDS data which could
be roughly verified by some other source were used. Similarly, because of
the questions concerning the proper emission factors, the recorded NEDS
emission data were not used as such. Instead, the NEDS fuel usage data
were multiplied by 1973 emission factors obtained from Ref. 2-11. A check
of resulting emissions totals calculated in this manner showed reasonably
good agreement with direct NEDS emissions data, except as discussed in the
CO and the process gas category.
A further complication in using the NEDS point source data
(NEDS tape) results from the use of a number of fuels, concurrently or at
different times, in the same facility. The emissions, operating times,
PART control equipment, and compliance data (card nos. 3 through 5) are
combined, listed, and stored as single values for the facility, while fuel and
fuel usage data are listed separately by fuel (multiple cards no. 6). There
appears to be no way to determine those emissions or fractions of operating
time associated with each fuel. To generate total emissions data from the
NEDS tape, this study utilized data from facilities using only one fuel (single
card no. 6) to determine an effective emission factor for that SCC. Total
emissions for that fuel were then calculated from the total usage of that fuel
in that SCC. This procedure assumes that the emission factor for a given
fuel in a given facility is the same whether or not the facility operates with
multiple fuels. For example, there is some evidence in the literature that
NO emissions during gas firing may be higher for a significant period of
j£
operation if it was preceded by a period of oil firing. No solution for this
possible source of error was found.
One of the greatest values of the NEDS tape analysis is in the
extremely detailed breakdown of PART control equipment usage and perform-
ance. No other source of such detail in the use of PART control equipment
was identified. The data on the NEDS tape are such that further valuable
information such as collector efficiencies, degree of application, and use of
secondary collectors could also be developed. While such data were not of
interest to the current study, it appears that a powerful tool for further data
analysis is available.
2-51
-------
2.6 REFERENCES
2-1. Guide for Compiling a Comprehensive Emission Inventory,
Revised, APTD-1135, U.S. Environmental Protection Agency,
Research Triangle Park, North Carolina (March 1973).
2-2. Nationwide Emissions Summary, National Emissions Data
System, U.S. Environmental Protection Agency, Research
Triangle Park, North Carolina (January 10, 1975).
2-3. Guide for Compiling a Comprehensive Emission Inventory,
U.S. Environmental Protection Agency, Research Triangle
Park, North Carolina (March 1973).
2-4. Unpublished Edison Electric Institute tabulation of utility boilers
by firing type, fuels, and megawatt capacity (May 1973).
2-5. Keystone Coal Industry Manual, McGraw Hill Book Co. ,
Inc. , New York (1973).
2-6. Semi-Annual Electric Power Survey, Nos. 53 and 54,
Edison Electric Institute, New York (1973).
2-7. "Annual Statistical Report, " Electrical World (March 15, 1973).
2-8. The 1970 National Power Survey, Federal Power Commission,
Washington, B.C. (December 1971).
2-9. "The 18th Steam Station Cost Survey, " Electrical World
(November 1, 1973).
2-10. "The 1973 Annual Plant Design Report, " Power (November 1973).
2-11. Compilation of Air Pollutant Emission Factors, 2nd ed.,
U.S. Environmental Protection Agency, Research
Triangle Park, N^rth Carolina (April 1973).
2-12. Systems Study of Nitrogen Oxide Control Methods for
Stationery Sources, GR-2-NOS-69, Esso Research and -
Engineering Co. . (November 1969).
2-13. "Controlling NOX Emissions from Steam Generators, "
Journal of the Air Pollution Control Association,
23 (1) 37 (1973). 7"
2-52
-------
2-14. "New Generating Capacity, " Power Engineering, 77(4),
40 (April 1973).
2-15. Federal Register, 36, Part II (December 1971).
2-16. "Utility Boiler Operating Modes for Reduced Nitric
Oxide Emissions, " Journal of the Air Pollution
Control Association, jil_(ll) (November 1971).
/
2-17. "Operation of Scattergood Steam Plant Unit 3 Under Los Angeles
County Air Pollution Control District Rule 67 for Nitrogen
Oxides Emissions, " Intersociety Energy Conversion Engineering
Conference Proceedings, Society of Automotive Engineers,
New York (1971).
2-18. W. Bartok, et al., Systematic Field Study of NOY Control
Methods for Utility Boilers, ESSO Research and Engineering
Company, Linden, New Jersey; EPA Contract No. CPA 70-90;
NTIS No. PB210-739 (December 31, 1971).
2-19. " A. R. Crawford, et al., Field Testing; Application of Com-
bustion Modification to Control NOX Emissions from Utility
Boilers, EXXON Research and Engineering Company, Linden,
New Jersey; EPA Report No. EPA-650/2-74-066; NTIS No.
PB237-344/AS (June 1974).
2-20. A. R. Crawford, et al., "The Effect of Combustion Modifica-
tion on Pollutants and Equipment Performance of Power
Generation Equipment, " Proceedings of Stationary Source
Combustion Symposium, Vol. Ill, EXXON Research and
Engineering Company, Linden, New Jersey; EPA Repo:-t No.
EPA-600/2-76-152c; NTIS No. PB-257-146/AS; page IV-3.
(Contact R. E. Hall, Project Officer, Environmental Pro-
tection Agency, Research Triangle Park, North Carolina, to
obtain document. )
2-21. G. A. Cato, Survey of Industrial Boilers. 60- 17, KVB, Inc., Tus-
tin, California (October 31, 1973), EPA Contract No. 68-02-1074.
2-22. J. R. Ehrenfeld, et al., Systematic Study of Air Pollution
from Intermediate Size Fossil Fuel Combustion Equipment,
PB207110, Walden Research Corporation, Cambridge,
Massachusetts (July 1971).
2-23. D. W. Locklin, et al. , Design Trends and Operating Problems
in Combustion Modification of Industrial Boilers, Battelle
Memorial Institute, Columbus, Ohio; EPA Report No. EPA-
650/2-74-032; NTIS No. PB235-712/AS (April 1974).
2-53
-------
2-24. A. A. Putman, et al., Evaluation of National Boiler Inventory,
Bat ell e Memorial Institute, Columbus, Ohio (October 197 5 j;
EPA Report No. EPA-600/2-75-067. (Conta t C. C. Lee,
Project Officer, Environmental Protection Agency, IERL./
Cincinnati, 555 Ridge Avenue, Cincinnati, Ohio 45268,to
obtain document. )
2-25. Particulate Pollutant System Study, Vol. 1 - Mass Emissions,
Midwest Research Institute, Kansas City (1 May 1971),
Contract CPA 22-69- 104.
2-26. Technical and Economic Factors Associated •with Fly Ash
Utilization, TOR-0059(6781)-1, The Aerospace Corporation,
El Segundo, California (July 1971).
2-27. Minerals Yearbook, Vols. I and II, U.S. Department of
The Interior, Washington, D. C. (1967).
2-28. Keystone Coal Industry Manual, McGraw-Hill Book Co. ,
Inc. , New York (1970).
2-29. "llth Survey on Steam Station Design, " Electric World
(October 1970).
2-30. "Standards of Performance for New Stationary Sources,
EPA," Federal Register, 36 (247) (December 23, 1971).
2-31. Compilation of Air Pollutant Emission Factors, U.S.
Environmental Protection Agency, Research Triangle
Park, North Carolina (1972).
2-54
-------
SECTION in
STATIONARY INTERNAL COMBUSTION ENGINES
3. 1 INTRODUCTION
Stationary internal combustion (1C) engines include those used
for (1) electrical power generation, (2) industrial use, (3) commercial and
institutional application, and (4) engine testing. The fuels used in these
engines range from natural gas to crude oil. The types of engines include
diesel and spark ignition reciprocating engines and gas turbines.
Since by definition point source engines are those where one
Or more of the common emissions exceed 100 tons per year, it is to be
expected that many stationary engines fall into the area source category (all
stationary sources of pollution other than point sources). These engines'fail
to qualify as point source engines because of (1) a smallness in size, (2) a low
usage rate, (3) a low emission factor, or (4) a combination of these factors.
Although the emissions total (point source plus area so.urce)
for most types of stationary engines is not much larger than point source
only, four engine-fuel combinations were identified where area source emis-
sions are estimated to be significantly large simply because their populations
are enormous. These four engines are distillate-fueled and crude-oil-fueled
turbines and gasoline-fueled and diesel-fueled reciprocating engines.
This study concentrates on point sources of air pollution as
described in Section 3.3; Section 3.4 describes the assessment of the engine
categories that make significant contributions to both area and point source
emissions.
3-1
-------
3.2 SUMMARY
The point source stationary 1C engines studied along with their
modified source classification code (MSCC) numbers and MSCC charge rate
units are listed in Table 3-1. The 1975, 1980, 1976, and 1981 point source
charge rates and emission rates are shown respectively, in Tables 3-2-a,
3-3-a, 3-4-a, and 3-5-a and their uncertainties in Tables 3-2-b, 3-3-b,
3-4-b, and 3-5-b.
Point source 1C engines in 1980 will contribute about one-half
million tons per year of nitrogen oxides (NO ) and hydrocarbons (HC) and
Jt
about 60,000 tons of carbon monoxide (CO) annually. The annual area source
emissions for the four previously mentioned engines are estimated to be
about 3 million tons of NO , 1 million tons of HC, and about 13.5 million
3C
tons of CO. The largest contributor to stationary 1C engine pollution is the
conventional gasoline engine.
3.3 POINT SOURCES
This category jncludes. fixed installations of diesel and spark
ignition reciprocating engines and gas turbine engines. These engines are
used for electrical power generation and for industrial use such as pumps
for fuels, water, and sewage and compressors for gaseous fuels and air.
The three basic types of engines may be further subdivided into subtypes
such as two and four stroke, direct and indirect injection, and carburetion.
However, obtaining emissions from such breakdowns is
frustrated by a lack of a breakdown in annual fuel consumption and emission
factors by engine subtype. Thus, it is not possible to establish the effect
on the environment of variations in engine configuration, state of repair, or
specific application. Significant pollution contributors in this category are
listed in Table 3-1.
3. 3. 1 Diesel Engines
Diesel engines are used for electrical generation in oil and
gas pipelines, oil and gas exploration, and pumping water and sewage.
(Continued on page 3_ 16)
3-2
-------
Table 3-1. DEFINITION OF INTERNAL COMBUSTION PROCESSES
MSCC
Source Category
Charge Rate Unit
201000000 Internal Combustion
(Electrical Generating)
201001010 Distillate-oil-fueled turbine
201002010 Natural-gas-fueled turbine
201002020 Natural-gas-fueled reciprocating
201003010 Diesel-fueled reciprocating
201999970 Other, not classified
201999980 Other (not classified)
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
1000 gal/yr
Million cu ft/yr
1000 gal/yr
202000000
Internal Combustion (Industrial)
202001010 Distillate-oil-fueled turbine
202002010 Natural gas turbine
202002020 Natural gas reciprocating
202003010 Gasoline reciprocating
202004010 Diesel reciprocating
202999970 Other (not classified)
1000 gal/yr
Million cu ft/yr
Million cu ft/yr
1000 gal/yr
1000 gal/yr
Million cu ft/yr
3-3
-------
Table 3-2-a. 1975 INTERNAL COMBUSTION EMISSIONS AND CHARGE RATES
ANNUAL CHARGE
MODIFIED
201001000
201001010
201002000
201002010
201002020
201003000
201003010
201999000
201999970
201999980
202001000
202001010
202002000
202002010
2024)02020
202003000
202003010
202004000
202004010
202999000
202999970
INTER
RATES AND EMISSIO
TACRP
(SCC UNITSI
1088100.
1088100.
338860.
115840.
223020,
75159,
75159.
7258.
115600.
65953.
65953.
973960.
69322.
904640.
3470.
3470.
26201.
26201.
23828.
23828.
NAL COMBUSTION ENGINES
NS PROJECTED TO
EMISSIONS
NOX
.120
.120
.0%
. 0 20
.076
.011
.011
.017
.011
.006
.004
.OC4
.348
• Oil
.337
.000
.000
.005
.005
.OC3
.003
1975 RUN
(MILLIONS OF
HC
.002
.002
.001
.001
0.000
.001
.001
.083
.012
.072
.000
.000
.089
.003
.086
.000
.000
.000
.000
.172
.172
DATE* MAR
TONS / Yi
CO
.010
.310
.000
.000
0.000
.005
.005
.002
0.000
.002
.002
.002
.044
.003
.041
.003
.003
.002
.002
.001
.001
PAGE 1
22*1977
EAR)
.008
.008
.000
.000
0.000
.002
.002
.001
0.000
.001
.001
.001
.004
•88?
.004
.000
.00"
.000
.000
.000
.000
-------
Table 3-2-b. 1975 INTERNAL COMBUSTION UNCERTAINTIES
INTER
TACR AND EMISSION UNCERTAINTIES
NAL COMBUSTION ENGINES
PROJECTED TO 1975
RUN DATE'
PAGE 1
MAR 22.1977
MODIFIED
sec
201001000
201001010
201002000
201002010
201002020
oo
1
Ul
201003000
201003010
201999000
201999970
201999980
202001000
202001010
202002000
TACRP
CSCC UNITS)
«• 3320600.
1088100.
+ 3320600.,
1088100.
i mm-.
«• 417010.
115840.
* 23532.
23532.
* 14799.
14799.
+ 14799.
14799.
+ 1804.
1804.
* 18027.
18027.
+ 22224.
22224.
* 2222J-
22224.
* 616740.
174900.
EMISS
NQX
- :!8
+ .369
- .120
- :8II
* .072
- ,020
+ .008
- .008
+ .003
- .002
+ .003
• .002
* .OC3
- .003
+ .003
- .003
* .001
- .001
+ .001
- .001
i :88i
+ .111
- .061
IONS
+
*
+
I
:
i
*
I
i
i
*•
(MILLIONS
HC
.005
.002
.005
.002
.002
.001
.002
.001
0.000
0.000
.000
.000
.000
.000
.012
.012
:!!
.000
.000
:888
.039
.016
OF TONS /
CO
* .029
- .010
* .029
- .010
* .003
- .000
* .003
- .000
+ 0.000
- 0.000
* .002
- .001
* .002
- .001
4 .000
- .000
-* 8:888
* .000
- .000
+ .001
- .001
* •QQl
- .001
+ .024
- .008
YEAR)
*
-f
*
\
!
1
I
*
*
1
1
*
PART
.024
.008
.024
.008
.001
.000
.001
.000
0.000
0.000
.001
.001
.001
.001
.001
.001
0.000
0.000
.001
.001
.000
.000
:888
.005
.004
-------
Table 3-2-b. 1975 INTERNAL COMBUSTION UNCERTAINTIES (Continued)
OJ
I
INTERNAL COMBUSTION ENGINES
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1975 RUN DATE'
PAGE 2
MAR 22*1977
MODIFIED TACRP
sec (sec UNITS)
202002010 +
202002020 +
202003000 +
202003010 +
202004000 +
202004010 +
202999000 *
202999970 +
595470.
69322.
160580.
160580.
1172.
1172.
H?l:
1181?:
mi:
5925.
5925.
5925.
5925.
*
+
*
*
*
4-
*
EMISSIONS
NOX
.094
.011
.060
.060
.000
.000
• 000
• OCO
:88§
:88f
.001
.001
.001
.001
•f
•f
*
*
*
!
*
(MILLIONS OF
HC
.024
.003
.000
.000
.000
.000
• QP.3
• 000
• Q^Q
. 000
.175
.043
.175
.043
•f
*
•f
i
*
*
!
TONS / YEAR)
CO PART
.022
.003
:88f
.002
.001
:o°8?
:88i
:88I
.000
.000
.000
.000
+ .004
- .000
• .004
- .004
1- .000
- .000
* .000
- .000
i :888
+ . 000
— . 000
* .000
- .000
+ . 000
- .000
-------
Table 3-3-a. 1980 INTERNAL, COMBUSTION EMISSIONS AND CHARGE RATES
INTERNAL COMBUSTION ENGINES
PAGE 1
OJ
ANNUAL CHARGE
HONIED
201001000
201001010
201002000
201002010
201002020
201003000
j 201003010
201999000
201999970
201999980
202001000
202001010
202002000
202002010
202002020
202003000
202003010
202004000
202004010
202999000
202999970
RATES AND EMISSIONS
(SCC UNITS)
1275600.
1275600.
290630.
98582.
192050.
82909.
82909.
8089.
140600.
79753.
79753.
824330.
48187.
776140.
4627.
4627.
35626.
35626.
32923.
32923.
PROJECTED
NOX
.141
.141
.083
.017
.066
.012
.012
.019
.012
.007
.005
.005
.297
.008
.289
.001
.001
.006
.006
,005
.005
TO 1980
.ONS (MILl
.032
.002
.000
.000
0.000
.001
.001
.100
.013
.087
.000
.000
.076
.002
.074
.001
.001
.000
.000
.237
.237
RUN DATE*
.IONS OF TQNS
CO
.011
.011
.000
.000
0.000
.005
.005
.002
0.000
.002
.002
.002
.037
.002
.035
.004
.004
.003
.003
.301
.001
MAR 22*1977
/ YEAR)
PART
.009
.009
.000
.000
0.000
.002
.002
.002
0.000
.002
.001
.001
.004
.000
.003
.000
.000
.000
.000
.000
.000
-------
Table 3-3-b. 1980 INTERNAL COMBUSTION UNCERTAINTIES
INTERNAL COMBUSTION ENGINES
i
CXI
TACR AND EMI
MODIFIED
sec
201001000
201001010
1
201002000
201002010
201002020
201003000
201003010
201999000
201999970
201999980
202001000
202001010
202002000
SSI
4-
:
4-
+
1
4-
4-
;
*
4-
4-
ON UNCERTAI
TACRP
(SCC UNITS!
3472000.
1275600.
3472000.
1275600.
1 09070.
417Q7Q.
46677^
46677.
18635.
18635.
18635.
18635.
3163.
3163.
41231.
41231.
49437.
49437.
49437.
49437.
662170.
276270.
RUN DATE
NQX
EMISSIONS (MILLIONS OF TONS
HC CO
.387
.141
.387
i :8B
.016
.016
.003
.003
.003
.003
.005
.005
.005
.005
.002
.002
.003
.003
.003
.003
.139
.1C2
«• .005
- .002
* .005
- .002
+ 0.000
- 0.000
4- .000
- .000
4- .000
- .000
* .026
- .026
+ .005
- .005
* .026
- .026
* .000
- .000
* .030
- .011
* .030
- .011
+ .037
- .025
0.000
0.000
.002
.001
.002
.001
.001
.001
0.000
0.000
.001
.001
.001
.001
:88t
.026
.013
PAGE 1
MAR 22*1977
/ fEAR)
PART
4- .025
* ,009
+ .025
- ,009
T «
4- o.'ooo
- 0.000
+ .001
- .001
* .001
- .001
+ 0.000
- 0.000
* .001
- .001
+ .001
* .005
- .003
-------
Table 3-3-b. 1980 INTERNAL COMBUSTION UNCERTAINTIES (Continued)
sD
INTERNAL COMBUSTION ENGINES
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980
RUN DATE'
PAGE 2
HAR 23,1977
MODIFIED
sec
202002010
202002020
202003000
202003010
202004000
202004010
202999000
202999970
TACRP
(SCC UNITS)
+ 2720301
272030.
* 2311.
2311.
+ 2311.
2311.
+ 26452.
26452.
^ m&:
+ 14845.
14845.
i HIM:
€MISS
NQX
* act
- .101
* .oco
- .000
+ .oco
- .oco
I :881
i :885
* .002
- .002
* .QQ2
- .002
IONS
*
*
*•
*•
i
:
t
(MILLIONS
HC
tOE7
.026
.000
.000
.000
.000
• 000
. 000
:888
.253
.107
:fSf
OF
*
1
1
+
i
+
•f
TONS
CO
',013
.012
.003
.002
.003
.002
.002
.002
:88i
.001
.001
:881
/ YEAR!
i
i
!
*
i
*
*
PART
.004
.000
.003
.003
.000
.000
.000
.000
:SS8
:888
.000
.000
:888
-------
Table 3-4-a. 1976 INTERNAL, COMBUSTION EMISSIONS AND CHARGE RATES
INTERNAL COMBUSTION ENGINES
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
RUN DATE'
PAGE 1
MAR 22*1977
MODIFIED
sec
201001000
201001010
201002000
201002010
i 201002020
i
h-k,
o
201003000
201003010
201999000
201999970
201999980
202001000
202001010
202002000
202002010
202002020
202003000
202003010
202004000
202004010
202999000
202999970
TACRP
ISCC UNITS)
1125600.
1125600.
329210.
112390.
216830.
76709.
76709.
1206&CU
68713.
68713.
944040.
65095.
878940.
3702.
3702.
28086.
28086.
25647.
25647.
EMISSIONS
NOX
.124
.124
.094
.019
.074
" .011
.011
.. .017
.004
.004
, .338
.010
.327
.000
.000
.005
.005
.004
.004
(MILLIONS
HC
.002
.002
.001
.001
0.000
.001
.001
.087
.012
.075
.009
.000
.086
.003
.083
.000
.000
.000
.000
.185
.185
OF TONS /
CO
.010
.010
.000
.000
0.000
.005
.005
.002
0.000
.002
.002
.002
.043
.002
.040
.003
.003
.002
.002
.001
.001
YEAR)
PART
.008
.008
.000
.000
0.000
.002
.002
.001
0.000
.001
.001
.001
.004
.000
.004
.000
.000
.000
.000
.000
-------
Table 3-4-b. 1976 INTERNAL COMBUSTION UNCERTAINTIES
INTER
TACR AND EMISSION UNCERTAINTIES
NAL COMBUSTION ENGINES
PROJECTED TO 1976
RUN DATE*
PAGE 1
MAR 22*1977
MODIFIED
sec
201001000
201001010
201002000
201002010
201002020
201003000
201003010
201999000
201999970
201999980
202001000
202001010
202002000
TACRP
(SCC UNITS)
* 3339400.
1125600.
* 3339400.
1125600.
+ 417950.
115800.
+ 417020.
112390.
+ 27906v
27906.
* 15352.
15352.
+ 15352.
15352,
* SP.4J'
- 2041.
* 22360.
22360.
* 27605.
27605.
i imt:
+ 623450.
-r 192420.
EMUS
NOX
* .372
- .124
- :!B
+ .072
- .022
+ .072
- .019
+ .010
- .010
* .OC3
- .002
* .003
- .002
* ,OC3
- .003
- .001
+ .002
- .002
i :88!
* .116
- .063
IONS
*
*
*
1
*
*
*
*
*
*
*
(MILLIONS
HC
.005
.002
.005
.002
.002
.001
.002
.001
0.000
0.000
.000
.000
:888
.014
.014
*014
.014
.000
.000
•8QQ
.000
.031
.017
Of TONS /
CO
* .029
- .010
i :m
* .003
- .000
* .003
- .000
+ 0.000
- 0.000
+ .002
- .001
* :88i
+ .900
- .000
* Q.OOO
- 0,000
•»• .000
- .000
* .001
- .001
i :881
* .024
- .009
YEAR
1
*•
1
*
*
*
1
*
!
1
*
>
PART
.024
.008
loos
.001
.000
.001
.000
0.000
0.000
.001
.001
• 001
.001
.001
.001
8*93°
• 000
.001
.001
.000
.000
• pp. p.
.000
.005
.004
-------
Table 3-4-b. 1976 INTERNAL COMBUSTION UNCERTAINTIES (Continued)
INTER
TACR AND EMISSION UNCERTAINTIES
NAL COMBUSTION ENGINES
PROJECTED TO 1976 RUN
DATE
PAGE 2
NAR 22,1977
MODIFIED
sec
202002010
202002020
I
| 202003000
202003010
I
I 202004000
£ 202004010
ro
202999000
202999970
TACRP
-------
Table 3-5-a. 1981 INTERNAL COMBUSTION EMISSIONS AND CHARGE RATES
LO
ANNUAL CHARGE
INTERNAL
RATES AND EMISSIONS
COMBUSTION ENGINES
PROJECTED TO 1981
RUN DATE'
PAGE 1
MAR 22,1977
MODIFIED
sec
201001000
201001010
201002000
201002010
201002020
201003000
201003010
201999000
201999970
201999980
202001000
202001010
202002000
202002010
202002020
202003000
202003010
202004000
202004010
202999000
202999970
TACRP
CSCC UNITS!
1313100.
1313100.
280980.
95131.
185850.
84459.
84459.
8255.
145600.
82513.
82513.
794400.
43960.
750440.
4859.
4859.
37511.
37511.
34742.
34742.
EMISSIONS
NOX
.145
.145
.080
.016
.064
.012
.012
.020
.012
.007
.005
.005
.286
.007
.280
.001
.001
• OC7
.007
.005
.005
(MILLIONS
HC
.002
.002
.000
.000
0.000
.001
.001
.104
.013
.090
.000
.000
.073
.002
.071
.001
.001
.001
.001
.250
.250
OF TONS
.012
.012
.000
.000
0.000
.005
.005
.002
0.000
.002
.002
.002
.036
.002
.034
.004
.004
.003
.003
.001
.001
/ YEAR)
PART
.009
.009
.000
.000
0.000
.002
.002
.002
0.000
.002
.001
.001
.003
.000
.003
.000
.000
.000
.000
.000
.000
-------
Table 3-5-b. 1981 INTERNAL COMBUSTION UNCERTAINTIES
TACR AND EMISSION
INTER
UNCERTAINTIES
I
(-*
£»
201001000
201001010
201002000
201002010
201002020
201003000
201003010
201999000
201999970
201999980
202001000
202001010
202002000
*
4-
*
•f
3518700*
1313100.
3518700.
1313100.
420260.
108180.
417090.
95131.
51514.
51514.
19658.
19658.
19658.
19658.
lifi:
46097.
46097.
674550.
299230.
IAI COMBUSTION ENGINES
PROJECTED TO 1981
PAGE 1
RUN DATE- MAR 22,1977
tnv EMISSIONS tMIUIONS OF TONS / *EAR)
NOX HC CO PART
!
*
:
i
i
*
4*
*
1
1
*
:
.392
.145
.392
.145
.074
.024
.072
.016
.018
.018
.003
.003
,003
.003
:88I
:88i
.002
.002
:881
•Ml
.146
.110
* .005
- .002
+ .005
- .002
+ .002
- .000
+• .002
- .000
» 0.000
- 0.000
+ .000
- .000
+ .000
- .000
* .029
- .029
* t.0.29
- .029
* . 000
i :888
*• .038
- .028
* .031
- .012
«• .031
- .012
* .003
- .000
+ .003
- .000
* 0.000
- 0.000
+ .002
- .001
• .002
- .001
+ .001
- .001
i 8:888
* .001
- .001
- :88i
* *QQI-
- .001
» .027
- .014
i- .026
- .009
* .026
- .009
• .001
- .000
* .001
- ,000
* 0.000
- 0.000
4- .001
- .001
* .001
- .001
* .002
- .002
i 8:888
* .002
- .002
* 'po1
* «PJtt
- .001
+ .005
- .003
-------
Table 3-5-b. 1981 INTERNAL COMBUSTION UNCERTAINTIES (Continued)
INTERNAL COMBUSTION ENGINES
PAGE 2
TACR AND E
MODJFI6D
202002010
202002020
202003000
202003010
202004000
202004010
202999000
202999970
MISSION
(SC
•f
•f
+
*
*
1
•f
UNCERTAINTIES
:P58?TS>
606150,
43960.
2959901
295990.
2540.
2540.
Htfc
stui:
26568.
26568.
mil:
mu:
PROJECTED
NOX
* .096
- IllO
* .oco
- .000
«• .000
- .000
i :88i
* .005
- .005
i :88f
- :ool
TO 1981
>SIQNS (NILLI
HC
* .025
- !023
* .000
- .000
+ .000
- .000
t :888
* .000
- .000
- :lll
+ .275
- .120
RUN
ONS OF
•f
*
1
+
i
i
i
DATE»
J8NS
.023
!oi4
.003
.002
.003
.002
-.88?
.002
.002
,001
.001
.001
MAR 22,1977
' ""'PART
* .004
; :88i
- .003
+ .000
- .000
+ .000
- .000
i :888
+ .000
- .000
i :888
+ .000
- .000
-------
For electrical generation, diesel engines reprt -ent on the
order of 1. 2 percent of the 1970 total electrical generating capacity in the
United States and only about 0.3 percent of the total power generated, for an
average utilization of about 12 percent. These engines are used for elec-
trical peaking power and also standby installation. The projected utilization
factor for 1980 drops to eight percent.
•;
Diesel engines represent about four percent of the installed
horsepower in pipelines and about five percent of the power generated. For.
oil and gas exploration, about 75 percent of the power used is generated by
diesel engines. For municipal water and sewage pumping about 50 percent
is diesel-powered, while agricultural water pumping is done almost exclu-
sively by diesel engines.
3.3.2 Gas Turbines
The main applications for stationary gas turbines include
electric power generation for utilities and for industrial and pipeline use.
Gas turbines have low initial costs, short delivery times, small space re-
quirements, flexible fuel needs, and high thermal efficiency. For these
reasons, turbines are being installed in electrical plants to replace steam
plants or to add capacity. , ;
Gas turbine engines vary greatly in size and configuration.
Turbines have single- or two-shaft designs. Both types can be operated in
simple cycles, regenerative cycles, or combined cycles. The simple-cycle
engines operate at 25 to 30 percent efficiency. Regenerative cycles utilize a
heat exchanger which uses turbine exhaust gases to heat the air as it passes
from the compressor into the combustor. Efficiency of these engines runs
about 34 to 38 percent. In the combined cycle, turbine exhaust gas is used
to generate steam which drives a second generator or other device. Effi-
ciencies of 40 to 42 percent are realized with these units.
3. 3. 3 Spark Ignition Engines
The spark ignition internal combustion engine is the most
widely used powerplant in the world today. These engines range from small
3-16
-------
single-cylinder units producing as little as a fraction of a horsepower to
large multicylinder units with power ratings of several thousand horsepower.
The large units are predominantly used in stationary power applications.
Medium-sized gasoline engines (50 to 200 hp) are used for
commercial and construction site compressors, pumps, blowers, and elec-
tric power generators. Medium-large spark ignition engines (200 to 1000 hp)
are generally operated on gaseous fuels to power gas compressors or standby
power generators. Large spark ignition engines (greater than 1000 hp) always
operate on gaseous fuels and are used for gas-well recompression, gas plant
compressors, refinery process compressors, water and sewage pumping,
and continuous electrical power generation.
3.3.4 Charge Rate
The NEDS was used as the primary source of data. Annual
charge rates (fuel consumption), as of the year of record, formed the start-
ing point for the charge rate projections.
The rate of change of charge rate for electric utility turbines
is based on the fuel demand data shown in Figure 3-1. The total rises every
year for all fuels except natural gas, reflecting the increased dependence on
turbine power. Lacking fuel consumption projections on gas turbines for
industrial use, the assumption was made that charge rate trends for these
turbines are equal to those for electrical power demand. For turbines us.ed
in the handling of petroleum products in such services as pumping and pres-
surization, it is also reasonable to assume that the same trends exist as for
the electric utility consumers.
For reciprocating engines, it was necessary to use less direct
methods of estimating charge rate changes. Table 3-6 shows data on the
number of 1C engines versus end use for gasoline and diesel fuels. Only
those listed in the source (Ref. 3-4) for construction, generator sets, or
general industrial use were considered in this part of the study. Of the
engines produced (Table 3-6), many were probably for replacement of
3-17
-------
1,320 TOTAL FUEL DEMAND
20-
50
480
••••— M
150
mmf****nm
260
TH
BA
^
OUSA
RREL
570
•^••••i
^
^•••••••M
7^-
280
200
NDS
SPEI
i
— •"
1?
OF
*DA\
760
70
150
^^^^^^••i
^ —
300
190
f
d
— —
_ -*
960
120
280
JL
320
180
— — • -
— "—
180
560
Jl
350
170
RESIDUAL
CRUDE
JET /KEROSENE
DISTILLATE
NATURAL GAS
(1000 barrel equivalent)
(1972) 1973 1975 1977 1979
CALENDAR YEAR
Figure 3-1. Electric utility gas turbine fuel demand
3-18
-------
Table 3-6. INTERNAL COMBUSTION ENGINE DISTRIBUTION:
NUMBER VERSUS END USE
00
vO
Engine Type
and End Usea
Number of 1C Engines Distributed
6
} g? f
1974
Gasoline
Construction 1,172,836 1,306,153 1,192,112 1,239,276 1,424,790 1,225,742 1,174,173 975,637 1,399,800 1,272,551
and General
Industrial Use
Generator
Sets
67,769 76,678 67,930 67,798 90,760 86,264 104,1.42 146,270 165,183 176,014
Total Gasoline 1,240,605 1,382,831 1,260,042 1,307,074 1,515,550 1,312,006 1,278,320 1,121,907 1,564,983 1,448,565
Diesel
Construction
and General
Industrial Use
Generator
Sets
Total Diesel
130,185 140,021 134,665 139,577 156,329 142,266 130,216 150,823 175,071 200,054
13,209 12,746 5,564 6,070 8,535 10,201 8,400 9,661 13,327 15,212
143,394 152,767 140,299 145,647 164,864 152,467 138,616 160,484 188,398 215,266
Total 1C
Engines
1,383,999 1,535,598 1,400,271 1,452,721 1,680,414 1,464,473 1,416,936 1,282,991 1,753,381 1,663,831
Ref. 3-4.
Represents total number of engines shipped or produced and incorporated into products at the same establishment during the time
period 1965 through 1974.
-------
worn-out engines or were exported, with perhaps only 10 p rcent of
production going into new installations. Hence, the assumption of a change
of charge rate based on 10 percent of the annual production seems conserva-
tive, but the uncertainty of this slope is rather large. Comparison of several
sources of predicted consumption for electrical generation shows variations
in slopes of from 3 to 22 percent per year. Thus, a 10 percent slope with
10 percent uncertainty in the slope was assumed.
3.3.5 Emission Factors
The emission factors were derived from the NEDS data by
dividing the emissions by the charge rate. Other sources of emission fac-
tors (Refs. 3-1 through 3-3) were used to determine the uncertainty of the
NEDS data. It was assumed that emission factors would not change with the
passage of time. The only factor that would change that assumption would
be the imposition of clean air standards on all of the users of this equipment.
This factor was ignored in the data input; thus, the data represent emissions
with no controls imposed.
3.3.6 Results
Table 3-3-a shows the' 1980 projections of annual charge rates
and emissions for point sources. The data show that about one-half million
tons per year of NOx and HC are produced by stationary 1C engines. Of this
amount, about 50 percent of the NO and 20 percent of the HC are from elec-
X*
trical generating plants, with the remainder from industrial sources. In the
electrical generating category, the worst offender is the distillate-fueled gas
turbine. With a charge rate of over '1. 25 billion gal/year, it contributes
about 140, 000 tons/year of NOx> In the industrial use classification, natural
gas reciprocating engines contribute about 300,000 tons/year of NO from
about 780 billion cu ft/year of gas. The uncertainty in 1980 charge rates
and emissions are shown in Table 3-3-b.
3-20
-------
3.4 TOTAL EMISSIONS FROM SELECTED STATIONARY 1C
ENGINES (POINT AND AREA SOURCES)
3. 4. 1 . Introduction
As reported in Section 3. 1, four stationary 1C engine-fuel
combinations were identified whose total (area plus point source) emissions
far exceed the estimated point source emissions reported in Section 3.3.
The four offenders are distillate-fueled and crude-oil-fueled turbines, and
gasoline-fueled and diesel-fueled reciprocating engines. Identification of
the engine types responsible for these large area source emissions was pos-
sible through analysis of the data extracted from Refs. 3-1, 3-4, and 3-5.
This section reports the rationale and results of estimating the total emis-
sions for those four types of engines.
3.4.2 Summary
Four engine-fuel combinations were found to contribute poten-
tially significant amounts of area source pollution: distillate-fueled and
crude-oil-fueled turbines and gasoline-based and diesel-fueled reciprocating
engines. Table 3-7 shows the total emissions for these engines in 19?0.
Table 3-8 gives the 1980 projection of pollutants from these four sources in
excess of the point sources data reported in Section 3. 3.
3. 4. 3 Discussion
3.4.3.1 Turbines
In 1971, the installed horsepower for gas turbines was about
38 million. About 29 million of that was for electrical power generation, and
the remainder was for pipelines and natural gas processing. For power gen-
eration, gas turbines provide the repowering when old and less efficient
plants are retired and also fill the need for increased power. In 1970,
approximately 5 percent of the power generated was by gas turbines; by 1980,
it is estimated that as much as 12 percent of the power capacity will be from
gas turbines. Projected electrical generation use is about 120--million hp in
3-21
-------
Table 3-7. 1980 PROJECTION OF TOTAL INTEF iAL
COMBUSTION ENGINE EMISSIONS*1
Emissions, million
Source Category
Distillate -Fueled Turbines
Crude -Oil -Fueled
Turbines
Gasoline -Fueled
Reciprocating Engines
Diesel-Fueled
Reciprocating Engines
Total
tons/yr
NOX HC
0.459 0.011
0.884 0.022
1.345 0.924
0.432 0.032
3.120 0.989
CO
0.060
0. 116
13,273
0. 142
13.591
Charge Rate,
1000 gal/yr
6.70 X 106
12.90 X 106
12.75 X 106
2.40 X 106
34. 75 X 106
Point source and area source emissions.
3-22
-------
Table 3-8. 1980 PROJECTION OF AREA SOURCE INTERNAL
COMBUSTION ENGINE EMISSIONS
Source Category
Emissions, million
tons/yr
NO,
HC
CO
Charge Rate,
1000 gal/yr
Distillate-Fueled Turbines
Crude -Oil-Fueled
Turbines
Gasoline-Fueled
Reciprocating Engines
Diesel-Fueled
Reciprocating Engines
0.313 0.009 0.047 5.34X10
0.884 0.022 0.116 12.90X10*
1.344 0.923 13.269 12.74X10*
0.414 0.031 0.134 2.28X10*
Total
2.955 0.985 13.566 33.26X10
3-23
-------
1980. Similar growth rates for other uses can be expected By 1980,
therefore, total gas turbine installed horsepower will be on the order of
150 million.
Figure 3-1 shows distillate consumption for gas turbines for
electrical generation growing to 350,000 bbl (14. 7-million gal/day in 1979).
Projecting this to 1980, fuel consumption can be expected to be 5.6-billion
gal/year for electrical generation alone. Adding consumption for other
uses increases this number by 20 percent to 6. 7-billion gal/year. The
1979 crude oil demand from Figure 3-1 is 560,000 bbl (23. 52-million gal/
day). Projecting the growth rate to 1980 and adding 20 percent for uses
other than electrical generation, the estimated consumption of crude oil in
gas turbines will be 12.9-billion gal/year in 1980.
Emission factors used to estimate total emissions are the
average of emission factors derived from the NEDS data and from Refs. 3-1
through 3-3. Crude oil emission factors were assumed to be the same as
the distillate emission factors, in the absence of any other information.
3.4.3.2 Diesel Engines
In Ref. 3-1, the total estimated installed horsepower of sta-
tionary diesel engines was about 16-million bhp (brake horsepower) in 1971.
Of this total, 5. 2-million bhp were used for electrical generation, and the
remainder was for industrial uses.
Table 3-6 indicates that about 215,000 diesel engines for in-
dustrial construction and generator sets were shipped in 1974. Total horse-
power was about 42 million for engines of greater than 50 hp. To estimate
fuel consumption, it was necessary to make the following assumptions:
a. Twenty percent of the engines shipped were new installa-
tions. The remainder were replacement engines or were
exported (nine percent were exported in 1974).
b. Engines will be operated on an average of 1170 hr/year.
NEDS data for 1970 indicate an average of 1888 hr/year*
for electrical generation and 5282 hr/year for industrial
use. The estimated 1980 operation is 8 percent for elec-
trical generation and 15 percent for industrial use.
3-24
-------
c. Specific fuel consumption is 0. 40 Ib/bhp-hr. (According to
Ref. 3-1, an average specific fuel consumption is 0.403 for
diesels of this class. ) Using data from Ref. 3-4 and the
1974 growth rate, it is estimated that diesel horsepower will
be about 36 million in 1980; fuel consumption will be 2.40-
billion gal/year (7. 0 Ib/gal). Emission factors were derived
as for gas turbines (Section 3. 3. 5).
3.4.3.3 Spark Ignition Engines
Spark ignition engines, both liquid- and gaseous-fueled, are
by two orders of magnitude the most common engines in the country today.
The 1971 total installed horsepower is estimated at 800-million (Ref. 3-1).
These engines are used for everything from small power tools to 1000-hp
and greater compressors, pumps, and electrical power installations.
Table 3-6 shows the number of 1C engines shipped in the years
1965 to 1974. Gasoline engines for construction, general industrial use, and
electrical generator sets number well over one million in each of those years.
Assuming that the engines in these categories are the larger horsepower
rated engines, this represents about 50-million hp/year. Of the 800-million
hp in 1971, it is estimated that about 50 percent was devoted to these
categories.
Using the same assumptions as were made for diesel engines,
namely, that 20 percent were new installations, but now assuming the aver-
age engine is used for 300 hr/year, the 1980 estimated installed horsepower
is 490 million and the annual fuel consumption (at 0. 52 Ib/bhp-hr) is 12.75-
billion-gal/year. Gasoline density of 6.0 Ib/gal was used in this computation.
Emission factors were derived by the same method used for
gas turbines (Section 3. 3. 5).
3.4.3.4 Results and Conclusions
From charge rates and emission factors, the 1980 total emis-
sions were estimated and are presented in Table 3-7. The data indicate that
about 3-million tons of NO , 1-million tons of HC, and 13. 6-million tons of
Jt
CO (mainly from gasoline engines) will be emitted from these engines.
Table 3-8 is the same data minus the point source data in Table 3-3-a. This
shows an estimate of the area source pollution.
3-25
-------
The uncertainty of the data is large. Although the
assumptions made are thought to be conservative, the real contribution of
these engines could be much higher.
The conclusions to be drawn from this study are that a large
number of stationary 1C engines are being produced in this country every
year and that information as to the application and utilization rates of these
engines is lacking. Therefore, a potentially large source of air pollution is
going undetected. Efforts to trace these engines to the user and to estimate
numbers of engines, use rate, and emissions are recommended.
3.5 REFERENCES
3-1. W. U. Roessler, et al., Assessment of the Applicability of
Automotive Emission Control Technology to Stationary
Engines, EPA-650/2-74-051, The Aerospace Corporation,
El Segundo, California (July 1974). -
3-2. C. R. McGowin, Stationary Internal Combustion Engines
in the United States, EPA-R2-73-210, Shell Development
Company, Houston, Texas (April 1973).
3-3. NEDS Source Classification Codes and Emission Factor
Listing (SCC Listing), Office of Air and Waste Material,
Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Washington, D. C.
(July 1974),
3-4. "Internal Combustion Engines: 1965 through 1974, "
Current Industrial Reports Series, MA-35L (65 through 74)-1,
U.S. Bureau of the Census, Washington, D, C. (1975).
3-5. V. DeBiasi, "Double Standard on Fuel Oils Would Favor
Steam over Gas Turbine Plants, " Gas Turbine World
(September 1973). *
3-26
-------
SECTION IV
CHEMICAL MANUFACTURING
4.1 INTRODUCTION
The emission sources discussed in this section are classified
under the general process category of chemical manufacturing and the more
specific categories of carbon black and ammonia manufacturing. The emis-
sions under consideration are oxides of nitrogen (NO ), hydrocarbons (HC),
Jt
carbon monoxide (CO), and particulate (PART) matter.
This section describes the development of the data base used
to calculate emissions from chemical manufacturing. The development of
emission equations is described in Section 1, Data Handling. Chemical
manufacturing processes studies are defined according to the National
Emissions Data System (NEDS) Source Classification Code (SCC) and, in
Table 4-1, by the NEDS Modified Source Classification Code (MSCC) devel-
oped by The Aerospace Corporation for this study.
4.2 SUMMARY
Chemical manufacturing production rates and emissions are
defined for 1975, 1980, 1976, and 1981. These data are respectively listed
in Tables 4-2-a, 4-3-a, 4-4-a, and 4-5-a. The respective uncertainties in
the production and emission data are listed in Tables 4-2-b, 4-3-b, 4-4-b,
and 4-5-b. Table 4-1 describes the process and production rate (charge
rate) unit for each MSCC for which emissions were determined.
(Continued on page 4-15)
4-1
-------
Table 4-1. DEFINITION OF CHEMICAL MANUFACTURIN PROCESSES
MSCC
301002010
301002020
301003010
301003020
301003030
301003990
301005010
301005020
301005030
301005040
301005050
301005991
301005992
301005993
.£
301005994
301005995
301999991
301999992
301999993
,, ,, . v- arge Rate
Source Category ° .
Purge gas in ammonia plant with methanator Tons/yr
Storage and loading in ammonia plant with
methanator
Regenerator exit in ammonia plant with CO
absorber
Purge gas in ammonia plant with CO absorber
Storage and loading in ammonia plant with CO
absorber
Miscellaneous processes in ammonia plant with
CO absorber
Channel process carbon black production
Thermal processes carbon black production
Gas-fired furnace process carbon black
production
Oil-fired furnace process carbon black
production
Gas- and oil-fired furnace process carbon
black production
SIC 2952 sector of miscellaneous carbon black
processes
SIC 3624 sector of miscellaneous carbon black
processes
SIC 3999 sector of miscellaneous1 Carbon black
processes
SIC 2899 sector 01 miscellaneous carbon black
processes
All other SICs of sectcj of miscellaneous
carbon black processes
SIC 2818 sector of miscellaneous chemical
manufacturing
SIC 3999 sector of miscellaneous chemical
manufacturing
All other SICs of sector of miscellaneous
chemical manufacturing
Standard industrial classification (SIC). The product description
corresponding to each SIC is given in Ref. 4-1.
4-2
-------
Table 4-2-a. 1975 CHEMIC At M^NU.F AC TURING EMISSIONS
AND CHARGE RATES " :
ANNUAL CHARGE
MODIFIED
sec
301002000
301002010
301002020
301003000
301003010
301003020
361003030
301003990
301005000
301005010
301005020
mmm
301005050
301005990
301005991
301005992
\
INDUSTRIAL
RATES AND EHISS
TACRP
-------
Table 4-2-b. 1975 CHEMICAL MANUFACTURING UNCERTAINTIES
INDUSTRIAL
TACR AND EMISSION UNCERTAINTI
MODIFIED
SCC
301002000 +
301002010 *
301002020 *
301003000 4-
301003010 4-
301003020 4-
301003030 *
301003990 +
301005000 +
301005010 +
301005020 4>
301005030 *
301005040 *
301005050 *
301005990 *
301005991 *
TACRP
CSCC UNITS)
m-
54487.
54487.
32080.
Km:
llffl:
16230.
'26540.
?26540.
17799.
17799.
2550.
isas:
201070.
200000.
200000.
PROCESS* CHEMICAL MANUFACTURING
ES PROJECTED TO 1975 RUN DATE-
EMISSIONS (MILLIONS OF TONS
NOX HC CO
PAGE 1
MAR 22*1977
/ YEAR)
Ittl
!?i?t: mmm
NEGLIGIBLE
NEGLIGIBLE
BLE
NEGLIG]
L
L
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
m
NEGL
NEGL
mi
N6GL
6 IBLE
GIBLE
GIBLE
lit
lit
mi
GIBL
NEGLIGIBLE
NEGLIGIBLE
i :8H
i 8:888
4>
.004
.004
* .004
- .004
* 0.000
- O.I
000
4- .00
- .000
* .003
- .003
«• .009
- .009
* .007
- .001
4- 0.000
- 0.000
.031
.031
+ 0.000
- 0.000
+ 0,000
: 8:888
. 0.000
* .340
- .340
«• .000
- .000
* .007
051
098
005
4 0.000
- 0.000
tt
PART
iLIGIBLi
;LIGIBLI
: 8:888 Rfitiiiitl
NEGLIGIBLE
NEGLIGIBLE
mmm
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mm
mm
NEGLIG
NEGLIG
'NEGLIG
iti
iti
BLE
N
ldL
mmm
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 4-2-b. 1975 CHEMICAL MANUFACTURING UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, CHEMICAL MANUFACTURING
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980 RUN DATE1
MODIFIED
sec
301005992
301005993
301005994
301005995
301999000
301999990
301999991
301999992
301999993
*
_
+
•
+
•
+
"*
+
—
*
—
4-
•"
•f
•
•*
—
TACRP
(SCC UNITS)
19999.
19999.
1000.
1000.
2000.
2000.
4999*
4999.
17464000.
17464000.
17464000.
17464000.
?8R88?,8«
7000000.
19999.
19999.
16000000.
16000000.
NOX
EMISSIONS (MILLIONS OF TONS
sS
ncGu
NEGL
it
M
NE
:G
3L
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
ftfttKifti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
HC
+ .000
; :8o°?
- .001
+ .000
- .000
* 0.'
- 0.)
* .065
- .065
+ .065
- .065
i :8ft
+ .011
- .011
* .050
- .050
CO
.'001
.001
.005
.005
.000
.000
* .129
- .129
+ .129
- .129
.126
.126
.026
.026
PAGE 2
MAR 22*1977
/ YEAR)
PART
f
N
NL
NEGLJ
mi
B
B
8
GIBL
6JBL,
GIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
RfftiEIttf
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 4-3-a.
1980 CHEMICAL MANUFACTURING EMISSIONS
AND CHARGE RATES
ANNUAL CHARGE
MODIFIED
SCC
301002000
301002010
301002020
301003000
301003010
301003020
301005000
301
005010
301005020
30}005030
301005040
301005991
301005992
301005993
301005994
301005995
INDUSTRIAL PR
RATES AND EMISSIO
TACRP
(SCC UNITS)
7083000.
6073000.
1010000.
2832500.
392000.
861500.
mm-.
6217000.
105960.
254010.
35795.
553100.
4003000.
425400.
24330.
44550.
49290.
CCESS, CHEMICAL
NS PROJECTED TO
EMISSIONS
NOX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
btiiiltf
NEGLIGIBLE
NEGLIGIBLE
SI8L
GIBL
NE
it
NEGL
NEGL
NEGL
NEGL
NEGL
GIBL
Ittt
ami
GIBLE
GIBLE
GIBLE
MANUFAC
1980
(MILLI
HC
.243
.243
0.000
.036
.001
.034
.328
.094
.000
.031
.116
TURING
RUN DATE*
ONS OF TONS
CO
.003
.003
0.000
,054
.054
0.000
8:888
2.369
.425
.004
.094
.621
0.000
.004
.005
.000
0.000
PAGE 1
MAR 22*1977
/ YEAR!
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
.009
.045
.000
0.000
NE
Ni
LIGIBLI
LIGIBLI
Rfgki&ittf
NEGLIGIBLE
NE6LIG]
NEGL
NEGL
NEGL
Rftt
BL
BL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
301999000
301999990
301999991
301999992
301999993
151180000.
151180000.
70000000.
181500.
81000000.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.518
.518
.276
.018
.224
.336 NEGLIGIBLE
.336 NEGLIGIBLE
.067 NEGLIGIBLE
.153 NEGLIGIBLE
.116 NEGLIGIBLE
-------
Table 4-3-b. 1980 CHEMICAL MANUFACTURING UNCERTAINTIES
INDUSTRIAL PRCCESS, CHEMICAL MANUFACTURING
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980 RUN DATE'
MODIFIED
SCC
301002000
301002010
301002020
301003000
301003010
301003020
301003030
301003990
301005000
301005010
301005020
301005030
301005040
301005050
301005990
301005991
TACRF
(SCC UNITS)
288*70.
288*70.
+
*
*
47130.
47180.
68686.
68686.
41862.
30270.
20485.
20485.
237320.
237320.
96857.
96857.
20185.
20185.
3070.
3070.
47482.
47482.
61941.
61941.
201070.
201070.
200000.
200000.
NOX
EMISSIONS (MILLIONS OF TONS
NEGLIGIBLE
NEGLIGIBLE
mmmi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEG
NEG
NEG
NEG
NEG
'
NEGL]
NEGL
NEGL
NEGL
G]
G
G
G
G
G
G:
G
BLE
8LE
BLE
BLE
BLE
BLE
BLE
BLE
GIBLE
HC
.032
.032
NEGLIGIBLE
NEGLIGIBLE
0.000
0.000
+ .009
- • i
*•
- .005
+ 0,<
- O.I
+ .000
- .000
* .087
- .087
«• .036
- .086
+ .000
- .000
* .003
- .003
+ .Oil
- .Oil
* .008
- .007
+ .001
- .001
* 0.000
- 0.000
CO
.001
.001
PAGE I
MAR 22*1977
/ YEAR)
PART
NEGLIGIBLE
NEGLIGIBLE
• 0.000
- 0.000
* .036
- .036
* .036
eel mstfgfitf
Rfstfgiitf
o
— 0.000
+ 0.000
— 0.000
* 0.000
- 0.000
+ .411
- .411
* .389
- .389
+ .000
- .000
4- .008
- .008
+ .062
- .061
* .116
- .116
+ .005
- .005
* 0.000
. 0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
EGL
EGL
_
EGL
NEGL
NEGL
NEGL
NEGL
BLE
BLE
BLE
BLE
BLE
BLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 4-3-b. 1980 CHEMICAL MANUFACTURING UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS* CHEMICAL MANUFACTURING PAGE 2
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1975 RUN DATE- MAR 22*1977
/ YEAR)
MODIFIED
sec
301005992 +
301005993 *
301005994 *
301005995 +
301999000 *
301999990 +
301999991 *
301999992 *
301999993 *
TACRP
(SCC UNITS)
EMISSIONS (MILLIONS OF TONS
NOX HC CO
PART
1000.
1000.
2000.
2000.
4999.
4999.
17464000.
17464000.
17464000.
17464000.
7000000.
700QQQO.
16000000.
KEt
€GL
-EGL
-------
Table 4-4-a. 1976 CHEMICAL MANUFACTURING EMISSIONS AND CHARGE RATES
ANNUAL CHARGE
MODIFIED
sec
301002000
301002010
301002020
301003000
301003010
mmm
301003990
301005000
301005010
mmm
301005040
301005050
301005990
301005991
301005992
301005993
301005994
301005995
301999000
301999990
301999991
301999992
301999993
INDUSTRIAL
RATES AND EHISS
TACRP
-------
Table 4-4-b. 1976 CHEMICAL MANUFACTURING UNCERTAINTIES
I
H-k-
o
INDUSTRIAL
TACR AND EMISSION UNCERTAINTI
MODIFIED
SCC
301002000
301002010 4-
301002020 *
301003000 4-
301003010 *
301003020 4
301003030 4-
301003990 4-
* K* S...S -
301005000 *
301005010 *
301005020 4~
301005030 *
301005040 *
301005050 *
301005990 *
301005991 t.
TACRP
(SCC UNITS)
HHW:
228630.
228630.
38029.
38029.
55125.
55125.
33589.
IIIII:
24244.
24244.
16421.
16421.
IBM:
lifi:
201070.
201070.
200000.
200000.
PROCESS* CHEMICAL MANUFACTURING
ES PROJECTED TO 1976'* RUN OAT£»
EMISSIONS (MILLIONS OF TONS
NOX HC CO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
tHitillltl
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
m\m
NEGLIGIBLE
NEGLIGIBLE
«EG
NEGL
GIBL
GIBLE
NEGLIGIBLE
NEGLIGIBLE
.029
.029
.029
- 0.000
4- .004
- .004
.000
.000
.004
.004
0.000
0 • 000
• 000
.000
i 'M
4- .000
- .000
4- .001
- .001
+ 0.000
- 0.000
4- .001
- .001
4- .001
- .001
4- 0.000
- 0.000
4- .032
- .032
* .032
4- olooo
- 0.000
4- 0.000
- 0.000
4- 0.000
- o.ooo
4- .000
- .000
*
i :J
4- .005
- .005
4- 0.000
- 0.000
PAGE 1
MAR 22*1977
/ YEAR)
PART
NEGLIl
NEGL!'
B
NEGLIGIBLE
ttfttitittf
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGlIGIBli
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mimt<
NEGL
NEGL
Slit
nut
NEGL]
NEGL]
GIBLE
GIBLE
Htti
GIBLE
GIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 4-4-b. 1976 CHEMICAL MANUFACTURING UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS* CHEMICAL MANUFACTURING
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE
PAGE 2
MAR 22*1977
MO
m
IED
301005992
301005993
30100599*
301005995
•f
4-
:scfA5RlTS)
1000*.
l9V-r.
*999.
NOX
EMISSIONS (MILLIONS OF TONS / YiAR)
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
4-
4-
4-
+ olooo
- 0.000
.001
• I
i :m
4- .005
- .000
4- 0.000
- 0.000
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
301999000 4-
301999990 4-
301999991 *
301999992 +
301999993 *
17*6*000.
17*6*000.
17*6*000.
17*6*000.
19999.
160
16000000.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
4- .065
- .065
* .065
- .065
i :ffl
4- .011
NEGLIGIBLE
.129 NEGLIGIBLE
.129 NEGLIGIBLE
.129 NEGLIGIBLE
.129 NEGLIGIBLE
N
• *
.126
- .050
NEGLIGIBLE
.026 NEGLIGIBLE
-------
Table 4-5-a. 1981 CHEMICAL MANUFACTURING EMISSIONS AND CHARGE RATES
INDUSTRIAL PROCESS* CHEMICAL MANUFACTURING
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981 RUN DATE'
301002000
301002010
301002020
301003000
301003010
301003020
301003030
301003990
301005000
301005010
301005020
301005030
301005040
301005050
301005990
301005991
301005992
301005993
301005994
301005995
7278400.
6240600.
1037800.
2910400.
916600.
«85200.
ft61200.
«,47400.
6249600.
NQX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NiG.^6
EHISSIaNS
NEGLIGIBLE
NEGLIGIBLE
.250
.250
0.000
.037
.001
.035
o.oog
.000
.330
101810.
261450.
36594.
565440.
737700.
4546600.
4003000.
425400.
24330.
44550.
49290.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGL
[GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
.090
.000
.031
.118
.081
.009
0.000
.004
.005
.000
0.000
TO
CO
.003
.003
0.000
.055
.055
0.000
.000
.300
0
0
2.394
.408
.004
.096
.635
1.197
.355
0.000
.009
.045
.000
0.000
PA5E 1
MAR 22,1977
ONS OF TONS /
NEGLIGIBLE
Ni
N!
ELIGIBLE
ELIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
N
N
GLIGIBL
GLIGIBL
GLIGIBL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLt
NEGLIGIBLE
301999000
301999990
301999991
301999992
301999993
151180000.
151180000.
70000000.
181500.
81000000.
NEGLIGIBLE
NEGLIGIBLE
NEGLI
GLI
IBL
NEGLIGIBL
NEGLIGIBL
.518
.518
224
.336
.336
116
NEGLlGinE
NEGLIGIBLE
NEGLIGIBL
-------
Table 4-5-b. 1981 CHEMICAL MANUFACTURING UNCERTAINTIES
co
INDUSTRIAL PRCCESS, CHEMICAL MANUFACTURING PAGE 1
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN DATE' MAR 22*1977
YEAR)
MOOIFXEO
sec
301002000
301002010 +
301002020 *
•»
301003000 +
301003010 +
301003020 *
301003030 «•
301003990 +
301005000 *
301005010 +
301005020 *
301005030 *
301005040 *
301005050 +
301005990 *
301005991 *
TACRP
-------
Table 4-5-b. 1981 CHEMICAL MANUFACTURING UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, CHEMICAL MANUFACTURING
PAGE 2
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE- MAR 22,1977
MODIFIED TACRP
SCC (SCC UNITS)
i 301005992 * 19999. N
19999. N
301005993 + 1000. K
301005994 * J888t B
^
i
h^
tfc.
2000. N
301005995 * 4999. N
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO
EG
' £
•G
t f*
m
k
4999. NEGL
G]
G
G
1
G
G
[G
B
B
B
3
E * .000 * .001 N
BL
3L
E - .000 - .001 N
• * .001 * .005 h
i ~ •QQ! — *QQ5 ^
* .000 + .000 f
• - .000 - .000 f
• * 0.000 * 0.000 N
PART
§11
• G
if
EG
EG
§;
\
G.
g
G
G
B
B
B
I
B
B
*
BLE - 0.000 * 0.000 NEGLIGIBLf
301999000 * 17464000. NEGLIGIBLE + .065 * .129 NEGLIGIBLE
17*64000. NEGLIGIBLE - .065 - .129 NEGLIGIBLf
301999990 * 17464000. NEGLIGIBLE * .065 + .129 NEGLIGIBLf
17464000, NEGLIGIBLE - .065 - .129 NEGLIGIBLf
301999991 + ZQQQQQQ* N
7000000. N
301999992 + 19999, N
19999. K
301999993 + 16000000. Nl
;|
*G
:G
EG
•
.
h
16000000. NEGL1
|
G
:
G
\\
8
3
B
3
i :m i :8t8 H
: + .011 + .126 N
: - .011 - .126 N
1^
It
> .050 + .026 NEG
- .050 - .026 NESL]
fi
GIB
618
GIB
GIBLE
-------
4.3 EMISSION ANALYSIS
The NEDS categorizes chemical manufacturing as a
member of the industrial process family of stationary sources of emissions
(Ref. 4-2). Industrial process emissions are compared to other point
sources in Table 4-6. Industrial process emissions for chemical manu-
facturing (SCC 3-01-xxx-xx) are compared in Table 4-7 with emissions
from the petroleum industry and other members of the industrial process
group. The PART and NO emissions from chemical manufacturing repre-
J\.
sent a small fraction, approximately three percent and four percent,
respectively, of total industrial process emissions. Since the PART
and NO emissions from chemical manufacturing processes represent
X ,.~
such small fractions of the totals from stationary sources, these pollutants
were largely neglected in this study.
The charge rate, emissions, and other pertinent data were
extracted from the NEDS point source data for each of the 143 SCC process
categories in the chemical manufacturing group. Table 4-8 ranks the cate-
gories with the highest charge rates. Tables 4-9 and 4-10, respectively,
list the most significant chemical manufacturing emitters by SCC category
and product for HC and CO emissions. In comparing the process categories
that produce the most emissions (Tables 4-9 and 4-10) to those having the
highest charge rates (Table 4-8), it is seen that the miscellaneous synthetic
rubber production (3-01-026-99) and the ammonium nitrate prilling tower
cooler (3-01-027-03) categories have high charge rates, but are not producers
of the largest amount of pollutants.
As a check against erroneous data, the effective emission
factors from the NEDS data (emissions and charge rate) were compared
with data published elsewhere. Although little data were available (data
were obtained only from Refs. 4-4 and 4-5), good agreement existed where
comparisons could be made. These comparisons plus a general knowledge
(Continued on page 4-21)
4-15
-------
Table 4-6. NATIONWIDE POINT SOURCE EMISSi 3NSJ
Source
Category
Emissions, ~tons/yr
PART
NO
HC
CO
Fuel
Combustion
Industrial
Processes
Other Point
Sources
5,414,427 8,922,937 239,403
150,847
645,880
8,427,012 3,728,717 7,033,590 21,132,667
29,725 165,847 5,455,023
Total
13,992,286 12,681,379 7,438,840 27,233,570
TRef. 4-3.
4-16
-------
Table 4-7. INDUSTRIAL PROCESS EMISSIONS*
Source
Category
Chemical
Manufacturing:
SCC 3-01-xxx-xx
Petroleum
Industry:
SCC 3-06-xxx-xx
Other Industrial
Processes^3
Total Industrial
Processes
PART
Total Industrial
232,886
(2.76%)
1,036,281
(12.30%)
, 7,157,845
(84.94%)
8,427,012
(100%)
N0x
HC
CO
Process Emissions, tons/yr
155,068
(4.16%)
3,264,812
(87.56%)
308,837
(8.28%)
3,728,717
(100%)
Total Nationwide Point Source
Chemical
Manufacturing
Petroleum
Industry
Other
Industrial
Processes
Total Industrial
Processes
1.7
7.4
51.2
60.2
1.2
25.7
2.4
29.4
2, 319, 544
(32.98%)
1,012, 131
(14.39%)
3,701, 915
(52.63%)
7,033, 590
(100%)
Emissions, %
31.2
13.6
48.8
94.6
5,992,262
(28.36%)
4, 524,476
(21.41%)
10,615,929
(50.23%)
21, 132,667
(100%)
22.0
16.6
39.0
77.6
Ref. 4-3.
Includes such processes as food, agriculture, primary metals, and secondary metals.
4-17
-------
Table 4-8. PRODUCERS OF GREATEST EMISS ONS
IN CHEMICAL MANUFACTURING
Rank
SCC
Numbe r
of Point
Sources
Source Category
Annual
Production
Rate,
tons/yra
4
5
3-01-999-99 1944
3-01-026-99 189
3-01-021-99 40
3-01-018-99 225
3-01-005-99 74
3-01-002-01 33
3-01-027-03 41
Miscellaneous
chemical
manufacturing
Miscellaneous
synthetic rubber
production
Miscellaneous
sodium carbonate
production
Miscellaneous
plastics production
Miscellaneous
carbon black
production
Ammonia pro-
duction with
methanator
Ammonium nitrate
with prilling
tower
151.29 x 106
13.63 x 10*
11.67 X 10*
5. 30 x 10
4.75 x 10
4.62 x 10
4.25 X 10
6.
Also known as annual charge rate (ACR).
These categories were not among the five categories yielding the greatest
emissions in the chemical manufacturing group.
4-18
-------
Table 4-9. PRODUCERS OF GREATEST HC EMISSIONS IN
CHEMICAL MANUFACTURING
Rank by Emissions
Rank SCC
i 3-01-999-99
2 3-01-005-01
3 3-01-002-01
4 3-01-005-04
5 3-01-018-99
Source Category
Miscellaneous chemical
manufacturing
Carbon black, channel
Ammonia with methanator
Carbon black, furnace oil
Miscellaneous plastics
production
Effective „ .
,_, . . Emission
Emission „ .
Factor, **ie.'
lb/tona tons/vr
6.86 519 X
1767. 227 x
69.2 160 x
425. 82 x
30.6 81 x
103
103
103
103
103
Rank by Product
Rank Product
1 Carbon black
2 Ammonia
3 Plastics
4 Other
Total
Production Rate
Tons /yr %
0.634 x 106 0.4
4.622 x 106 2.9
5.296 x 106 3.3
151.3 x 106 93.5
161.85 x 106 100
Emission Rate
Tons /yr %
309 X 103 29
160 x 103 15
81 x 103 8
519 X 103 49
1069 x 103 100
aEffective emission factor is the emission rate (Ib/yr) divided by the
production rate (tons/yr).
4-19
-------
Table 4-10. PRODUCERS OF GREATEST CO EMI SIONS IN
CHEMICAL MANUFACTURING
Rank
1
2
3
4
5
6
sec
3-01-005-01
3-01-005-05
3-01-005-04
3-01-999-99
3-01-005-03
3-01-005-99
Rank by Emissions
Source Category
Carbon black, channel
Carbon black, furnace
oil and gas
Carbon black, furnace oil
Miscellaneous chemical
Carbon black, furnace gas
Carbon black, miscella-
neous processes
Effective
Emission
Factor,
lb/tona
8031.
3246.
2137.
4.44
5000.
24.44
- "1
Emis sion
Rate,
tons /yr
1032 x-ip3
797 X iO3
-• '
403 x IO3
336 x IO3
60 x IO3
58 x IO3
Rank by Product
Rank
1
2
Product
Carbon black
Miscellaneous
chemical
manufacturing
Total
Production Rate
Tons/yr %
5.90X106 3.8
151.29X106 96.2
157. 19 X IO6 100
Emission
Tons /yr
2350 x IO3
336 x IO3
2686 x IO3
Rate
% ;
87
13
100
Effective emission factor is the emission rate (Ib/yr) divided by the
production rate (tons/yr).
4-20
-------
of the subject process resulted in the elimination of synthetic rubber
and ammonium nitrate manufacturing as major contributors of the four
emissions of interest.
4.3.1 Chemical Manufacturing Processes Studied
As mentioned, only unburned HC and CO emissions were
examined when forming the list of products and SCCs for which future charge
rate and emission forecasts were to be made. All SCC categories related
to an offending product were studied regardless of the magnitude of the
current emissions represented by any one SCC. Table 4-9 shows that cer-
tain carbon black, ammonia,'and miscellaneous chemical manufacturing
emissions represent 93 percent of the HC emitted by the five largest pro-
ducers in the chemical manufacturing category. Table 4-10 shows that
certain carbon black manufacturing processes produce the most CO emis-
sions in the chemical manufacturing group.
The chemical manufacturing products and SCC categories
for which future emissions and production rates were projected are as
follows:
SCC Product
3-01-0002-xx Ammonia made with methanator
3-01-003-xx Ammonia made with CO absorber
3-01-005-xx Carbon black
3_01-999-99 Miscellaneous chemical manufacturing
These four broad categories were divided into 19 MSCC
categories, and a current data base and 1980 projection were made for each.
More detailed definitions of these processes, as well as charge rates, are
listed in Table 4-1.
4.3.2 General Observations
In the course of the chemical manufacturing emissions study,
certain errors and discrepancies were noted in the NEDS point source
4-21
-------
emission data. Most of these observations were trivial, but two were
believed sufficiently significant to be reported here.
4.3.2.1 Summary of Point Source Comparison
The charge rate (production) and emissions as extracted from
the NEDS point source data (Ref. 4-6) are shown in Table 4-11 for the chemi-
cal manufacturing group. Although the years of record vary from 1969 to
1973 for the NEDS data, the preponderance of SCC data is for 1971. The
emissions from Refs. 4-3, 4-6, and 4-7 are summarized in the following
table and are presented graphically in Figure 4-1.
Emissions, million tons/yr
Data Source PART"" NOxHC CO
NEDS Tape:
1971 0.28 0.33 1.42 2.92
NEDS Nationwide Emis-
sion Summary _Repprt:
December 1973 0.22 0.15 2.37 6.01
January 1975 0.23 0.16 2.33 5.99
A discontinuity appears to exist between the 1971 and the
1974-75 data shown in Figure 4-1, indicating an inconsistency in ground
rules or methods of establishing the two sets of data. Two known factors
which may have contributed to the inconsistency are listed here. Their
exact effects are unknown, but are believed to be significant.
a. Emissions listed on the NEDS tape are based frequently
on preliminary (sometimes inaccurate) emission factors
(Ref. 4-4) or in some cases simply a guess. A com-
parison of emission factors published in Refs, 4-4 and
4-5 reflects the size of certain data errors. These
could cause either high or low emissions to be entered
on the NEDS tape.
4-22
-------
Table 4-11. SUMMARY OF CHEMICAL MANUFACTURING
AND EMISSIONS REPORTED IN NEDSa
sec
3-01-002-01
3-01-002-02
3-01-002-99
3-01-002
3-01-003-01
3-01-003-02
3-01-003-03
3-01-003-99
3-01-003
3-01-005-01
3-01-005-02
3-01-005-03
3-01-005-04
3-01-005-05
3-01-005-99
3-01-005
3-01-999-99
3-01-008
3-01-033-01
3-01-900-99
Other
3-01
Total
Annual ,
Charge Rate
4,621,676
766, 500
679,793
651,996
486, 877
330,000
257, 163
24,381
376,731
491,484
4,745,552
151,288,357
248,813
(100 tons/yr)
3,000
(gal/yr)
747
(million cu ft/yr)
182,696,930
aExtracted from Ref . 4-6.
Unless otherwise specified, charge
PART
118
118
(-%)
40
119
159
(0. 1%).
22, 146
3,614
901
7, 168
8, 079
41,908
(15.2%)
69,015
(25.0%)
343
(0.1%)
(-)
4,667
(1.7%)
159,870
(57.9%)
276,080
(100%)
rate units are
Emissions,
N0x
3,259
3,259
(1.0%)
65
65
(-%)
435
10
68
513
(0.2%)
44,054
(13.3%)
55,730
(16.8%)
(-)
146
(-)
228, 523
(68. 8%)
332,290
(100%)
~ tons /yr
HC
160,008
160,008
(11.3%)
772
2, 510
331
3,613
(0.3%)
227, 337
19,997
82, 204
54,013
8,967
392,518
(27.7%)
518, 506
(36.5%)
(-)
5,801
(0.4%)
(-)
338, 554
(23.9%)
1,419,000
(100%)
CO
2,777
2,777
(0. 1%)
10,995
10,995
(0.4%)
1,031,710
63, 469
402,659 .
797,087
57, 506
2,352,431
(80.7%)
335,500
(11.5%)
144
(-%)
(-)
18,850
(0.6%)
194, 503
(6.7%)
2,915,200
(100%)
in tons of product per year.
4-23
-------
0.28
0.26
0.24
0.22
0.20
0.34
0.30
E 0.26
I 0.22
U-
S 0.18
o
3 0.14
CO
1 2.2
—
1.8
OS
UJ
1.4
6.0
5.0
4.0
3.0
2.01
O - REF. 4-6 A•• REF.4-3 and 4-7
OXIDES OF NITROGEN
UNBURNED HYDROCARBONS
CARBON MONOXIDE
I
1971 1972 1973
CALENDAR YEAR
1974
1975
Figure 4-1. Emissions from chemical manufacturing
4-24
-------
b. Emissions listed in the summary reports (Refs. 4-3
and 4-7) are based on the product of charge rate and
known emission factors. Where the emission factors
are not known, zero emissions are entered. This
characteristic can only cause the summary report
emissions to be low.
4.3.2.2 Lack of Thermal Carbon Black Data
No data were reported under SCC 3-01-005-002 thermal
carbon black production. Reference 4-8 shows a steady growth from 47,000
tons in 1950 to 137,000 tons in 1965. Approximately 170,000 tons should
have been reported in 1970 according to the trend reported in Ref. 4-8.
Total carbon black production in 1970 as extracted from the NEDS falls on
the trend line established from Ref. 4-8 only if some production other than
that reported in the SCC categories 3-01-005-01, -03, -04, and -05 existed.
The difference is close to the forecast production of thermal black in the
Ref. 4-8 data. Either Jthermal carbon black was not reported or it was
.~~~ *" ~ ———• • V- ,.-
erroneously reported in SCC 3-01-005-99- Normally, this SCC would be used
to report carbon black handling or the manufacturing of some product where
carbon black is a principal ingredient. That portion of SCC 3-01-005-99
corresponding to SIC 2895 is close to the deficit. Of the nine SICs compris-
ing SCC 3-01-005-99, SIC 2895 is the only one identified as carbon black. .
4.3.3 Ammonia Production
4.3.3.1 Process Description
Two principal methods of ammonia (NH-) production exist:
a. Methanator process
b. CO absorber process
Both processes combine nitrogen (N) from the atmosphere with hydrogen
(H,) from some HC feed stock such as natural gas. The difference in the
Li
two techniques is centered on how the large amounts of CO are handled.
The CO results when H_ is extracted from the HC feed stock. While the
£
CO emissions in the main process of ammonia production are substantially
4-25
-------
less in the CO absorber technique, the CO efflux from the absorber when
it is being rejuvenated tends to be quite high. An extensive water scrubber
and incinerator system can considerably reduce the CO emissions during
absorber regeneration.
Unburned HC emissions (usually methane) from the purge
gas stream are of the same concentration whether the methanator or CO
absorber system is used. Scrubbers have a modest effect on HC emissions.
Although beyond the scope of this study, another noteworthy
emission is ammonia vapor. This emission can be reduced to almost any
level of insignificance through repeated water scrubber application.
4.3.3.2 Data Research and Analysis
*
Production rates of synthetic ammonia are recorded in
Refs. 4-6 and 4-9- The charge rate history is graphically presented in
Figure 4-2. Several straight lines were derived by least square fit tech-
niques from various combinations of the data points on Figure 4-2. The
straight line obtained when 1964 and 1965 data were excluded yielded the;
best correlation. Its equation was used when estimating future ammonia
production. The uncertainty in baseline production is simply the standard
error of estimate obtained with the straight line derivation. The uncertainty
of the production slope is the difference in slope for the adopted line and the
line derived using the six data points :.n Figure 4-2. This number is
approximately 21 percent of the baseline value.
The total production reflected in Figure 4-2 is considered to
be apportioned among the six SCC categories for all years in the same per-
centage as that listed by the NEDS for the 1970-72 era. Emission factor
data are found in three areas:
*
The term "production rate" as used here refers to the charge rate
associated with the particular operation; e.g., SCC 3-01-002-02 is related
to storage and loading, and the ammonia charge rate was actually produced
or created under 3-01-002-01 for methanator systems. The production
SCC for CO absorption systems is 3-01-003-02.
4-26
-------
10
o
I—
o
CD
O
Q_
O REF. 4-9
A REF. 4-6
LEAST SQUARE FIT TREND
(excluding 1964 and 1965 data)
0
1940
I
1945 1950
1955 1960
CALENDAR YEAR
1965 1970
1975
Figure 4-2. Synthetic ammonia production
4-27
-------
a. Reference 4-5
b. Reference 4-10
c. Quotient of emissions and charge rate from Ref. 4-6
data.
Where emission factor data exist in Ref. 4-10, they are considered to ,;
supersede Ref. 4-5 data. In the following discussion, that which prevails »,,
between Refs. 4-5 and 4-10 will be referred to as the "EPA emission
factor."
Where reasonable agreement (i.e., less than 15 percent,
difference) exists between the EPA emission factor and that derived from
the NEDS data, the average of the two was established as the baseline value.
Where the difference was great, a third source was enlisted as a referee;
where no third source was available, engineering judgment was exercised on
the basis of knowledge of the process in question. The uncertainty in the base-
line emission'factor is simply the difference between the baseline value and
the nearest source value which contributed to its derivation.
As mentioned, PART and NO emissions from chemical
x
manufacturing were so small (Table 4-7) in comparison to the total indus-
trial process that no time was spent in establishing their emission factors
(or related variables like slope or uncertainties); these emissions were
defined as negligible for all future years.
The literature survey described ammonia production
processes as having remained essentially unchanged since 1953, and no
substantial changes in controls or process are forecast for the immediate-
future. As a result, the slope and the slope uncertainties for ammonia
emission factors were set to zero.
4.3.3.3 Projections of Ammonia Activity
The total HC emission from ammonia production in 1980 is
estimated to be 279, 000 tons ± 32,000. The majority (243,000 tons),of these
emissions is from methanator-type production. The total estimated CO,
4-28
-------
emissions from ammonia industries in 1980 is 57,000 tons ±36,000. The
NO and PART emissions are expected to be negligible in 1980 (as is the
3C
case presently) compared to other point source industrial processes
emissions.
4.3.4 Carbon Black Industry
4.3.4.1 Processes and Uses
Carbon black is an oil-free ultrafine soot. Although it is
used in the paint and printing industry as a pigment, the prominent use is
in the rubber industry as a reinforcing agent. Tires, for example, roll
three to five times farther with carbon black than without.
Three principal techniques of carbon black production exist:
a. Impingement process
b. Thermal process
c. Furnace process
The furnace process, which accounts for most carbon black production, is
subdivided further according to fuel type: oil, natural gas, and oil-enriched
natural gas.
The impingement and thermal processes involve incomplete
combustion of HC fuel, whereas the thermal process involves thermal
decomposition (or cracking) of natural gas by exposing it to heated (2400°
to 2800°F) brick work. The impingement process (also called channel
process) involves natural gas-fueled flames impinging on surfaces of steel
(usually channel cross section) and depositing carbon black. The carbon
black is periodically scraped off the channels before pelletizing (to increase
the density for more economical shipment) for packaging and shipment.
Channel black is one of the finest (20 to 50 nm particle size) grades made.
Furnace black particle size is 25 to 160 nm. Although the thermal process
produces a much larger particle size (150 to 500 nm) and consequently
facilitates control of particulate-type HC emissions, many users of carbon
black, such as tire manufacturers, simply cannot use this product. The
4-29
-------
furnace process employs refractory-lined furnace combustion chambers
where the natural gas and oil is burned with insufficient air. The process
is continuous in nature, whereas the thermal and impingement processes
are cyclic. Furnace reactors have grown to be sophisticated efficient
plants compared to the channel black burner houses. The latter are
normally temporarily set up at the source of cheap natural gas and involve
few controls (except for air flow). Gas furnaces yield 12 to 16 Ib of carbon
black per 1000 cu ft of gas compared to a yield of 2 to 3 lb/1000 cu ft from
the channel black process. The theoretical yield is approximately 32 Ib/
1000 cu ft.
T
By its nature, carbon black production is a high emitter of
HC and CO. Although much of the following practice was implemented to
improve efficiency, pollution control benefits are inherent. Since most HC
emission are in the form of 4°ot par_ti_cu_l_atej_. the most common forms of
alleviation are cyclone separators; water scrubbers; bag filters; and, more
recently, electrostatic percipitators. Also some consideration has been
given to burning HC emissions. This would alleviate the flow of gaseous
emissions such as methane as well as the fine particulate soot. CO emis-
sions are left essentially uncontrolled in carbon black production.
4.3.4.2 Data Research and Analysis
4.3.4.2.1 Carbon Black Production - .
Production rates of carbon black are listed in Ref. 4-8 for
selected years from 1925 to 1965. Production rates for 1970 are recorded
in Ref. 4-6. With some difficulty, the data from Ref. 4-8 for the years
1950, 1955, I960, and 1965 were merged with the Ref. 4-6 data to establish
a modern-day trend. Two problems were encountered:
a. The Ref. 4-8 furnace data were not broken down by
type, i.e., oil, gas, or oil and gas.
b. No production rates were recorded in Ref. 4-6 for
thermal black.
4-30
-------
Problem a. was disposed of by assuming Ref. 4-8 furnace charge rates
were apportioned among the three processes on a percentage basis the same
as the Ref. 4-6 data.
The trend of total carbon black production for 1970 follows
the same curve as Ref. 4-8 data only if some carbon black production exists
other than that reported in Ref. 4-6 under the SCC categories 3-01-005-01,
-03, -04, and -05. As seen in Figure 4-3, the deficit closely matches the
charge rate reported under SIC 2895 of SCC 3-01-005-99. These observa-
tions (plus the fact that corporations listed in the NEDS point source data
were involved in other carbon black production) led to defining the 1970
production as the sunn of the charge rate for the four previously mentioned
SCC categories and the portion of SCC 3-01-005-99 allocated to SIC 2895.
Products corresponding to SIC classifications are defined in Ref. 4-1.
Figure 4-4 shows the production rate of carbon black for the five processes
under these ground rules.
Trend curves were established for the production rate of
each process by deriving the least square fit straight line using various
combinations of the 1955 to 1970 data. Figure 4-4 shows the curve which
used all five sets of data between 1950 and 1970. Even though the 1950-65
data resulted in a better fit (higher correlation coefficient), it was decided
to use (for future black production estimates) those curves derived from all
five points (1950 to 1970). The rationale was as follows:
a. The inclusion of the latest data (1970) adds credence
to future estimates.
b. Use of data from several sources offsets errors in
individual data where checking for validity is not
possible.
These trend curves were used to establish baseline production in the year
1975. The uncertainty in baseline production is equal to the standard error
of estimate obtained in deriving the straight line. The uncertainty of the
baseline slope (change in production rate per year) was defined as the dif-
ference in slope of straight lines using all five points and that excluding the
1970 data.
4-31
-------
O£
O
in
O
u_
O
«/>
z
o
o
QO
oc
-------
LLJ
O£
ff
00
Z
O
u_
o
oo
z
o
0.5
0.4
0.3
o'
0.4
0.3
0.2
0.1.
0
0.025
=! 0.020
S
z" 0.015
^ 0.010
§ 0
%. 0.20
O
<
CQ
Z
O
oo
Q±
<
O
0.15
0.10
o'
0.3
0.2
0.1
0
0 = REF. 4-3 A= REF4-6
- O
1950
FURNACE
(gas/oil)
FURNACE
(Oil)
FURNACE
(gas)
THERMAL
CHANNEL
1955 1960 1965
CALENDAR YEAR
1970
1975
Figure 4-4. Breakdown of carbon black production
4-33
-------
Emission factors for carbon black production are reported
in Refs. 4-5 and 4-10 and also can be calculated by dividing the pounds of
emissions by the tons of carbon black produced from Ref. 4-6. Data in :
Ref. 4-10 for a particular process were considered an update of Ref. 4-5
data. Reference 4-5 or 4-10 data (whichever prevail) is referred to as
the "EPA emission factor." The other source is called the "NEDS emis-
sion factor." Where reasonable agreement (i.e., < 15 percent difference)'
exists between the EPA and NEDS emission factors, the average of the
two values was established as baseline and its uncertainty was the difference
between the baseline value and the parent data..
Three cases were encountered where the EPA emission factor
differed substantially from the one based on the NEDS data:
a. Hydrocarbon emission factor for channel process
b. Carbon monoxide emission factor for channel
process
c. Carbon monoxide emission factor for oil-fed
furnace.
It was reasoned that the emission factors should be inversely proportional
to the percent theoretical product yield.
The theoretical maximum yield of carbon black is 32 lb/
1000 cu ft of natural gas. However, according to Ref. 4-11, approximately
40 percent of this HC is needed to raise the temperature sufficiently to
separate the carbon. Therefore, if none of the 32 lb of carbon black were
collected, approximately 19 lb would escape to the atmosphere, and the
remainder would be consumed to heat the gas. Stated mathematically, the
hypothesis is as follows:
(1.0 - 0.4 -
4-34
-------
where
EF = emission factor
T\ = decimal fraction of 32 Ib that the process yields of
carbon black
Since the emission factor for furnace process with gas was known (i.e.,
good agreement between the EPA emission factor and the one derived from
the NEDS), it was used as a basis to establish the three discrepant emis-
sion factors. This approach yielded values so close to the ones derived
from the NEDS data that the latter was selected for channel baseline
emission factors. .-.',
In the case of the oil-fired furnace process, the baseline
CO emission factor was defined as five percent higher than the one based
on NEDS data.
4.3.4.2.Z Miscellaneous Carbon Black Processes
Data were prepared to allow projections to be made in the
five MSCC categories of the miscellaneous carbon black industry
(MSCC 3-01-005-99). These MSCC categories were based on the SIC
classifications listed below and their corresponding products and comprised
the point sources under SCC 3-01-005-99 in Ref. 4-6 of the NEDS data:
MSCC SIC Product
3-01-005-99-1 2952 Asphalt, felts, and coatings
3-01-005-99-2 3624 Carbon and graphite products
3-01-005-99-3 3999 Manufacturing industries NECa
3-01-005-99-4 2899 Chemical preparation NEC
3-01-005-99-5 3334 Primary aluminum
3069 Fabricated rubber products
3991 Brooms and brushes
2999 Petroleum and coal products
lNot elsewhere classified (NEC).
4-35
-------
The baseline charge rate was set equal to the NEDS (1970)
value. Uncertainties were set at 5 percent of the base value for cate-
gories MSCC 3-01-005-99-1 through 3-01-005-99-4 and to 10 percent for
MSCC 3-01-005-99-5, which is a bigger uncertainty since it is comprised
of a broad collection of activities. Typical uncertainty of the carbon black
production is eight percent.
The baseline emission factors were set equal to the NEDS
emissions divided by the charge rate. The emission factor uncertainty was
set. to 10 percent of baseline value, which was typical of the primary carbon
black production SCC categories.
Since little is known about the production and processes in
this miscellaneous manufacturing group, no attempt was made to establish
a finite slope (trend) or slope uncertainty of any of the data leading to ":
projections of the 3-01-005-99 SCC categories. :
4.3.4.3 Projections of Carbon Black Activity
The estimated HC emissions in 1980 carbon black industries
are 328,000 tons ± 87,000. Although the channel process is by far the
dirtiest (high emission factor), its HC emissions are down both trend-wise
and process-wise. The 1980 channel black production is 94,000 tons com-
pared to 116,000 for the oil-fired furnace process. The estimated channel
black HC emissions in 1975 are 112,000 tons.
The estimated CO emissions from carbon black in 1980 are
2.37-million tons ± 411,000 tons. The oil-enriched natural gas-fired
furnace technique leads CO emissions with 1. 17-million tons in 1980.
4.3.5 Miscellaneous Chemical Manufacturing
4.3.5.1 Products
Some 78 separate products (SIC classifications) at 1944
point sources comprised the miscellaneous chemical manufacturing
(SCC 3-01-999-99) categories in the NEDS data tape. Entries made under
4-36
-------
SIC 2818 and 3999, respectively, constituted approximately 50 percent of
the HC and CO emissions. The 76 other SIC products combined represented
only 43 percent of the HC and 35 percent CO emissions. Emission projec-
tions were made for three subdivisions of miscellaneous chemical manu-
facturing: (1) SIC 2818, (2) SIC 3999, and (3) remainder (other than SIC 2818
and 3999). SIC 2818 was not defined in Ref. 4-1, but such a classification
would be a member of the industrial inorganic chemicals under SIC 281x.
SIC 3999 designates manufacturing industries NEC.
4.3.5.2 . Data Definition
The baseline charge rates and emission factors for each
category were set equal to the value calculated from the NEDS data
(Ref. 4-6). The uncertainties in charge rates and emission factors were
based on other chemical manufacturing (ammonia and carbon black).
Slopes and slope uncertainties were set to zero since little
is known about the collage of industrial activity.
4.3.5.3 Projections of Miscellaneous Chemical
Manuf a ctu ring
The estimated 1980 HC and CO emissions from miscellaneous
chemical manufacturing are 518,000 ± 65,000 tons and 336,000 ± 129,000
tons, respectively.
4.4 REFERENCES
4-1. Standard Industrial Classification Manual, Executive Branch
of The Federal, Government, Statistical Policy Division,
Washington, D.C. (1972).
4-2. Guide for Compiling a Comprehensive Emission Inventory,
Revised, APTD-1135, U.S. Environmental Protection
Agency, Research Triangle Park, North Carolina
(March 1973).
4_3. NEDS Nationwide Emissions Report as of January 10, 1975
(with New York and West Virginia Supplement), U.S. Environ-
mental Protection Agency, Research Triangle Park, North
Carolina (February 12, 1975).
4-37
-------
4-4. Compilation of Air Pollutant Emission Factors, AP-42, U.S.
Environmental Protection Agency, Research Triangle Park,
North Carolina (February 1972).
4-5. Compilation of Air Pollutant Emission Factors, 2nd ed. ,
AP-42, U.S. Environmental Protection Agency, Research
Triangle Park, North Carolina (April 1973).
4-6. "Industrial Processes, Chemical Manufacturing Category, "
NEDS Data, The Aerospace Corporation Tape Analysis, The
Aerospace Corporation, El Segundo, California (February 25;
1975).
4-7. NEDS Nationwide Emissions Report as of December 10, 1973,
U.S. Environmental Protection Agency, Research Triangle
Park, North Carolina (January 12, 1974).
4-8. I. Drogin, "Carbon Black," Journal of Air Pollution Control
Association, Informative Report No. 9, 8 (4) (April 1968).
4-9. R- Shreve, Chemical Process Industries, 3rd ed., McGraw
Hill Book Co., Inc., New York (1967).
4-10. NEDS Source Classification Codes and Emission Factor
Listing (SCC Listing), U.S. Environmental Protection
Agency, Research Triangle Park, North Carolina
(July 1974).
4-11. T. Cox, Jr. , "High Quality-High Yield Carbon Black, "
Chemical Engineering Journal (June 1950).
4-38
-------
SECTION V
PETROLEUM REFINERIES
5. 1 INTRODUCTION
This section develops data for the petroleum refining industry,
j
in terms of several important source classification codes (SCC), for emis-
sions of particulate (PART) matter, nitrogen oxides (NO ), unburned hydro -
J&*
carbons (HC), and carbon monoxide (CO).
The purpose is to provide a general overview of the petroleum
refining industry, assess the importance of specific major process sources
of atmospheric emissions, estimate current and projected levels, provide the
rationale used in making the projections, and present the data sources.
Table 5-1 describes the process and charge rate units for each SCC studied.
5.2 SUMMARY
Petroleum industry annual charge rates and emission rates
were established for 1975, 1980, 1976, and 1981 and are reported in
Tables 5-2-a, 5-3-a, 5-4-a, and 5-5-a, respectively. Uncertainty data are
listed in Tables 5-2-b, 5-3-b, 5-4-b, and 5-5-b for 1975, 1980, 1976, and
i
1981, respectively.
5.3 APPROACH
Developing and forecasting emission inventories requires
knowledge or judgment about a combination of factors. Technological gen-
eralities are discussed in Section 5. 7. Two important elements are total
annual charge rates and emission factors. Judgments have been made about
expected changes in these parameters resulting from technology advancements,
(Continued on page 5-15)
5-1 " " "-
-------
Table 5-1. DEFINITION OF PETROLEUM INDUSTRY t^OCESSES
MSCC
Source Category
Charge Rate Unit
306001010
306001020
306001030
306001040
306002010
306003010
306008010
306008020
306008030
306008040
306008050
306012010
Process heater (oil-fired, major
quantitie s)
Process heater (gas-fired, minor
quantities)
Process heater (oil-fired, minor
quantities)
Process heater (gas-fired, major
quantities)
Fluid catalytic cracking
Moving bed catalytic cracking
Miscellaneous leakage (pipe, valve,
flange)
Miscellaneous leakage (vessel
relief valves)
Miscellaneous leakage (pump seals)
Miscellaneous leakage (compressor
seals)
Miscellaneous leakage (other,
general)
Fluid coking
1000 bbl burned/yr
1000 cu ft burned/yr
1000 gal burned/yr
Million cu ft burned/yr
1000 bbl fresh feed/yr
1000 bbl refined/yr
1000 bbl refined/yr
1000 bbl refined/yr
1000 bbl refined/yr
i
1000 bbl refined/yr
i
1000 bbl fresh feed/yr
5-2
-------
Table 5-2-a. 1975 PETROLEUM INDUSTRY EMISSIONS AND CHARGE RATES
Ul
i
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1975 RUN DATE'
MODIFIED
see
306001000
306001010
306001020
306001030
306001040
306002000
306002010
306003000
306003010
306008000
306008010
306008020
306008030
306008040
306008090
306012000
306012010
TACRP
fSCC UNITS)
160600.
2200000000.
586700.
NEGLIGIBLE
1500000.
1500000.
108500.
108500.
26250000.
5250000.
5250000*
1118888:
5250000.
110000.
110000.
NOX
.507
i
• i
4
.*020
NEGLIGIBLE
.050
.050
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
EMISSIONS (MILLIONS OF TONS
CO
NE
N!
$
i
NEGLIGIBLE
NEGLIGIBLE
HC
.045
-.m
.001
NEGLIGIBLE
.170
.170
.005
.005*
.187
•
.0
l
6
NEGLIGIBLE
NEGLIGIBLE
.034
PAGE 1
HAR 22*1977
/ YEAR)
PART
.095
.001
NEGLIGIBLE
16.800
16,800
.210
.210
NEGLIGIBLE
NEGL
NEGL
HI
NI
ft!
it
It
BL
NEGLIGIBLE
NEGLIGIBLE
:88
.006
NEGLIGIBLE
.180
.180
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
m
NEG
LIG
6
LIG
BL
.027
.027
-------
Table 5-2-b. 1975 PETROLEUM INDUSTRY UNCERTAINTIES
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1975 RUN DATE =
MODIFIED
see
306001000
306001010
306001020
306001030
306001040
306002000
306002010
306003000
306003010
306008000
306008010
306008020
306008030
306008040
306008050
TACRP
(SCC UNITS)
* 8000.
8000.
4 110000000*
; lloo?8888:
^9000.
4
+
+
4
4
30000.
30000.
30000.
30000.
2169.
2169.
2169.
2169.
05000.
05000*
05000.
05000.
85000.
5000.
105000.
105000.
181888:
NOX
.025
.025
.016
.016
.018
:81?
.007
EMISSIONS (MILLIONS OF TONS
CO
.005
.005
.003
.003
.004
•.m
.000
.003
.003
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
flKtig
NEGLIG
NEGLIG
*EGL
BL
BL
BL
NEGLIGIBLE
4
+
HC
.006
.006
.006
.006
.002
looo
.009
.009
.009
.009
.000
.000
.000
.000
m
:W
:8t|
.005
.005
4
4
PAGE 1
MAR 22,1977
/ YEAR)
PART
4 .005
- .005
4 .005
- .005
4 .002
LE NFGLIGIBLF Nf
LE NEGLIGIBLE Ni
4 5.890
- 5.890
4 5.890
- 5.890
4 .011
- .011
.011
.011
I i :81* HI
H
18
EG
EG
m
G
N
N
H
N
NEGLIGIBLE
BiitBi
BLI
BLI
- .002
Histigiiti
4 .010
- .010
4 .010
- .010
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
HfgtiEiitf
Nil
tin8
•
NE<
NE(
N!
Ni
NEGLIGIBLE
-------
(Jl
I
(Jl
Table 5-2-b. 1975 PETROLEUM INDUSTRY UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, PETROLEUM PRODUCTS PAGE 2
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1975 RUN DATE* MAR 22,1977
MODIFIED TACRP EMISSIONS (MILLIONS OF TONS / YEAR)
SCC (SCC UNITS! NQX HC CO PART
306012000 + 2199. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE + .002
2199. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE - .002
306012010 + 2199. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE + .002
2199. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE - .002
-------
Table 5-3-a. 1980 PETROLEUM INDUSTRY EMISSIONS AND CHARGE RATES
Ul
i
o
ANNUAL CHARGE
MODIFIED
SCC
306001000
306001010
306001020
306001030
306001040
306002000
306002010
306003000
306003010
306008000
306008010
306001020
306008030
306008040
306008050
306012000
306012010
INDUSTRIAL
RATES AND EMISSIO
TACRP
(SCC UNITS)
112410.
3100000000.
586700.
NEGLIGIBLE
1690000.
1690000.
70000.
70000.
29850000.
6150000.
6150000.
PROCESS* PETROLEUM PRODUCTS
NS PROJECTED TO 1980 RUN DATE'
PAGE 1
MAR 22*1977
6150000.
120000.
120000.
NOX
.326
.082
EMISSIONS (MILLIONS OF TONS I YEAR)
CO
NEGLIGIBLE
.056
.056
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
HC
.055
.008
.047
.001
NEGLIGIBLE
.180
.180
.003
.003
.215
.087
,*030
NEGLIGIBLE
NEGLIGIBLE
.038
.010
.027
.001
NEGLIGIBLE
11.441
11.441
.130
.130
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
.082
.047
.031
.004
NEGLIGIBLE
.128
.128
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.029
.029
-------
Table 5-3-b. 1980 PETROLEUM INDUSTRY UNCERTAINTIES
ui
INDUSTRIAL
TACR AND EMISSION UNCERTAINTIES
306001000
306001010
306001020
306001030
306001040
306002000
306002010
306003000
306003010
306008000
306008010
306008020
306008030
306008040
306008050
4-
4-
mi-.
310160000.
310160000.
\
168980.
168980.
168980.
168980.
21002.
21002.
21002.
21002.
mm.
mm-.
615030.
615030.
mm:
615030.
615030.
615030.
615030.
PROCESS* PETROLEUM PRODUCTS
PROJECTED TO 1980 RUN DATE'
EMISSIONS (MILLIONS OF
NOX HC
.032
.032
+ .006
- .006
+ .006
- .006
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
KEtmitf
NEGLIGIBLE
it
!fl
Nl
NEGL
NEGL
NI-
NE
Gl
I
G
G
G
G:
BL1
III
BLE
BLE
4- .006
- .007
4-
4-
:i. _
,005
.005
* .030
- .030
i :88?
mmim mmm\
* .020
- .023
* .020
- .020
* .001
- .001
.001
.001
.012
.012
:8H
.005
.005
.011
.011
+ .006
- .006
* •P.Q2.
- .002
• .006
- .006
+ •!
+ 6.723
- 6.723
«• 6.723
- 6.723
* .040
- .040
+ .040
- .040
PAGE 1
MAR 22*1977
' *EARI,m
• .006
- .006
T •'
+ 1003
- .003
4-
NEGLIGIBLE
NEGLIGIBLI
slit
NEGL
NEGL
NEGL
NEGL]
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
+ .014
- .014
+ .014
- .014
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* «QH MEGLIGIBLE NEGLIGIBLI
- .041 NEGLIGIBLE NEGLIGlBLl
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
BLL
BLE
BLE
BLE
BLE
BLE
BLE
-------
(Jl
I
00
Table 5-3-b. 1980 PETROLEUM INDUSTRY UNCERTAINTIES (Continued)
i
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS PAGE 2
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1980 RUN DATE* MAR 22,1977
MODIFIED TACRP EMISSIONS {MILLIONS OF TONS / YEAR)
SCC
-------
Table 5-4-a. 1976 PETROLEUM INDUSTRY EMISSIONS AND CHARGE RATES
vD
ANNUAL CHARGE
MODIFIED
SCC
306001000
306001010
1818818
(0600104
306002000
306002010
306003000
306003010
306008000
306008030
306008040
306008050
306012000
306012010
INDUSTRIAL
RATES AND EMISSIO
TACRP
-------
Table 5-4-b. 1976 PETROLEUM INDUSTRY UNCERTAINTIES
i
^•*.
O
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE'
c. .._„ EMISSIONS (MILLIONS OF TONS
51 NOX HC
MAR
PAGE 1
22*1977
306001000
306001010
306001020
306001030
306001040
306002000
306002010
306003000
306003010
306008000
306008010
306008020
306008030
306008040
306008050
8154.
8154.
124350000.
*
•f
•f
30741.
44790.
44790,
4707.
4707.
4707.
4707.
mm:
mm:
160360.
603
60"
601
. 0 26
.026
.015
,015
.019
- .007
flfiUEtiti
* .003
- .003
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
lit
GL
NEGLIGIBLE
B
ft
N
K
Nl
mti
GIBLI
.006
.006
.005
.005
.003
!ooo
mmim
.010
.010
+ ,000
- .000
» .000
- .000
:8B
.011
:8U
•M
.005
.005
.005
.003
.003
.004
- .000
flittttiiti
* 6.047
- 6.047
+ 6.047
- 6.047
• .013
- .013
* .013
- .013
t :m mmi
NiltiMIti
NEGllGIBLE
mt
NEGL
NEGL
NEGL
g
«•
BLE
BL
BL
* .005
- .005
«• .005
- .005
* .002
- .002
•»• .010
- .010
+ .010
- .010
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
urn
KfSt
NEGL
NEGL
NEGL
G]
M
iti
BLE
BLE
BLE
-------
Table 5-4-b. 1976 PETROLEUM INDUSTRY UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS
TACR AND EHISSIOM UNCERTAINTIES PROJECTED TO 1976 RUN DATE-
EMISSIONS UUONS of
PAGE 2
MAR 22*1977
306012000
306012010
3225.
3225.
3225.
3225.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
+ .002
- .002
* .002
- .002
Ul
i
-------
Table 5-5-a. 1981 PETROLEUM INDUSTRY EMISSIONS AND CHARGE RATES
Ul
ANNUAL CHARGE
INDUSTRIAL
RATES AND ENISSIQ
PRQCESSt PETROLEUM PRODUCTS
NS PROJECTED TO 1981 RUN DATE'
PASE 1
MAR 22*1977
MODIFIED
sec
306001000
306001010
306001020
306001030
306001040
306002000
306002010
306003000
306003010
306008000
306008010
306008020
306008030
306008040
306008050
306012000
306012010
TACRP
«SCC UNITS!
102770.
3280000000.
586700.
NEGLIGIBLE
1728000.
1728030.
62300.
62300.
30570000.
6330000.
6330000.
6330000.
5250000.
6330000.
122000.
122000.
EMISSIONS {MILLIONS
NOX HC
.290
.060
.221
.008
NEGLIGIBLE
.058
.058
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.058
.007
.049
.001
NEGLIGIBLE
.182
.182
.003
.003
.221
.090
.034
.054
.013
.031
NEGLIGIBLE
NEGLIGIBLE
OF TONS /
CO
.039
.009
.028
.001
NEGLIGIBLE
10.168
10.168
.115
.115
NEGLIGIBLE
BKtiSiltf
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
YEAR)
PART
.079
.043
.033
.003
NEGLIGIBLi
.115
.115
NEGLIGIBLE
NEGLIGIBLi
NEGLIGIBLI
HfttKiit
NEGLIGIBL
NEGLIGIBL
NEGLIGIBLi
.030
.030
-------
Table 5-5-b. 1981 PETROLEUM INDUSTRY UNCERTAINTIES
un
i
INDUSTRIAL
TACR AND EMISSION UNCERTAINTIES
PROCESS* PETROLEUM PRODUCTS
PROJECTED TO 1981 RUN DATE'
MODIFIED
SCC
306001000
306001010
306001020
306001030
306001040
306002000
306002010
306003000
306003010
306008000
306008010
306008020
306008030
306008040
306008050
•f
*
TACRP
CSCC UNITS)
12404.
12404.
364970000;
364970000.
67723.
67723.
NEGLIGIBLE
NEGLIGIBLE
201800.
201800.
201800.
201800.
25161.
25161.
25161.
25161.
UU988:
mm:
734740.
734740.
734740.
734740.
««*«:
HH«:
NQX
EMISSIONS
(MILLIONS
HC
* .034
- .034
«• .010
- .010
+ .031
- .031
* .007
- .007
NEGLIGIBLE
NEGLIGIBLE
+ .007
- .007
* .007
- .007
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIG
NEGLIG
mm
mm
8LE
BLE
BLE
BLE
ittl
+ .007
- .007
+ .003
- .004
+ ',000
- ,000
NEGLIGIBLE
NEGLIGIBLE
* .023
- .023
+ .023
- .023
* .001
- .001
+ .001
- .001
* .013
- .013
* ,020
- .020
OF TONS
CO
+ .007
- .007
+ .002
- .002
PAGE 1
MAR 22,1977
/ YEAR)
PART
«• .007
- .007
«• .000
- .000
NEGLIGIBLE
NEGLIGIBLE
* 6.877
- 6.877
+ 6.377
- 6.877
«• .047
- .047
+ .047
- .047
RfStfSfltf
NEGLIGIBL
NEGLIGIBL
LIGIBL
LIGIBL
N
mmm
.001
- .001
NEGLIGIBLE
NEGLIGIBLE
+ .015
- .015
+ .015
- .015
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 5-5-b. 1981 PETROLEUM INDUSTRY UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS* PETROLEUM PRODUCTS PAGE 2
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN DATE* MAR 32,1977
MODIFIED TACRP EMISSIONS (MILLIONS OF TONS / YEAR)
SCC CSCC UNITS) NOX HC CO PART
306012000 + 1*323. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE + .004
14321. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE - .004
306012010 + 14323* NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE + .004
14323. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE - .004
Ul
-------
regulatory impacts, economic considerations, and other matters . Development
of emission factors for the more important SCCs was primarily based upon
data provided in Ref. 5-1. The major sources of petroleum refinery emissions
stem from combustion -generated emissions resulting from process heating
and catalyst regeneration, while HC discharges result mainly from sources
of leakage or evaporation.
In certain instances, revisions of CO factors were made for
consistency with other firing equipment using similar fuels or known data.
For example, the CO emission factor for oil-fired process heaters in SCC
3-06-001-01 is indicated as zero. The corresponding CO emission factor for
external combustion boilers (SCC 1 -02-004 -xx and 1-02-005-xx) indicates
4-lb CO/ 1000 gal burned, which is equivalent to 168 lb/1000 bbl. The factor
used in this instance was accordingly taken as 170 for equipment in this SCC.
In a similar way, it can be determined that CO variation in
fluid catalytic cracking introduces uncertainty in the emission factor for
SCC 3-06-002-01. The factor given for this effluent in Ref. 5-1 is 13, 700-lb
CO/SCC. Coke formation ranges between 4 and 10 percent of fresh feed
charge. The amount of CO produced varies with the stoichiometry within the
regenerator, but a range may be assessed in a simple way by assuming that
the CO,/CO ratio in the off gases is 1.5, which is typical (Ref. 5-2). On
£4
the basis of an 8 percent coke formation and a feed gravity of 300 Ib/bbl, we
have
5C + 4O2 = 2CO + 3CO2
8-lbcoke x 56 -IbCO x 3001b iOOObbl = 40Q_lb , t
100 -Ib fresh feed 60 -Ib coke bbl SCC
Slightly different assumptions can be made to show even more severe emission
factors, which merely makes the uncertainty range greater.
5-15
-------
5.4 GENERAL REFINERY STATISTICS
Statistical data from several sources served as the basis
for obtaining detailed information concerning crude charging rates, produc-
tion capacities, product yields, and past production trends . Most refiners
try to maximize gasoline and fuel production, although some operators
concentrate on other specialty products as well. Average yields and other
statistics of U.S. refineries are periodically published by the American
Petroleum Institute (API) and also in industry journals such as The Oil and
Gas Journal (Ref. 5-3). Percentage yields of various petroleum products for
1973 are represented in Table 5-6. As shown, gasoline represents the major
product of the industry; the yield of gasoline relative to crude input is nearly
one-half the total volume. This is a composite statistic; some refiners can
obtain gasoline yields in excess of 60 percent.
Petroleum refinery statistics dating back to 1956 are given in
Ref. 5-2. Few changes in refinery yields have occurred. Average gasoline
yields have increased from 43.4 to 45.6 percent. The annual growth rate in
crude runs to stills for the entire time period of Ref. 5-2 is 2.7 percent and
3.6 percent over the last 10 years. Gasoline production growth over this
same time period has been nearly 4 percent and approximately 3 percent
over Hie entire time period. Thus, refiners have been concentrating their
efforts on producing ever increasing amounts of gasoline from crude. The
most recent estimates for gasoline production in 1974 is about 6.5 X 10 bbl/
day or nearly 10 gal/year. Although kerosene production in Ref. 5-4
appears to have declined, it has been replaced by jet fuels. Total kerosenes
therefore, are increased. A considerable decline in residual fuel oil yield
from 14.7 percent in 1956 to 7.7 percent in 1973 is indicative of further
processing of these "heavy ends."
Recent data on a state-by-state basis show that in early 1974
there were 247 refineries operating in the United States, with a daily stream
crude capacity of 14.9 x 10 bbl/day, running at 96 percent capacity (Ref. 5-3).
For 1975, the daily runs were estimated at 15 X 10 bbl, which when annu-
Q
alized on 350 days results in 5.25 X 10 bbl. Although this appears to be an
5-16
-------
Table 5-6. 1973 DISTRIBUTION OF PETROLEUM PRODUCTS
Product Percent of Refinery Yield
Gasoline 45.61
Distillate Fuel Oil 22.46
Residual Fuel Oil 7 . 74
Jet Fuel (Kerosene) 5.41
Kerosene 1.73
Jet Fuel (Naphtha) 1.44
Lubricants 1.50
Other 14.11
5-17
-------
exceptional rise in the two-year interim following the last tabulated values of
Ref. 5-2, it seems in line with present market demand patterns and industry
construction.
A number of reference sources can be cited in forecasting
energy demands, sources of supply, or projected growth rate of U.S. con-
sumption (Refs. 5-5 through 5-11). Such issues as economics and industrial
activity, population growth, domestic government policies, and related inter-
national politics lead to considerable uncertainty in forecasts. In this study,
considering an overall oil requirement in the vicinity of 22 to 23 million
bbl/day by 1980, refinery runs have been estimated to be in the range of 17
to 18.5 million bbl/day. On an annual charge rate basis, the values are from
Q Q
6.0 X 10 to 6.3 X 10 bbl/year. When a SCC is measured in terms of 1000
bbl/year, these figures represent projected levels of 6.0 to 6.3 X 10 SCC/
year and compare favorably with the long-term and recent-term trends
discussed earlier.
5.5 PETROLEUM REFINERY PROCESSES EVALUATED
5.5.1 Process Heaters
Energy consumption requirements of typical refineries were
determined to establish the emissions from combustion equipment. Energy
used in refining, as in other industrial practices, is governed by fuel price.
Nelson (Ref. 5-12) has shown that, for an average refinery, net energy con-
sumption varies with refinery complexity, but for many years has generally
remained in the range of 10 to 12 percent of processed crude. Newer refin-
eries tend to have lower energy consumption because refiners have installed
more efficient systems, enabling better overall heat utilization. In this study,
the net energy consumption level was therefore assumed as 10 percent of
0. 63 x 10 Btu/bbl oil processed. About two thirds of this heat is obtained in
some plants by the burning of refinery process gases and about one third from
the firing of salable liquids or residual fuel (Ref. 5-13). A further breakdown
of process heater firing was obtained from a NEDS data tape printout which
showed that 92 percent of the oil-fired process heater charge rate is in large
heaters (SCC category 3-06-001-01) versus 8 percent in small heaters (SCC
3-06-001-03) (Ref. 5-14).
5-18
-------
In forecasting to 1980, it was assumed that refineries will
continue to increase in complexity (as they have for many years). There are
several reasons why this should occur. A large portion of the industry lacks
the capability to process high-sulfur crude oil (Ref. 5-15). Therefore, the
industry will develop the flexibility to handle such crudes and at the same time
will be upgrading production facilities to meet new environmental demands
for pollution control and to produce lead-free and low-lead gasoline products.
These factors will tend to be offset by certain energy conservation measures;
hence, it was assumed that the energy required to operate refineries in 1980
will still be 10 percent of the total product processed by these refineries.
The overall energy consumed by oil-fired heaters will tend to
decline as fuel-firing strategies will tend toward selection and use of process
gaseous fuels having a low sulfur content. This is dictated by recently pro-
mulgated regulations (Refs. 5-16 and 5-17) which limit atmospheric sulfuric
oxide (SO~) emissions from process heaters. It has been estimated that a
L*
reduction of up to 30 percent of current energy values in SCC 3-06-001-01 can
be realized. The implication of this is that future needs for process heat
from this SCC will consume only about 25 percent of refinery fuel require-
ments, with greater implementation of refinery-process gas-fired equipment.
At the same time, improved firing techniques will enable reductions in NO
J^
emission factors.
5.5.2 Fluid Catalytic Cracking
The fluid catalytic cracking capacity of an average refinery is
about 30 percent of crude capacity, with larger companies tending to have
higher fractions (approximately 34 percent) and smaller companies having
lower fractions (24 percent)(Ref. 5-15). The largest fluid catalytic cracking
plants operate in the range of 120, 000 bbl/day, and there are eight plants of
this size range (Ref. 5-3). The total annual charge rate of this SCC is
Q
presently 1.5 X 10 bbl/year. Over the past few years, the growth trend has
been a fairly consistent 2.4 percent annually, so that by 1980 the expected
Q
new additions will account for 1.69 X 10 bbl/year, if no perturbations occur.
According to Conn (Ref. 5-18), the attributes of fluid catalytic cracking are
that fluid crackers (1) may be constructed in very large sizes, (2) are rela-
tively free of mechanical problems, and (3) have proven flexible in operation.
5-19
-------
As mentioned, several important advances have taken place in fluid catalytic
cracking. These include improved catalysts and improved operating and
regeneration techniques (such as riser cracking and two-stage regeneration)
resulting in improved capacities and yields (Ref. 5-19), lower coke make,
and lower emissions (Ref. 5-20). The rising trend in fluid cracking capacity
is expected to continue.
However, the new standards of performance which became
effective in 1974 limit the emissions from fluid catalytic crackers (Ref. 5-16).
The promulgated standards apply to PART and CO emissions from new or
modified catalyst regenerators. Essentially, an operator is prohibited from
discharging (1) PART matter in excess of 1 kg/1000 kg (1 lb/1000 Ib) of.coke
burnoff in the catalyst regenerator and (2) gases which contain CO in excess
of 0.050 percent by volume (500 parts per million).
Background information contained in Refs. 5-21 and 5-22 shows
that compliance with the new standards may be achieved by use of more than
one type of control technique. Emissions of CO from fluid cracking regen-
erators are also discussed in Ref. 5-20.
Since the regulations apply to new plants and existing plants
which were modified in a way that increased their emissions, it became
necessary to assess the expected degi ee of modernization which can occur
between the present and 1980. In other words, to forecast the emissions one
must evaluate the expected rapidity of plant replacement and the fraction of
controlled emission production levels which would be in effect by 1980.
Information concerning refinery abandonments, replacements, enlargement,
and modernization is scarce. As reported by Nelson (Ref. 5-23), a refinery
that is to operate profitably must adhere to certain rules:
a. Grow in crude capacity so that the refiner retains his share
of the growing market
b. Be constantly repaired and maintained
c. Grow in downstream technology to meet product and
quality requirements
d. Grow technologically so that it remains competitive
5-20
-------
Thus, not only does crude and downstream capacity increase, but whole
process units (e.g., crude, cracking, and reforming) are replaced from time
to time so that the larger refinery is not simply an accumulation of small units,
It has also been shown that on average a refinery can be kept competitive
with respect to crude capacity and downstream facilities by doubling every
12 to 13 years, or at an annual rate of 5.7 percent. In addition, during recent
years , nonoperating refineries of major companies have been below 0. 4 per-
cent of existing capacity. The approach taken was to assume that these
criteria apply also to fluid catalytic cracking, and on this basis an analytical
assessment was made on 1980 charge rates.
5.5.3 Moving Bed Cracking
This form of catalytic cracking appears to be of diminishing
importance in terms of overall charge rates. Recent trends according to
Ref. 5-15 show that daily capacity receded from 0.5 X 10 bbi/day in 1972 to
0.3 X 10 bbl/day in 1975. At this rate of decline (roughly 16 percent annu-
ally), the daily charge rate would be about 0. 13 X 10 bbl/day, but it is not
known how the new regulations will affect refiners plans. The approach used
was to assume the decline would continue at approximately half this rate so
that by 1980 the daily throughput would be 0.2 x 10 bbl/day. The annual
charge rate becomes 0-07 X 10 bbl/year or 0.07 X 10 SCC/year. The
uncertainty in charge rate is thus relatively high. The emission factors used
were those in Ref. 5-1.
5,5.4 Coking and Miscellaneous Categories
These categories include particulate dispersions resulting
from coke making and various other HC losses. No special approach was
necessary for SCCs based upon total annual charge rate. For coking, annual
charge rates were based on the assumption that two percent of capacity is
used in coke making. According to Ref. 5-3, coke capacity of 43,410 tons
5-21
-------
is obtained from a daily feed capacity of 14. 2 X 10 bbl. At 300 Ib/bbl,
we obtain
43,410 ton/day y ' '->--— /s. i\J\J — Lt * \j JQ
14.216X10 bbl/day x 300 Ib/bbl X
5.6 RESULTS AND DISCUSSION
Tables 5-2-a and 5-3-a summarize the results of the inventory
studies for process heaters, catalytic cracking, and the miscellaneous cate-
gories of fluid coking and equipment leakage.
Emission factor levels are generally found to be declining
gradually. This is expected to result from higher monetary values for fuel
and more stringent control of emissions through expansion and modernization.
The new ruling especially in regard to fluid catalytic cracking is estimated
o
to affect 0.67 X 10 bbl/year of fresh feed charge rates out of a total of
9 9
1.69 X 10 bbl/year by 1980. In other words, of the current 1.5 X 10 , nearly
one third of the total charge will either have been replaced or modernized
and will therefore be in compliance.
However, as seen in Tables 5-2-b and 5-3-b, large uncertain-
ties can exist in charge rate data, emissions, and other data. It is therefore
necessary to periodically revi ;v/ industry production trends, technology
achievements, and consumer demands which can impact the resulting year-to-
year data.
It was originally intended to compare emission level results
from the NEDS data. However, because of significant discrepancies found in
the past, this was not attempted here. The most recent NEDS data error
showed that total annual charge rate in fluid catalytic cracking was approxi-
mately a factor of 20 too high (Ref. 5-24). This error was acknowledged and
corrected in Ref. 5-25.
5-22
-------
5. 7 PETROLEUM REFINERY PRACTICES
5. 7. 1 Background
Familiarization with overall refinery technology (Ref. 5-23)
is prerequisite to understanding the refinery industry practices which con-
stitute important sources of atmospheric emissions. The raw feedstocks,
consisting mainly of crude oil but including, also, natural gas and asphalt,
are subjected to thermal or chemical treatments leading to a broad variety
of intermediate and finished products.
A single refinery may not produce all petroleum products,
even in the most diverse of the major composite refineries. Significant dif-
ferences occur in chemical composition and physical properties of the crude
liquid feedstocks that are available to an individual plant. For example, some
crudes are highly amenable to the economical production of lubricants and
waxes, whereas others may be less so. The fundamental determinant defining
which products will be produced at a given refinery is economics. Economics
includes not only such factors as equipment capitalization, operating costs,
and product values, but also feedstock costs and variability.
5. 7. 2 Refinery Processing Overview
It is desirable to recognize certain types of similar refinery
processes and operations from a chemical engineering aspect. The more
important manufacturing procedures that may be associated with atmospheric
emissions are identified as follows:
a. Topping
b. Crude distillation
c. Gasoline stabilization
d. Vacuum flash operation
e. Cracking (thermal and catalytic)
f. Catalytic reforming
g. Hydroprocessing
h. Alkylation
i. Isomerizatiqn
5-23
-------
Topping
The basic operation in all refineries is atmospheric pressure
distillation. This operation, known as *opping, represents the first step in
the fractionation of crude oil feedstock into various boiling range components
such as gasoline, kerosene, distillates, lubricants, and fuels. Crude-oil
distillation normally requires preheating the feedstock in a heat exchanger
train and/or direct-fired heaters before being fed to the distillation tower
units. The overhead stream condensate (raw straight-run gasoline) goes to a
stabilizer column for pro pane-butane removal, yielding stabilized straight-
run gasoline for later treatment and octane upgrading. The side streams,
which boil at intermediate temperatures, yield naphtha, kerosene, diesel oil,
and gas oil. The bottom stream, also called reduced crude, may be vacuum-
fractionated for lube manufacture or run (with gas oil) into cracking units for
conversion into lower molecular weight products, particularly gasoline.
Cracking
The major forms of cracking are thermal and catalytic pro-
cesses. At one time during World War II, overall gasoline yield from crude
was less than 40 percent, and thermal cracking accounted for more than
20 percent of total gasoline yield from crude. Thermal processes are now
mainly used for viscosity breaking (visbreaking) of reduced crudes and for
coke production. Catalytic c rz. ;king is used mostly with gas oil but may
sometimes be used on various fractions, including naphtha and residuals.
The process takes one of several forms, depending upon the method of hand-
ling the catalyst. Fluidized bed catalytic cracking represents the largest
overall capacity in the United States, followed by Thermofor and Houdriflow
moving bed processes. Cracking causes decomposition of the higher molecu-
lar weight constituents of petroleum, which produces products in lower boiling
ranges. These include large amounts of olefinic gases, gasoline, and recycle
oil. Coincident with the disintegration mechanisms, coke deposits on the
catalyst. The amount and rate of coke formation varies with the type of feed
5-24
-------
and catalyst, system design, and operating conditions. Generally, the
coking laydown ranges between 4 and 10 percent of the fresh feed charge
(Ref. 5-23).
Since catalyst activity declines with coke deposition, reactiva-
tion is required and is accomplished by periodic burnoff of the coke with air.
Modern systems operate continuously by recirculating finely divided catalyst
beads between the reactor and the regenerator. Regenerator off gases contain
the usual combustion products of HC, but complete combustion of carbon is
seldom accomplished during regeneration. Concentrations of CO in the flue
gases, therefore, are also variable but generally 8 to 10 percent by volume.
Further combustion of these gases in flares or CO boilers may be accom-
plished to recover heat energy and to minimize emissions. Cyclone sepa-
rators are the means used to retain the solids in the circulating system.
Additional separation equipment in the form of electrostatic precipitators
can be used to further recover catalyst fines.
Recent advances have occurred in fluid catalytic cracking,
including the use of highly active zeolitic catalysts, higher pressures and
temperatures, more efficient equipment, and improved construction materials.
Higher equipment capacities, improved conversion and energy utilization,
higher octane products, and greater operating flexibility have resulted. Des-
criptions of several modern catalytic cracking processes as practiced by major
refiners are provided in Ref. 5-26. Considerable study effort was devoted
to catalytic cracking practices because of the overall impact of these practices
on atmospheric emissions.
Catalytic Reforming
Catalytic reforming causes rearrangement of HC molecules,
primarily accompanied by hydrogen abstraction (dehydrogenation) or addition
(hydrogenation). The process is used to upgrade low-octane naphtha to high-
octane gasolines and to produce aromatics such as benzene, toluene, and
xylene (BTX). Reforming was developed in the late 1940s and early 1950s
with a platinum catalyst on a ceramic substrate. One of the main advantages
of the so-called platforming process at that time was the great improvement
5-25
-------
in catalyst lifetime relative to existing cracking catalysts. In catalytic crack-
ing, about 10-gal oil/lb catalyst could be processed before regeneration was
needed while the reforming processes could treat 1000-gal oil/lb catalyst. By
1956, as much as 10, 000-gal oil/lb catalyst could be treated. Other advan-
tages of reforming included resistance to permanent catalyst poisoning, ability
to achieve multiple reactions simultaneously (e.g., dehydrogenation, dehydro-
isomerization, dehydrocyclization, isomerization, and hydrodesulfurization).
In short, the process was used to produce a high quality gasoline known as
reformate and a high yield of aromatics (for which there existed a high market
demand at the time). More recently, catalytic reforming processes have
become a valuable source of byproduct hydrogen. As in the case of catalytic
cracking, newer catalysts (some including nonnoble materials) are being
developed. The processes are variously referred to as platforming, magna-
forming, houdriforming, powerforming, rheniforming, and ultraforming *
(Ref. 5-26).
A particular type of reforming process involving rearrange-
ment of a HC molecular structure is known as isomerization. Originally,
isomerization involved the vapor-phase conversion of HC from one structure
to another by an acid catalyst (e.g., butane to isobutane, C, isomerization;
pentane to isopentanes, C- isomerization). Now, more modern plants
such as Butamer, Penex, and Hysomer process reactants in the presence of
highly active and selective fixe J-bed noble catalysts. Such plants are often
operated in conjunction with alkylation facilities. The clear octane ratings
of isomerization products is significantly improved. Unconverted reactants
are often recycled.
Hydroprocessing
The rapid increase in catalytic reforming capacity during the
past 25 years and the consequent availability of large amounts of hydrogen
produced therefrom has stimulated the development of refinery processing
in which the low-cost hydrogen is consumed or used within a particular
process. The general terms hydroprocessing, hydrotr eating, and hydro-
refining are used to describe a multitude of production systems. The most
5-26
-------
usual applications are for desulfurization (also called hydrosulfurization) of
various petroleum fractions in which many of the more stable sulfur-containing
compounds, such as mercaptans, are destroyed catalytically into HC rem-
nants. The liberated sulfur combines with the hydrogen to form hydrogen
sulfide gas which requires removal to avoid emission to the atmosphere.
This may be accomplished in several ways, often leading to recovery of
marketable byproduct sulfur compounds.
Some of the more commonly known processes are Gulfining,
HDS, RDS, VRDS, and ultra sweetening. Besides desulfurization treatments,
hydrogen processing includes selective hydrogenation treatment of certain
olefin or aromatic stocks and lube oil improvement. Finally, there are
combination processes such as ultrafining. A number of hydroprocessing
plant descriptions are contained in Ref. 5-26.
Rebuilding Processes
Several processes are used to rebuild various types of low
molecular weight of hydrocarbons into higher molecular weight species.
Alkylation and polymerization are processes in which unsaturated two-,
three-, and four-carbon atom gases are reacted in order to form high-octane
branched chain hydrocarbons for gasoline. The olefinic feedstocks are
usually cuts obtained from catalytic cracking. When olefins are added to
olefins, the product is called polymer gasoline. When an olefin is connected
to a saturated molecule such as isobutane, the product is called alkylate.
Alky late finds extensive use in aviation gasoline.
Other Processes
Several other refinery processes were examined but do not
appear at this time to be significant factors relating to atmospheric emissions
in terms of volatile HC, CO, CO,, or NO except, perhaps, from the stand-
£* x.
point of requiring boiler-produced steam or direct-fired thermal energy.
These include the following:
a. Light oil treating
b. Lube oil processing
5-27
-------
c. Asphalt manufacture
d. Sulfur recovery
e. Wax forming operations
Coking processes involve relatively severe cracking for converting heavy
components (such as pitch and tar) into lighter products (such as gas oil and
coke) for fuel and other specialty uses. Two major processes are delayed
coking and fluid coking, the latter being a continuous fluidized bed circulation
flow process. In withdrawing the coke product from the system, some
entrainment of particulates does occur as the gases pass through the cyclone
separators and disperse to the atmosphere.
5. 8 REFERENCES
5_ 1. NEDS Source Classification Codes and Emission Factor
Listing (SCC Listing), U.S. Environmental Protection
Agency, Washington, B.C. (July 1974).
5-2. Energy Statistics, Department of Transportation,
Washington, B.C. (August 1974), p. 57.
5-3. A. Cantrell, "Annual Refining Survey, " The Oil and Gas
Journal (1 April 1974).
5_4. E. J. Cahill and A. L. Grossberg, Current and Future
Trends in United States Gasoline Supply, SAE Paper
No. 730516, Society for Automotive Engineers, New York
(1973).
5-5. W. G. Bupree, Jr. and J. A. West, United States Energy
Through the Year 2000, U.S. Department of the Interior,
Washington, B.C. (Becember 1972).
5-6. W. B. Bryant, "Trends in the Qil Industry, " Chemical
Engineering Progress, 7£ (8) (August 1974).
5-7. "The Energy Outlook for the United States, " The Oil and
Gas Journal, 59 (16 September 1974).
5-8. M. W. Nichols, "Balancing Requirements for World Oil
and Energy, " Chemical Engineering Progress, 70 (10)
(October 1974)"! ~
5-28
-------
5-9. A. L,. Aim, "Energy and the Environment: Choices for
the Future," Chemical Engineering Progress, 70 (12)
(December 1974).
5-10. "News Features. . . Oil Price Drop? , " Chemical Engineering,
34 (February 3, 1974).
5-11. W. W. Reynolds and H. S. Klein, "Petrochemical and
Energy in Perspective," Chemical Engineering Progress,
Ti_, (3) (March 1975).
5-12. "Fuel and Steam Required in Average U. S. Refinery,"
The Oil and Gas Journal (April 21, 1958).
i
I
5-13. "Industrial Processes, Petroleum Industry Category, "
NEDS Data, The Aerospace Corporation Tape Analysis,
The Aerospace Corporation, El Segundo, California
(February 25, 1975).
5-14. L. R. Aalund, "Refining Capacity Registers Largest
'Nickel and Dime1 Jump in History, " The Oil and Gas
Journal (April 1974).
5-15. "Air Programs; Standards of Performance for New
Stationary Sources Additions and Miscellaneous
Amendments, " Federal Register, 39(47), Part II
(8 March 1974).
5_16. Journal of the Air Pollution Control Association, 24 (4),
362,364 (April 1974).
5-17. A. L. Conn, "Developments in Refining Processes for
Fuels, " Chemical Engineering Progress, 69 (12)
(December 1973).
5-18. "Striking Advances Show Up in Modern FCC Design, "
The Oil and Gas Journal (October 30, 1972).
5_19. "NPRA Q&C - 3, Answers for Process Questions of
FCC Units, " The Oil and Gas Journal (March 11, 1974).
5_20. Background Information for Proposed New Source Per-
formance Standards, Vol. 1, Main Text, U.S. Environ-
mental Protection Agency, Washington, D.C. (June 1973).
5_21. Background Information for New Source Performance
Standards, Environmental Protection Agency, Vol. 3,
Promulgated Standards, U.S. Environmental Protection
Agency, Washington, D.C. (February 1974).
5-29
-------
5-22. "Question on Technology," The Oil and Gas Journal
(February 5, 1973).
5-23. W. L. Nelson, Petroleum Refinery Engineering, 4th ed.,
McGraw Hill Book Co. , Inc. , New York (1958).
5-24. E. K. WeinLorg to O. Dykema, The Aerospace Corporation
Memo No. 75-5124.31-16, "Data Error in EPA National
Emissions Data Systems (NEDS)" (13 May 1975).
5-25. O. W. Dykema to J. G. Summers, U.S. Environmental
Protection Agency Memo (September 1975).
5-26. Hydrocarbon Processing (1974 Refining Process Handbook ,
Issue) (September 1974).
5-30
-------
SECTION VI
POINT SOURCE EVAPORATION
6.1 INTRODUCTION
The point source evaporation category of stationary source
emissions is comprised of activities involving cleaning solvents, surface
coatings, and the storage and marketing transportation of petroleum products.
The emissions of concern are hydrocarbons (HC), which are approximately
99 percent of all point source evaporative emissions.
Forty-nine Source Classification Code (SCC) categories were
identified from Ref. 6-1 which emitted 500 tons per year or more of pollutant.
These point source emission categories formed the list of activities studied
in the HC evaporation category. For better identification of the nature of HC
emissions from evaporation, many of the 49 SCCs were subdivided to yield a
total of 85 processes, which were identified as modified SCCs (MSCC)
categories.
6.2 SUMMARY
The total HC evaporation rate from point sources in 1976 was
4. 25-million tons/year and is estimated to drop by 40 percent to 2.5-
million tons/year in 1981.
The largest contributor to these totals is the paint and surface
coating application industries. The most dramatic reduction in estimated
emissions between 1976 and 1981 occurs in the petroleum products storage
category. The reduction is estimated to be 1. 15-million tons/year (1.65 to
0- 50) or a minus 70 percent change in the 5-year period. This reduction is
6-1
-------
based on an assumed elimination of the use of fixed-roof tanks for the storage
of the most volatile products (gasoline and crude oil).
Table 6-1 presents the MSCC number, description, and charge
rate unit for the point source evaporation categories studied. A detailed list
of emissions from evaporation and total annual charge rates (TACRP) is
shown in Tables 6-2 and 6-3 for 1976 and 1981, respectively.
6.3 PROCESSES EVALUATED
According to the National Emissions Data System (NEDS)
(Ref. 6-2), 4.5-million tons of HC vapor are annually evaporated into the
atmosphere from stationary point sources. This represents 58 percent of
the total (evaporation plus combustion) point source HC emissions and 40
percent of the total (point plus area) stationary source HC emissions. In
addition to the 4.5-million tons/year of HC from point source evaporation,
Ref. 6-2 lists another 2. 75-million tons/year of HC from area source
evaporation. (A point source is identified as more than or equal to 100 tons/
year; an area source is less than this amount.) Except for HC evaporation
from handling gasoline at retail outlets (filling stations), no consideration
was given to area source emissions. This section presents discussions of
the processes that produce stationary source HC evaporative emission.
6.3.1 Cleaning Solvents
Cleaning solvents are broadly divided into two application
categories: (1) dry cleaning of clothing and (2) degreasing of metal and
other parts.
The emissions from cleaning solvents represent only about
3 percent of total point source evaporation. Petroleum (Stoddard) and chlori-
nated synthetic (Perchlorethylene) solvents are used for both applications
where trichlorethane, trichloroethylene^ and methylene chloride are used
only for degreasing operations. Although the petroleum-based solvent is
considered the most attractive from a low pollution standpoint, because it is
not photochemically reactive, its production rate is on the decline. It is
(Continued on page 6-39)
6-2
-------
Table 6-1. DEFINITION OF HC EVAPORATION
MSCC
Source Category
Charge Rate Unit
401001010
401001020
401002010
401002020
401002030
401002050
401002990
Perchlorethylene dry cleaning
Stoddard dry cleaning
Stoddard degreasing solvent
Trichleroethane degreasing solvent
Perchloroethylene degreasing
solvent
Trichloroethylene degreasing
solvent
Clothes, tons/yr
Clothes, tons/yr
Solvent, tons/yr
Solvent, tons/yr
Solvent, tons/yr
Solvent, tons/yr
Miscellaneous degreasing solvent Solvent, tons/yr-
402001011
402001012
402001013
402001014
402001015
402001016
402001017
402001018
402001019
402002011
402002012
402002013
402002014
402002015
402002016
402002017
402002018
402002019
Sheet, strip, and coil paint
Auto and truck paint
Major appliances paint
Industrial machinery paint
Wooden furniture paint
Metal furniture paint
Small appliances paint
Farm machinery paint
Commercial machinery paint
Coating for coated paper
Coating for folding cartons
Coating for craft paper
Coating for milk cartons
Coating for paper bags
Coating for paper boxes
Coating for paper tubes and cans
Coating for printing paper
Coating for waxed paper
Paint, tons/yr
Paint, tons/yr
Paint, tons/yr
Paint, tons/yr
Paint, tons/yr
Paint, tons/yr
Paint, tons/yr
Paint, tons/yr
Paint, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
6-3
-------
Table 6-1. DEFINITION OF HC EVAPORATION (Continued)
MSCC
402003011
402003013
402003014
402003017
402003019
402004011
402004012
402004015
402004017
402005011
402005012
402005013
402005016
402005017
402006011
402006012
402006014
402006016
402006017
402006019
402007011
402007012
402007013
Source Category
Varnish and shellac on sheet,
strip, and coil
Varnish and shellac on major
appliances
Varnish and shellac on industrial
machinery
Varnish and shellac on small
appliances
Varnish and shellac on commercial
machinery
Lacquer on sheet, strip, and
coil
Lacquer on autos and trucks
Lacquer on wooden furniture
Lacquer on small appliances
Enamel on sheet, strip, and coil
Enamel on autos and trucks
Enamel on major appliances
Enamel on metal f irniture
Enamel on small appliances
Primer on sheet, strip, and coil
Primer on autos and trucks
Primer on industrial machinery
Primer on metal furniture
Primer on small appliances
Primer on commercial furniture
Dye for fabric
Permanent crispness solution
for fabric
Sizing solution for fabric
Charge Rate Unit
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Coating,
Solution
Solution
Solution
tons /yr
tons /yr
tons /yr
tons /yr
tons/yr
tons /yr
tons /yr
tons/yr
tons/yr
tons/yr
tons/yr
tons/yr
tons/yr
tons /yr
tons/yr
tons /yr
tons/yr
tons /yr
tons /yr
tons/yr
, tons/yr
, tons/yr
, tons/yr
6-4
-------
Table 6-1. DEFINITION OF HC EVAPORATION (Continued)
MSCC
Source Category
Charge Rate Unit
402007014
402007015
402008011
402008012
402999990
Waterproof solution for fabric
Wrinkle resistance solution
for fabric
Oven coating for sheet, strip,
and coil
Oven coating for autos and trucks
Miscellaneous surface coating
activity
Solution, tons/yr
Solution, tons/yr
Coating, tons/yr
Coating, tons/yr
Coating, tons/yr
403001011
403001021
403001031
403001041
403001051
403001061
403001071
403001501
403001511
403001521
403002011
403002021
403002031
Fixed-roof tank gasoline breathing
loss
Fixed-roof tank crude breathing
loss
Fixed-roof tank gasoline working
loss
Fixed-roof tank crude working loss
Fixed-roof tank JP-4 breathing loss
loss
Fixed-roof tank kerosene breathing
loss
Fixed-roof tank distillate breathing
loss
Fixed-roof tank JP-4 working loss
Fixed-roof tank kerosene working
loss
Fixed-roof tank distillate working
loss
Floating-roof gasoline tank
standing loss
Floating-roof gasoline tank
working loss
Floating-roof crude tank
standing loss
Storage capacity,
1000 gal
Storage capacity,
1000 gal
Throughput,
1000 gal/yr
Throughput,
1000 gal/yr
Storage capacity,
1000 gal
Storage capacity,
1000 gal
Storage capacity,
1000 gal
Throughput,
1000 gal/yr
Throughput,
1000 gal/yr
Throughput,
1000 gal/yr
Storage capacity,
1000 gal
Throughput,
1000 gal/yr
Storage capacity,
1000 gal
6-5
-------
Table 6-1. DEFINITION OF HC EVAPORATION (Continued)
MSCC
Source Category
Charge Rate Unit
403002041
403002051
403002061
403002071
403003020
403999990
Floating-roof crude tank working
loss
Floating-roof JP-4 tank standing
loss
Floating-roof kerosene standing
loss
Floating-roof distillate standing
loss
Variable vapor-space gasoline
working loss
Miscellaneous petroleum product
storage loss
Throughput,
1000 gal/yr
Throughput,
1000 gal/yr
Storage capacity,
1000 gal
Storage capacity,
1000 gal
Throughput,
1000 gal/yr
Stored, 1000 gal
406001011
406001012
406001021
406001022
406001261
406001262
406001271
406002010
406002260
406002270
Load gasoline on tank cars,
splash
Load gasoline on tank trucks,
splash
Load crude on tank cars, splash
Load crude on trucks, splash
Load gasoline on tank cars,
submerge
Load gasoline on tank trucks,
submerge
Load crude on tank cars,
submerge
Load gasoline onto marine vessels
Unload gasoline from marine
vessels
Unload crude from marine vessels
Transferred,
1000 gal/yr
Transferred,
1000 gal/yr
Transferred,
Transferred,
Transferred,
1000 gal/yr
Transferred,
1000 gaVyr
Transferred,
1000 gal/yr
Transferred,
Transferred,
1000 gal/yr
Transferred,
1000 gal/yr
6-6
-------
Table 6-2-a. 1976 HC EVAPORATION EMISSIONS AND CHARGE RATES
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
MODIFIED
SCC
401001000
401001010
401001020
401002000
401002010
401002020
401002030
401002050
401002990
401999000
401999990
402001000
402001010
402001011
402001012
4020010
4020010
4020010
4020010
402001019
402002000
402002010
402002011
402002012
TACRP
(SCC UNITS)
41850.
29420.
12430.
114460.
NOX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
EMISSIONS (MILL
HC
RUN DATE*
IONS OF TONS
CO
PAGE 1
MAR 22»1977
/ YEAR)
,004
.002
• 002
.103
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
MS: Silti
7213. NEGL
9?JI8: Rift]
ft fti -881' Bi£H£i
ulDLC .003 ffcbLlb
G BLE .006 NEGLIG
GIBLE .005 NEGLIG
GIBLE .083 NEGLIG
BLE NEGLIGIBLE
lit NEGLIGIBLE
BLE NEGLIG BLE
BLE NEGLIG BLE
BLE NEGLIGIBLE
113650. NEGLIGIBLE .025 NEGLIGIBLE NEGLIGIBLE
115650. NEGLIGIBLE .025 NEGLIGIBLE NEGLIGIBLE
438000. NEGLIGIBLE .224 NEGLIGIBLE NEGLIGIBLE
438000. NEGLIGIBLE .224 NEGLIGIBLE NEGLIGIBLE
310000. NEGL1
84000. NEGL
»H«: Hill
10704. NEGL
8168. NEGL;
2218. NEGL
3272. NEGL
143$. NEGL1
GIBLE .174 NEGLIGIBLE NEGLIGIBLE
GIBLE .033 NEGLIGIBLE NEGLIGIBLE
GI3LE .004 NEGLIGIBLE NEGLIGIBLE
GIBLE .003 NEGLIGIBLE NEGLIGIBLE
GIBLE .004 NEGLIGIBLE NEGLIGIBLE
GIBLE .003 NEGLIGIBLE NEGLIGIBLE
GIBLE .001 NEGLIGIBLE NEGLIGIBLE
GIBLE .001 NEGLIGIBLE NEGLIGIBLE
[GIBLE .001 NEGLIGIBLE NEGLIGIBLE
10136000. NEGLIGIBLE .441 NEGLIGIBLE NEGLIGIBLE
10136000. NEGLIGIBLE .441 NEGLIGIBLE NEGLIGIBLE
131720. NEGLIGIBLE .061 NEGLIGIBLE NEGLIGIBLE
21100. NEGLIGIBLE .004 NEGLIGIBLE NEGLIGIBLE
-------
Table 6-2-a. 1976 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYDPOCARBCN EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
PAGE 2
RUN DATE- MAR 22,1977
MODIFIED
SCC
402002013
402002014
402002015
402002018
402002019
402003000
402003010
4020030]
40200301
mm
4020030]
402004000
402004010
402004011
402004012
402004015
402004017
402005000
402005010
402005011
402005012
402005013
402005016
TACRP
tSCC UNITS)
NOX
EMISSIONS
144240.
27980.
9328000.
603ft!
3254001
27M70.
274170.
264000.
9240*
ill:
95*
75735.
75735.
29900.
41760.
4022.
53.
298340.
298340.
118900.
167040.
11920.
240.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Bftttltti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
(MILLIONS
HC
.063
.025
.196
.044
.033
.181
.181
.174
.006
looo
.056
.056
.022
.031
.003
.000
.172
.172
.068
:m
.000
OF TONS
CO
/ YEAR)
PART
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
GIBLE
GIBLE
GIBLE
GI8
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
SEGLIGIBLE
EGLIGIBLE
atitUiihi
HfEkigiltf
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
BLE
BLE
NEGLI
NEGLI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-2-a. 1976 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
RUN DATE
MODIFIED
SCC
402005017
TACRP
(SCC UNITSI
244.
EMISSIONS (MILLIONS OF TONS /
NOX HC CO
NEGLIGIBLE
.000
NEGLIGIBLE
PAGE 3
22,1977
YEAR)
PART
NEGLIGIBLE
402006000
402006010
402006011
876030.
876030.
650000.
20880.
476.
402006019
.
92.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
EHt:
N£
M
NEGL]
G
G
GIBLE
.467
.467
.453
looo
.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
EGLIGIBLE
ELIGIBLE
EGLIGIBLE
402007000
402007010
4020070:
4020070!
4020070
4020070
40200703
1583700.
1583700,
334600.
270.
1056800.
10672.
181400.
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL]
NEGL]
NEGL
NEGL]
BLE
BLE
BLE
BLE
BLE
.229
.229
.000
.011
.000
.001
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL]
NEGL
NEGL
NEGL]
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGL
G
BLE
B
B
BLE
BLE
L
L
402008000
402008010
402008011
402003012
170640.
170640.
66240.
104400.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.104 NEGLIGIBLE
.104 NEGLIGIBLE
.040 NEGLIGIBLE
.064 NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
402999000
402999990
1500900.
1500900.
NEGLIGIBLE
NEGLIGIBLE
.202 NEGLIGIBLE
.202 NEGLIGIBLE
.010
.010
-------
Table 6-2-a. 1976 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
ANNUAL CHARGE
HYD
RATES ANO EMISSIQ
o
MODIFIED
sec
403001000
403001010
403001011
403001020
403001021
403001030
403001031
403001Q40
403001041
403001050
403001051
403001060
403001061
403001070
403001071
403001500
403001501
403001510
403001511
TACRP
tSCC UNITS)
17100000.
17100000.
1480000.
14 80 100.
43000000.
43000000.
18400000.
18400000.
124000.
124000.
500000.
500000.
6909400.
6909400.
48450000.
1570000.
20800000.
20800000.
8QCAR80N EVAPORATION
KS PROJECTED TO 1976
EMISSIONS CHILLI
HC
RUN DATE*
PAGE 4
HAS 22*1977
NOX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
ONS OF TONS / YEAR)
CO
1.318
.389
.889
.044
.044
.223
.223
.082
.082
.002
.002
.004
.004
.050
.050
.025
.002
.010
.010
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIB! E
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-2-a. 1976 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
RUN DATE'
PAGE 5
MAR 22*1977
MODIFIED
sec
403001520
403001521
403002000
403002010
403002011
403002020
403002021
403002030
403002031
403002040
403002041
403002050
403002051
i
403002060
403002061
403002070
403002071
TACRP
(SCC UNITS)
26080000.
260BOOOO.
7920000.
7920000.
9600000.
9600000.
10760000.
10760000.
48800000.
48800000.
89700.
89700.
52000.
52000.
154000.
154000.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.012 NEGLIGIBLE
.012 NEGLIGIBLE
.200 NEGLIGIBLE
.053 NEGLIGIBLE
.093 NEGLIGIBLE
.013 NEGLIGIBLE
.013 NEGLIGIBLE
.057 NEGLIGIBLE
.057 NEGLIGIBLE
.077 NEGLIGIBLE
.077 NEGLIGIBLE
.000 NEGLIGIBLE
.000 NEGLIGIBLE
.000 NEGLIGIBLE
,000 NEGLIGIBLE
.000 NEGLIGIBLE
.000 NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
403003000
14860000.
NEGLIGIBLE
.065
NEGLIGIBLE NEGLIGIBLE
-------
Table 6-2-a. 1976 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
t\J
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976
RUN DATE
PAGE 6
MAR 32*1977
MODIFIED
sec
403003020
403999000
403999990
406001000
406001010
18*881811
406001020
l
406001021
406001022
406001260
406001261
406001262
406001270
406001271
i 406001272
406002000
406002010
mmm
406002270
TACRP
(SCC UNITS)
14860000.
ISOOOOOt).
15000000.
81932000.
229
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES
HYDROCARBON EVAPORATION
TACR AND EHISSION UNCERTAINTIES PROJECTED TO 1976
PAGE 1
RUN DATE- MAR 22,1977
MODIFIED
SCC
401001000
401001010 +
401001020 *
401002000 *
401002010 +
401002020 +
401002030 +
401002050 «•
401002990 *
401999000 +
401999990 +
402001000 «•
402001010 *
402001011 *
402001012 +
TACRP
ISCC UNITS)
23350.
15367.
9035.
9035.
21540.
12430.
51063.
51063.
Wl
2121.
2121.
1389.
1389.
50990.
50990.
18320.
18320.
18320.
18320.
3874
3874
iBtt:
32202.
32202.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
NEGLIGIBLE
NEGLIGIBLE
N
N
LIGIBL
LIGIBL
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGLIG
L
L
NEG
NEGL
NEGL
G
BLE
BLE
BLE
BLE
GIBL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NE
NE
GLIGIBL
NEGLIGIBL
K£
NE
NE
NE
ItiEHtl
itiSittl
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.050
.050
+ .005
- .005
* .005
- .005
^ :8i*
* .021
- .021
i :m
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
BiS
Hift
NEGL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
S
BLE
flfft
Riit
NEGL GIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
El
mil
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
N
N
GLIGIBL
GLIGIBL
a
LI
LI
IBL
IBL
HfEHEUtf NfEtiEiiti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGClGIBEi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN OAT£« HAR
MODIFIED »crJ*3l8?rr» *nv EMISSIONS (MILLIONS OF TONS /
SCt iSCC UNITS) NOX HC CO
o
402001013
402001014
402001015
402001016
402001017
402001018
402001019
4-
4
*
1690.
1406.
1406«
2276.
2276.
221.
221.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
KgGLj
NEGLI
NEGLIG
S
ti
_
BLE
NEGLIGIBLE
gttiSHti
177.
:GLI<
:GLI(
IBLE
I3t€
.902
, 002
.001
.000
,000
NEGLIGIBLE
NEGLIGIBLE
N6GL.K,:
NEGLI<
N£GLI<
NE3LIG]
NEGLIG
NEGLIG
NEGLIG
NEGLIGIBLE
ttittfEitti
NEGLIGIBLE
NEGLIGIBLE
PAGE 2
22,1977
NEGLIGIBLE
NEGLIGIBLE
NEGLI
BiGL.
IGL:
NEGL
NEGL
NEGL
NEGL:
NEGLIGIBLE
tliitiiilti
NEGLIGIBLE
NEGLIGIBLE
GI
402002000
402002010
402002011
40Z002012
402002013
402002014
402002015
402002016
402002017
402002018
4-
+
3219300.
3197600,
3219300.
3197600.
44939.
44939.
72^5,
7205.
49172.
49172.
9544.
9544.
3194000.
33
•GLIGIBLI
IGLIGIBLi
2063.
2068.
26406.
264^6.
NEGLIGIBLE
NESLIG I3L5
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
:G
NEGLIGIBLE
NEGLIGIBLE
Ni
Ni
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Ni
Nf
GLIG13LS
GLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGI8L
NEGLIGIBL
NEGLIGIB
MEGLIGIB
N
NEGLIGIBLE NEGLIGIBLE
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
HYDffQCARBCN EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
MODIFIED
SCC
402002019
TACRP
CSCC UNITS)
EMISSIONS (MILLIONS OF TONS
NOX HC CO
PAGE 3
RUN DATE- MAR 22*1977
t YEAR)
mm-, mmmi i -.m
PART
402003000
402003010
402003011
402003013
402003014
402003017
402003019
4
4
4
26919.
26919.
>6880.
!6880.
1434.
1434.
93.
93.
II:
87.
87.
•GLIGIBLI
;GLIGIBLI
N
NEGL]
L
GIBL
SIH§
pIBLE
NEGLIG
NEGI
NEGLIGIBLE
mmm
NEGLIGIBLE
NEGLIGIBLE
.019
.019
Nj
Nf
iLIi
JLK
IBLj
I8LI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBL!
NEGLIGI8LI
NEGLIGIBLE NEGLIGIBL
NEGLIGIBLE NEGLIGIBLI
NEGLI
NEGLI
NEGLIG
NEGLIG
NEGLIG
NEGLIGIBLE
HftH&Utf
NEGLIGIBLE
NEGLIGIBLE
BLE
BLE
BLE
BLE
BLE
402004000 4
402004010 4
402004011 4
402004012 +
402004015 *
402004017 *
11094.
11094.
3064.
3064.
10628.
10628.
855.
855.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
61
;G
NEGL]
NEGL
NEGL]
NEGL
NEGL
(Eft
NEGLIGIBLE
BLE
BLE
BLE
BLE
BLE
m
4 .010
- .010
4 .010
- .010
4 .004
- .004
4 .009
- .009
4 .001
4 .1
- .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIG
NEGLIG
NEGL
NEGL
NEGL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEG
NEG
NEG
Hi!
NEGLIGIBLE
BLE
BLE
LE
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE-
MODIFIED
SCC
402005000
402005010
402005011
402005012
402005013
402005016
402005017
TACRP
(SCC UNITS)
44162.
44162.
*
+
tttti:
4? 79.
42 79.
1843
4 A.
II:
x«
NOX
EMISSIONS (MILLIONS OF TONS
NEGLIGIBLE
NEGLIGIBLE
mm
NEGLIG
let
BLE
HC
* .026
- .026
- .025
* ,002
•f
*
CO
PAGE 4
MAR 22,1977
/ YEAR)
NEGLIGIBLE
NEGLIGIBLE
i -M Ulitililt
NEGLIGIBLE
a
PART
NEGLIGIBLE
NEGLIGIBLE
mm
NiEtiEiit
NEGLIGIBLE
G
402006000 +
402006010 +
402006011 +
402006012 +
402006014 *
402006016 +
402006017 «•
402006019 +
Bttfc
87522.
•®!:
9£'
746»
746.
33.
33.
11.
11.
NEGLIGIBLE
ntft
NEGL
NEGL
NEGL
NEGL
NfGL
NEGL
NEGL
-^
g
G
tl
iti
iti
3 Li
BLE
BLE
* -811 BiM-tfHU BKHSHtl
•~ .093 NeGLlSlBLc NcSLl&loL!
* *
~ •
093 NEGLIGIBLI
093 NEGLIGIBLI
• w ^^
; :89
.093
93
03
- .090
NEGLIGIBLE
NEGL
NEGL
it
Ni
Ni
Ni
NEGL
NEGL
it!
BLI
BLI
BL!
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Nfitiiliti
Ni
NI
Ni
N{
)I&
;!s
NEGLIGIBLE NEGLIGIB
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
i
i-»-
^j
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE
MODIFIED
SCC
402007000
402007010
402007011
402007012
402007013
402007014
402007015
402008000
402008010
402008011
402008012
TACRP
(SCC UNITS)
+
+
+
fc
106620.
106620*
32025.
32025.
26.
1000
10
1000.
18013.
18013.
27605.
27605.
27605.
27605.
NOX
ofEtttitti
mmm
NEGLIGIBLE
NEGLIGIBL
fcEGLIGIBL
tfEt
EMISSIONS
NEGLI
NEGL
g;
G:
BL
BLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mmm
(MILL
HC
IONS OF TONS /
CO
PAGE 5
MAR 22,1977
YEAR)
.119
.119
.119
1 000
.009
.000
.000
.018
.018
.018
.018
K!
•GLIGIBLI
•GLIGIBLI
NEGL
NE
NE
NEGL]
NEGL)
NEGL
GIBLE
iti
tti
BLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
i :l« UigtiEilti ftfttii
NEGLIGIBLE
NEGLIGIBLE
NEGL
urn
fliSt
flftt
NEGL
NEGL
NEGL
GI
G
BLE
Iti
m
3LE
BLE
BLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Higtigfiti mtimt
402999000 +
402999990 *
403001000
253400.
253400.
253400.
253400.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
*»
*
!
.040
.040
.040
.040
.352
.351
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* .002
- .002
* .002
- .002
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
jO
HYDRQCAR8CN EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE'
MODIFIED
SCC
403001010
403001011
403001020
403001021
403001030
403001031
403001040
403001041
403001050
403001051
403001060
403001061
4030010TO
+
«•
*
*
TACRP
CSCC UNITS)
3280200*
3280200*
3280200*
3280200.
82S&20.
824620*
82..520,
8246?0,
40447000.
40447000
40447000.
40447000^
18216000.
18216000.
18216000.
18216000.
8944
8944
89442.
89442.
Itti
to.
10.
316230.
316230.
NOX
EMISSIONS CMILLIONS OF TONS
HC
CO
PAGE 6
MAR 22.1977
/ YEAR}
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NE
K£
Nf
NE
GIBL!
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
*EGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NI-
NE
IIISIBLI
ILIGIBLi
NEGLK
NEGLK
I8L!
IBLi
,267
.267
.267
,267
- :m
* .212
- .212
* .083
- .082
> .083
- ,082
* .001
- ,001
* .001
- .001
.002
.002
MtittM - :ffi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Nl
Ni
NEGLI
NEGLI
IBLE
IBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Ni
Ni
N!
NI
Ni
•GLIGIBLE
ELIGIBLE
: GLIGIBLE
•GLIGIBLE
•GLIGIBLE
ELIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGI8L
NEGLI
Ni
Nf
GI8LJ
tiiilt!
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
•GLIGIBLE
•GLIGIBLE
EGLIGI3LE
•GLIGI8L
•GLIGISLE
•GLIGIBLE
NEGLIGIBLI
NEGLIGIBLI
Aigtfgfltl
Ni
Ni
Nj
Mi
Nf
N(
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
i
I-*
vD
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
RUN DATE-
MODIFIED
SCC
403001071
403001500
403001501
403001910
403001911
403001920
403001521
TACRP
SCC UNITS)
mm:
11111888:
800000.
800000.
8000000.
8000000.
NQX
EMISSIONS
Kgkigiiki
NEGLIGIBLE
NEGLIGIBLE
mum
mum
NEGLIGIBLE
NEGLIGIBLE
(MILLIONS
HC
.001
.001
.004
.004
Of TONS
CO
BiitKiltl
NfcliL iol Oil
PAGE 7
MAR 22,1977
/ YEAR)
PART
NEGLIGIBLE
NEGLIGIBLE
:;i
R!
ItiSfU
!ti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mmmi
HiEuemi
NEGLIGIBLE
NEGLIGIBLE
403002000
403002010
403002011
403002020
403002021
2218200
2218200
tlit
5590200.
5590200.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
GLIGIBLE
GLIGIBLE
NEGLIGIBL
NEGLIGIBL
.079
.075
.016
*• .016
- .013
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLI
NEGLI
L
L
Nl
Nj
Ni
Ni
•GLIGIBLI
IGLIGIBLI
IttKfttl
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
N-iatiiiii-E
NI
Ni
Nf
Ni
JLIGIBLI
iLIGIBU
itffflt!
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
I
• J
o
TACR AND EMISSION
HYD
UNCERTAINTIES
ROCARBON EVAPORATION
PROJECTED TO 1976
PAGE 3
RUN DATE- MAR 23*1977
«0{?££I£D c
403002030 +
403002031 +
403002040 *
403002041 *
403002050 *
403002051 +
403002060 *
403002061 *
403002070 *
403002071 *
ScPBElTS)
2236100.
2236100.
iiimS:
Ktti88:
8246^00.
8246^0.
45891.
45891,
45891*
45891.
15811.
15811.
15811.
15811.
47434.
47434.
WM:
NOX
NiftiSittf
NEGLIGIBLE
NEGLIGIBLE
SiltlSBti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
IONS (MILLIONS OF TONS / VEAR)
HC CO PART
+ .013
- .013
* .013
- .013
* • 9.Z&
* .074
- .070
* .000
- .000
* .000
- .000
* .000
- .000
+ .000
- .000
* . 000
- .000
- :888
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
BISHilS'-i
NtbL 1516 - 1
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE,
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
RfStigilti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
403003000 *
«•
403003020 *
- -.m m
371080.
371080.
NEGLIGIBL1
NEGLIGIBL!
.011 NEGLIGIBLE
.011 NEGLIGIBLE
GLIGIBLE
GLI
IBLE
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
EMISSIONS
RUN DATE'
MODIFIED
SCC
403999000
403999990
406001000
406001010
406001011
406001012
406001020
406001021
406001022
406001260
406001261
406001262
406001270
406001271
TACRP
(SCC UNITSI
8246200. Nl
8246200. NE
+ 8246200.
8246200.
* 7161400.
7161400.
+ 4921200.
4921200.
+ 89442.
89442.
* 4920400.
4920400^.
+ 456520.
456520.
* 8854.
8854.
* 456440.
456440.
+ 5162200.
5162200.
+ 89442.
89442.
«• 5161400.
5161400.
+ 459870.
459870.
NOX
GLIGIBLI
GLIGIBLJ
(MILLIONS OF TONS
HC CO
PAGE 9
MAR 22*1977
/ YEAR)
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIG
NEGLI
BLE
BL
NEGLIGIBLE
NEGLIGIBLE
fl
IStiifitl
NF
NE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.039
.047
.039
.Q47
.082
.082
.032
.052
.001
- .052
• .003
- .005
* . 000
* .000
+ .003
- .005
+ .075
- .062
+ .075
- .062
+ .010
- .010
Nl
Ni
•GLIGIBLI
[GLIGIBLi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Nl
N!
iGLIGIBLi
IGLIGIBLI
56080. Ni
56080. Nl
iGLIGIBLi
iGLIGIBLt
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NfcGLIGI
NEGLIGII
N!
Mi
[GLIGIBLI
EGLIGIBLI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
SEGLIGIBLE
IGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
SEGLIGIBLE
EGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-2-b. 1976 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE-
EMISSIONS (MILLIONS OF TONS
MODIFIED
SCC
406001272
TACRP
fSCC UNITS)
456440.
NOX
NEGLIGIBLE
NEGLIGIBLE
HC
* .010
- .010
CO
PAGE 10
MAR 22,1977
/ YEAR)
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLI
NEGLIGIBL!
I
ts)
Cs)
406002000
406002010
406002020
406002260
406002270
*
+
+
15430000.
15430000.
4640000.
464JOOO.
9Q42?QO.
9042900.
7280100,
728010C.
L£
I l\ .
+ .007
- .007
+ ,012
,023
KiEtiSHtf
mm]
NEGLIG
NEGLIG
NEGLIG
NEGLIG
NEGLIG
NEGLIG
M
BLE
BLE
BLE
BLE
BLE
[BLE
•GLIGIBLI
•GLIGIBLI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-3-a. 1981 HC EVAPORATION EMISSIONS AND CHARGE RATES
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
RUN DATE'
MODIFIED
SCC
401001000
401001010
401001020
401002000
mmm
401002030
401002050
401002990
401999000
401999990
402001000
402001010
402001011
402001012
402001013
402001014
402001015
402001016
402001017
402001018
402001019
TACRP
(SCC UNITS)
43000.
40570.
2430.
114560.
14213.
1670.
97450.
130690.
130690.
601620.
601620.
460000.
99000.
8]
6:
12:
81
21
2.
4.
'?!:
3762.
1592.
EMISSIONS (MILLIONS OF TONS /
NOX HC CO
PAGE 1
MAR 22*1977
YEAR)
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mt
NEGL
NEGL1
NEGL
I
GI8LE
6IBLE
GIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGU
NEGL
NEGL
*EGL
NEGL
BLE
3LE
G
BL
BL
BL
GIBL
GIBLE
.001
.001
.000
.096
.036
.002
.088
.014
.014
.145
.129
.011
.001
.001
.000
.000
.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
Kiibl
NEGL
NEGL
NEGL)
BLE
BLE
BLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
••-- • mr
BL
8L
BL
BLE
BLE
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEGI
I:
[G
G
G
G:
G
G:
G:
GI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
Hist
Silt
NEGL
GIBL
6I8LI
iiiti
GIBLE
GIBLE
GIBLE
402002000
402002010
402002011
402002012
6642900.
6642900.
86370.
13850.
NEGLIGIBLE
NEGLIGIBLE
JLIGI8LI
JLIGI8LI
.289 NEGLIGIBLE
.289 NEGLIGIBLE
.040 NEGLIGIBLE
.003 NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-3-a. 1981 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
no
IED
402002013
402002014
402002015
402002016
402002017
402002018
402002019
.scPBKrs.
94540.
18330.
6113000.
48830.
3956.
50620.
213400.
NEGL
NEGL
NEGL]
*SGL
NEGL
NEGL
NEGL
G
G
EHISSiQMS
BLE
BLE
BLE
BM
ILL
.-BLE
GIBLE
RUN DATE- MAR
OF JgNS /
PAGE 2
22,1977
.041 Nl
.016 N
.128 N
.009 N
.001 N
.029 N
.021 N
EGLIG]
•GLI6
EGLIG
EGLIG
•GLIG
•GLIG:
EGLIGl
[BLE NEG
BLE NEG
BLE NEG
:BLE NEG
[BLE NEG
•
.
G
i
6
G
BLE
BLE
BLE
BLE
BLE
BLE
BLE
402003000
402003010
402003011
402003013
402003014
402003017
402003019
402004000
402004010
402004011
402004012
401970.
401970.
394000.
7(
106*
97988.
97988.
44400.
48960.
4562.
66.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBL
NEGLIGIBL
N
N
.133 NEGLIGIBLE
.133 NEGLIGIBLE
.130 NEGLIGIBLE
!000 NEGLIGIBLE
.000 NEGLIGIBLE
LIGIBL
LIGIBL
.036
.036
.016
.018
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
flfftttilti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
402005000
402005010
402005011
402005012
402005013
402005016
382350.
382350.
235
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.110 NEGLIGIBLE
.110 NEGLIGIBLE
.050 NEGLIGIBLE
.056 NEGLIGIBLE
.003 NEGLIGIBLE
.000 NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-3-a. 1981 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
i
ro
HYDROCAR8CN EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
RUN DATE'
PAGE 3
MAR 22,1977
MODIFIED
sec
402005017
402006000
402006010
mmm
402006014
402006016
mmii
402007000
402007010
402007011
402007012
402007013
402007014
402007015
402009000
402008010
402008011
402008012
402999000
402999990
TACRP
(SCC UNITS)
303,
1294500.
1294500.
*!«!:-
1652700.
1652700.
349100.
282.
1102800.
11137.
189400.
220940.
220940.
98540.
122400.
1693600.
1693600.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.000
.344
.344
«O07
* ^23
•888
.239
.239
.227
.000
• Oil
.000
.001
.067
.067
.030
.037
.143
.143
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
HiEtttlltf
NEGLIGIBLE
NEGLIGIBLE
HiStiSitti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
HiStiMltf
NEGLIGIBLE
NEGLIGIBLE
ttf&usnti
NEGLIGIBLE
NEGLIGIBLE
Kstiiffli
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.012
.012
-------
Table 6-3-a. 1981 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIOKS PROJECTED TO 1981
RUN DATE'
MODIFIED
sec
403001000
403001010
403001011
403001020
403001021
403001030
403001031
403001040
403001041
403001050
403001051
403001060
403001061
403001070
403001071
403001500
403001501
403001510
403001511
TACRP
(SCC UNITS)
0.
0.
0.
0.
0.
0.
c.
0.
124000.
124000.
500000.
500000.
6932900.
6932900.
52050000.
1570000.
20800000.
20800000.
NOX
NEGLIGIBLE
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
EMISSIONS (MILLIONS OF TONS /
HC
.082
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
.002
.002
.004
.004
.050
.050
.026
.002
.010
.010
CO
NEGLIGIBLE
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PAGE 4
MAR 22*1977
YEAR!
PART
NEGLIGIBLE
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBi -
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-3-a. 1981 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
o
1
CO
-4
MODIFIED
sec
403001520
403001S21
403002000
403002010
403002011
403002020
403002021
403002030
403002031
403002040
403002041
403002050
403002051
403002060
403002061
403002070
403002071
TACRP
CSCC UNITS)
29680000.
29680000.
2920000.
2920000.
0.
0.
12660000.
12660000.
79800000.
79800000.
89700.
89700.
52000.
52000.
154000.
154000.
EMISS
NQX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
O.OCO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
IONS (MIL
HC
.014
.014
.212
.019
.019
0.000
0.000
.067
.067
.125
.125
.000
.000
.000
.000
.000
.000
PAGE 5
RUN DATE" MAR 22,1977
/ YEAR)
CO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
403003000
32360000.
NEGLIGIBLE
.1*2
NEGLIGIBLE NEGLIGIBLE
-------
Table 6-3-a. 1981 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON EVAPORATION
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
ON
1
tv
00
MODIFIED
sec
403003020
403999000
403999990
406001000
406001010
406001011
406001012 ;__
406001020
smm&
406001260
406001261
406001262
406001270
406001271
406001272
406002000
406002010
406002020
406002260
406002270
TACRP
CSCC UNITS)
32360000.
15000000.
15000000.
83302000.
7900000,
0.
7900000.
2106000.
2o5?888:
58500000.
0.
58500000.
14796000.
396000.
14400000.
113600000.
6300000.
7000000.
6300000.
94000000*
•r • w » ** » ' •» ** v«* ^9 • wt *f
EMISS
NOX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
O.OCO
NEGLIGIBLE
NEGLIGIBLE
HttttHtf
NEGLIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* V* A f TIT 4b
IONS (MIL
HC
.142
.069
.069
.090
.049
0.000
.049
.011
*&?, 9
• Oil
.024
0.000
.024
.006
.000
.006
.213
.003
.003
.001
.207
RUN DATE'
PAGE 6
MAR 22,1977
.IONS OF TONS / YEAR)
CO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
NEGLIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
LIGIBLE
JLIGIBL!
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES
to
vQ
HYDROCARBON EVAPORATION
TACR AND EHISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE
PAGE 1
MAR 23*1977
401001000
401001010
401001020
401002000
401002010
401002020
401002030
401002050
401002990
401999000
401999990
402001000
402001010
402001011
402001012
4-
*
TACRP
(SCC UNITS)
33470.
20053.
19905.
19905.
26907.
2430.
100730.
97631.
IH:
2061.
1069.
4-
*
4-
li?E:
1W?8:
:
32003.
32003.
76850.
76850.
76850.
76850.
61508.
61508.
45572.
45572.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGtlG. __
NEGLIGIBLE
NEGLIGIBLE
ittiiiitf
EtkiSBti
NEGLIGIBLE
NEGLIGIBLE
K
N
LIGIBL
LIGIBL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* .006
- .001
4- .004
- .000
+ .004
- .000
* .093
- .088
- ^001
* •!
*
i :8H
> .015
- ,014
+• .138
- .105
4- .131
- I008
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Hi
N(
itiii
(LI
JLI
NEGLIGIBLE
NEGLIGIBLE
BLI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
ILIGIBLI
ILIGIT
NEGLIGIBL
NEGLIGIBLE
NEGLIGIBLE
mimtt
mm
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
HYDPOCARBCN EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE*
MODIFIED
SCC
402001013 +
402001014 +
402001015 +
402001016 +
402001017 *
402001018 *
402001019 *
TACRP
(SCC UNITS)
2755.
2755,
2659.
2659.
4742.
4742.
2738.
1005.
300.
300.
NOX
NE6LIG
NEGLIG
KEGLIG
NEGLIG
NEGLIG
It
g
I
NEGLIG
NEGLIG
NEGLIG
EMISSIONS (MILLIONS OF TONS
HC CO
PAGE 2
MAR 22*1977
/ YEAR)
IBLE
ISLE
IBLE
IBLE
IBLE
BLE
BLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
HHttf"
m
NEG
NEG
NEG
NEG
NEG
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
HIS
m
NEG
BLI
.IGIBLE
.IGIBLE
.IGIBLE
402002000 +
402002010 +
402002011 4
402002012 *
402002013 +
402002014 +
402002015 *
402002016 «•
402002017 *
402002018 *
6626800.
6118500.
6826800.
6118500.
95131.
86370.
15270.
13850.
104240.
94540.
20213.
6113000.
855060.
48830.
4366.
50620
hEGLIGIBLI
HEGLIGIBLi
KEGLIGIBLf
NEGLIGIBLi
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIB
GIB
GIB
GIBL
GIBLE
* .260
- .146
N
N
GLIGIBLE
GLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
mm
- .029
j-GLIGIB
IGLIGIB
EGLIGIB
LIGISL
R
NEGLIGIBLE
N
Ni
N
Ni
•GLIG
•GLIG
BLi
BL1
•GLIGIBLE
•GLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Hf&iiiiti
NEGLIGIBLE
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
HYOPOCARBCN EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE'
MODIFIED
see
402002019
TACRP
(SCC UNITS)
235080.
213400.
EMISSIONS (MILLIONS OF TONS
NOX HC CO
PAGE 3
MAR 22*1977
/ YEAR)
NEGLIGIBLE
NEGLIGIBLE
.024
.021
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
i
(-0
402003000
402003010
402003011
402003013
402003014
402003017
402003019
*
+
51220.
51220.
51166.
51166.
177.
ti:
89.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mmm
NEGLIGIBLE
* .129
- .106
* .129
- .106
* .129
- .106
ooo
- .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
m
NEGL
im
GIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIi
NEGLIi
IIBLI
NEGLIGIBLE
NEGLIGIBLE
Hiitiiiiti
NEGLIGIBLE
NEGLIGIBLE
402004000
402004010
402004011
402004012
402004015
402004017
*
+
*
23595.
23595.
5863.
5863.
22786.
22786.
1782.
178«:
8.
iGLIGIBLE
ELIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* .027
- .021
NEGLIGIBLE * .027
NEGLIGIBLE - .021
* .017
- .013
* .021!
- .017
* .002
NEGLIGIBL!
NEGLIGIBLi
NEGLIGIBLI
NEGLlGlici
NEGLIGIBLI
NEGLJ
NEGL
N6GL1
GI8LE
GIBLE
GIBLE
NEGLIGIBLE
000
NEGLIGIBLE
Nlttifitti
NEGLIGIBLE
NEGLI
NEGLli
IIBLI
;IBLI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mtimtt
NEGLIGIBLE
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
i
w
IS)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE'
MODIFIED
SCC
402005000
402005010
402005011
402005012
402005013
402005016
402005017
TACRP
CSCC UNITS)
94088.
94088.
*
*
EMISSIONS (MILLIONS OF TONS
NQX HC CO
PAGE 4
HAR 22*1977
/ fEAR)
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mt
NEGL
NEGL
NEG
NEG
m
NEG
BLE
GIBLE
GIBLE
GIBLE
* .080
- .066
i :m
+ .051
- .052
+ .904
- .003
+ .000
GIBL
.
.000
NEGLIGIBLE
NEGLIGIBLE
Kfibffittf
Hist
NEGL
NEGL
NEGL
NEGL
Hiit
NEGL
G]
BLE
BLE
BLE
BLE
BLI
BL!
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
mtfc
NEGL
NEGL
NEGL
NEGL
... HiSt
BLE K£6t
G
Gl
GIB
[BLE
GIBLE
402006000
402006010
402006011
402006012
402006014
402006016
402006017
402006019
*
*
*
167120.
167120.
167120.
167120.
166720.
4B8J:
11481.
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Rfitl
NEGL
NEGL
N§GL
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
GIBLE
LE
* .362
- .273
<- .362
- .273
GIBLE
- .000
+ .000
- .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Hfgtiliiti
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL]
G
G
G
G
G
G
G
EG]
BLf
BL
BL
BL
BL
BL
BL
BLE
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
I
oo
HYDPOCARBCN EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE
PA6E 5
MAR 22,1977
MODIFIED TACRP
SCC
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
I
OJ
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE'
PAGE 6
MAR 22,1977
MODIFIED
sec
403001010
403001011
403001020
403001021
403001030
403001031
403001040
403001041
403001050
403001051
403001060
403001061
403001070
TACRP
(SCC UNITS)
4
1
4
4
4
4
4
4
4
4
4-
1
:
0.
0.
0.
0.
0.
0.
8:
0.
0.
8:
0.
0.
0.
0.
120420.
120420.
120420.
120420.
460980.
460980.
460980*
460980.
854460.
854460.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PART
4- O.OCO
- 0.000
4 0.000
- 0.000
4 0.000
- 0.000
t 8:888
4- 0.000
- 0.000
+ 9*888
- O.OCO
4 0.000
- 0.000
+ 0.000
- 0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
4 0.009
- 0.000
4 0.000
- 0.000
4 0.003
- 0.000
i 8:888
4 0.000
- 0.000
i 8:888
4 0.000
- 0.000
4- 0.000
- 0.000
4- .002
- .002
4- .002
- .002
4- .933
- .004
4 .003
- .004
4 .008
- .027
4- 0.000
- 0.000
4 0.000
- 0.000
+ 0.000
- 0.000
4 O.QQQ
— 0.000
4 0.000
- 0.000
i 8:888
4 0.000
- 0.000
* 8*888
- 0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
4- 0.000
- 0.000
4 0.000
- 0.000
4 0.000
- 0.000
i 8:888
4- 0. 000
- 0.000
i 8:888-
4- 0.000
- 0.000
* 8-888
- 0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
i
U)
(Jl
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
PAGE 7
RUN DATE- MAR 22.1977
MODIFIED
SCC
403001071
403001500
403001501
403001510
403001511
403001520
403001521
TACRP
(SCC UNITS)
mnm-.
1600000.
1570000.
18000000.
18000000.
18000000.
18000000.
NOX
EMISSIONS (MILLIONS OF TONS / YEAR)
HC CO PART
NEGLIGIBLE
NEGLIGIBLE
mmim
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.002
.002
+ .009
-- .009
+ .009
- .009
+ .009
- .009
NEGLIGIBLE
NEGLIGIBLE
m Nittigiiki
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
403002000
403002010
403002011
403002020
403002021
7001800.
2920000.
0.
0.
0.
0.
NEGLIGIBLE
NEGLIGIBLE
* 0.000
• 0.000
+ 0.000
- 0.000
* .137
- .128
* 0.000
• 0.000
+ 0.000
- 0.000
NEGLIGIBLE
NEGLIGIBLE
ggtisiiti •- -.m mwm
BL
+ 0.000
- 0.0"
00
* 0.000
- 0.000
NEGLIGIBLE
NEGLIGIBLE
+ 0.0(
- 0.0(
BLI
+ 0.000
- 0.000
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE-
PAGE 8
MAR 32,1977
MODIFIED
SCC
403002030 *
403002031 +
403002040 +
403002041 *
403002050 «•
403002051 *
403002060 *
403002061 +
403002070 *
403002071 «•
TACRP
CSCC UNITS)
7071100.
7071100.
7071100.
7071100.
18111000.
18111000.
11111888:
WM:
90448.
89700*
40311.
40311.
40311*
40311.
18:
120930.
120930.
NOX
NEGLIG
NEGL IG
NEGLIGIBLE
NEGLIGIBLE
EMISSIONS (MILLIONS Qf TONS / YEAR)
HC CO
NE
NE
iLIGIBLI
iLIGIBLI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
iHiilt!
NEGLIGIBLE
NEGLIGIBLE
.038
.049
.038
.049
.123
.117
.000
.000
.000
.000
.000
.000
+ .000
- .000
NEGL
NEGL
HBLI
1IBLI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
m mtimti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLI
NEGLIGIBLI
Ni
Ni
itiiiit!
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
403003000
403003020
814980.
814980.
NEGLIGIBLI
NEGLIGIBLI
* .025
- .077
NEGL
NEGL
mimm
mtmti
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
i
10
HYOROCARBCN EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN
EMISSIONS BILLIONS OF
18
NS
PAGE 9
MAR 22>1977
' r6ARWT
| 403999000
403999990
406001000
406001010
406001011
406001012
406001020
406001021
406001022
406001260
406001261
406001262
406001270
406001271
4- 18111000.
15000000.
i UU18M:
* 15906000.
— 14080000.
4- 10824000.
7900000.
+ 0,
+ 10824000.
7900000.
i 8I8U8:
4- 22574.
19999.
+• 830110.
830110.
4- 11595000.
11595000.
* 0.
* 11595000!
11595000.
+ 835160.
835160.
* 91706.
91706.
NEGLIGIBLE
NEGLIGIBLE
UttiSHkf
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* 0.000
- 0.000
NEGLIGIBLE
NEGLIGIBLE
BiftigUti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* o.oco
- 0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
»
•»
+
*
*
I
*
*
4-
:
4-
+
4-
4-
.084
.069
•.m
•152
.056
.067
.049
0.000
!o49
:m
.000
.000
.005
.009
.134
.024
0.000
0.000
.134
.024
.024
.006
.001
.000
NEGLIGIBLE
NEGLIGIBLE
SiibfSiit!
KIEHUli:!
NEGLIGIBLE
NEGLIGIBLE
+ 0.000
- O.QOO
NEGLIGIBLE
NEGLIGIBLE
* Miitiifiti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
4- 0.000
- 0,000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Biitifilti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
• 0.000
NEGLIGIBLE
NEGLIGIBLE
Hf&iifttf
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
4- 0.000
NEGL!G?BLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
-------
Table 6-3-b. 1981 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVAPORATION
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE'
MODIFIED
SCC
406001372
TACRP
(SCC UNITS)
830110.
830110.
NE
NE
NOX
EMISSIONS (MILLIONS OF TONS
HC CO
BLI
PAGE 10
MAR 22,1977
/ YEAR)
PART
.E NEGLIGIBLI
.6 NEGLIGIBLI
406002000
406002010
406002020
406002260
406002270
36896000.
15046000.
10475000.
7000000.
24016000.
6300000.
9899500.
9899500.
•6LIGIBU
IGLIGIBLI
(lit
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
mt
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
+ .094
- .102
* .013
- .003
+ .008
- .003
* .008
- .001
«• .092
- .102
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGL
GIBLI
GIBL!
GIBLI
GIBL!
GIBLI
00
-------
marginally profitable to produce; consequently, older plants are not being
replaced as they enter obsolescence. On the other hand, trichloroethylene
is very photochemically reactive and has been banned from uncontrolled use
in many areas. For these reasons, perchloroethylene is expected to emerge
as the prominent solvent in the next decade.
6.3.2 Surface Coating
Hydrocarbon emissions from paint and other surface coatings
occur during application and result primarily from the evaporation of the
thinning agent (solvent). A second source of HC emissions is the film
formers called resins. The thinner is in the coating to allow application in
the liquid state. Although solid (powder) surface coating has been applied
and baked with some success in a few limited applications, it is not expected
to serve as a significant substitute for liquid coatings in the near future.
The total quantity of surface coatings used nationwide in 1974
was essentially divided equally between industrial applications and trade or
retail sales. Since the trade-sales surface coatings are almost exclusively
area source emissions, they were not included in this study.
For a better insight into the source of the surface coating
emissions, the SCC numbers were subdivided into types of products such as
motor vehicles, appliances, and machinery. In 1972, the sheet, strip, and
coil industry and the paper industry each represented the source of about a
billion pounds of HC discharged to the atmosphere. Motor vehicles and
fabric treatment plants each contributed about 0.4-billion pounds. All other
activities combined contributed less than 10 percent of the emissions from
surface coatings. The emissions from industrial surface coatings come from
approximately 10, 000 point sources which are widespread geographically.
At the start of this study, no activity had been assigned by the
NEDS to the SCC numbers 402002xx nor 402007xx. For this study, these
numbers were respectively assigned to paper products and fabric treatment.
In the meantime (December 1975), the SCC category number 402007xx was
6-39
-------
assigned by EPA to adhesives. This represents the only inconsistency
between the NEDS numbering system and the modified SCC system described
in Table 6-1.
A more detailed description of the industrial surface coating
industry is found in Ref. 6-3.
6.3.3 Petroleum Product Storage
Although many types of storage facilities have been developed
to retard the loss of petroleum products to the atmosphere, three types store
significant quantities of product and were consequently considered in this
study: (1) fixed-roof tank, (2) floating-roof tank, and (3) variable vapor-
space tank.
According to Ref. 6-1, five products are significant contribu-
tors (>500 tons per year) to atmospheric emissions: (1) gasoline, (Z) crude
oil, (3) jet fuel (JP-4), (4) kerosene, and (5) distillate fuel.
Although all five fluids contributed to emissions from fixed-
roof and floating-roof tanks, only gasoline was found to be a significant
emitter of vapor from the variable vapor-space tank. Reference 6-4 des-
cribes the causes of and influencing factors on evaporation from petroleum
product storage tanks. Although initial motives for developing the floating-
' i ,
roof and variable vapor-space tanks were essentially economic through con-
servation of the products, pollution alleviation characteristics are inherent.
Recent improvements have been directed toward the pollution control aspects
of these facilities.
The American 1 ecroleum Institute (API) coordinated efforts as
early as 1952 to correlate evaporation losses to tank and fluid variables.
Empirically derived equations which relate the evaporative losses to the
independent variables for the fixed-roof, floating-roof,) and variable vapor-
space tanks are respectively described in Refs. 6-5 through 6-7.
For purposes of emissions data, storage, and handling, as in
Refs. 6-1 and 6-2, emissions from the storage tanks are calculated from an
equation which is a function only of two variables, the emission factor and
6-40
-------
the charge rate as defined in Table 6-1. Reference 6-8 lists the EPA-
recommended emission factors. To capitalize on the API analysis, it was
necessary to convert the API empirically derived equations into the two-
variable equation. This was accomplished by rearranging the API equations
as necessary to include the Table 6-1 charge rate as one of the variables.
For example, the API breathing loss equation is a function of tank diameter
to the 1. 73 power and the average vapor space depth to the 0.51 power, which
in turn are related to tank capacity. Through proper substitution, the tank
capacity (which is the Table 6--1 charge rate) can appear in the API equation.
The product of all other terms in the API equation corresponds to the emis-
sion factors. If nominal values are assigned to these terms, an emission
factor can be calculated which corresponds to the nominal conditions. Sec-
tion 6. 5 describes the development of the modified API equation for the
subject evaporation losses.
6.3.4 Marketing and Transportation of Petroleum
Products
6.3.4. 1 Point Source Emissions
Significant loss of HC vapors to the atmosphere is encountered
in two of the operations involved in marketing and transportation of petroleum
products. These two operations are (1) loading railraod tank cars and tank
trucks and (2) loading and unloading of marine vessels.
6.3.4.2 Area Source Emissions
Although large quantities of HC emissions are attributed to
unloading tank trucks and filling motor vehicles at retail service stations,
none dispense sufficient quantities to qualify as a point source. To qualify
as a point source emission (>100 tons/year) with 1975 emission factors
(~ 10 lb/1000 gal transferred), filling stations would have to pump approxi-
mately 20-million gal/year. Although NEDS lists 45 stations under the broad
heading of vapor displacement sources (4-06-004-01), the composite total
annual charge rate from these sources is only 4. 593-million gal. Also, a
6-4!
-------
personal communication with a representative of Standard Oil Company,
El Segundo, California, indicated that the rates of their higher filling stations
are 160, 000-gal/month (~ 2-million gal,/year). It was concluded that no
filling stations qualify as point sources. Table 6-4 lists the HC emission
losses at service stations.
6.4 EMISSIONS ANALYSIS
This section describes certain of the hypotheses, assumptions,
and observations that were made in the course of establishing the data base
on which the charge rate and emission rate calculations are based.
6.4.1 Cleaning Solvents
The change in charge rate (tons of clothing per year) for the
dry cleaning processes reflects two things:
a. The phasing out of petroleum solvent is assumed to be com-
pleted in a 10-year period starting in 1972. The synthetic
solvent is expected to fill this void.
b. The expected annual population growth rate is 0.9 percent
from 1972 to 1980.
The degreasing sector of cleaning solvent usage is also under
scrutiny, and the distribution of usage rates among the four major solvents
is expected to be realigned. The Stoddard solvent is expected to disappear
from the market because petroleum companies are not replacing antiquated
facilities for reasons of poor profit forecasts. Also, trichloroethane and
trichloroethylene uses are expected to be restricted to operations where
emissions are highly controlled. These solvents are highly photochemically
reactive. Perchloroethylene is expected to make up the deficit created by
the declining use of these two solvents.
The general industrial usage rate of solvents is also expected
to increase by 3 percent per year, which is the typical growth rate of manu-
factured goods over the last 10 years. This growth is also factored into the
perchloroethylene and miscellaneous solvent usage rate change.
6-42
-------
Table 6-4. EVAPORATION FROM SERVICE STATIONS: GASOLINE
TRANSFERRED CHARGE RATES AND EMISSIONS
MSCC
••••••••MtfWBIIIH^^^
A406004011
A406004012
A406004013
Total Sales
A406004020'
Total
Gasoline Pumped, HC Emissions,
1000 gal/yr million tons/yr
1976 1981 19761981
^^^^i^HH^^WWB^IHHHHHHIIIlllllllllH
5.69E7 5.69E7 0.138 0.023
3.56E7 3. 56E7 0.094 0.016
9. 14E6 9. 14E6 0.040 0.040
1.016E8 1.016E8 0.272 0.079
1.016E8 1;. 016E8 0. 006 0.005
0.278 0.084
Activity
Vapor displacement
during fill
Vapor displacement
during fill
Vapor displacement
during fill
Spillage
A406003010
A406003040
5. 772E7 -0-
0. 332
A406003020 3. 902E6 1.040E7 0.014
A406003030 1.532E7 4. 080E7 0.006
2.401E7 5. 040E7 -0-
Total Storage 1. 016E8 1.016E8 0.352
-0-
0.038
0.016
-0-
0.054
Filling underground
storage
Filling underground
storage
Filling underground
storage
Filling underground
storage
Total Service
Station Activity
0.630 0.138
6-43
-------
6.4.2 Surface Coating
Except for motor vehicles, the 1972 data in Ref. 6-3 were
used to establish the baseline values for charge rates (quantity of surface
coating used) and the emission factors (percent of surface coating comprised
by solvent) from which projections were made.
Although the data published in Ref. 6-9 are based on a sample
survey and the actual usage numbers may be somewhat different from the
published numbers, the percentage changes per year are considered accurate.
For this reason, the Ref. 6-9 data were used as a basis for establishing the
slope and slope uncertainty of the time-usage curve of the respective indus-
trial surface coating applications.
Automobile, truck, and bus production data extracted from
Refs. 6-10 and 6-11 were the basis for estimating vehicle production and
paint usage rates.
Reference 6-12 listed 26 Ib of paint and other surface coating
as being used on the Plymouth Fury, which is considered an average pas-
senger car. Bus and truck usages were estimated on the basis of their
relative surface area to the passenger car area.
6.4.3 Petroleum Product Storage
The API equations are intended for calculating the evaporative
emissions under a particular set of storage conditions. At this writing, an
inventory of facilities grouped according to the various influencing param-
eters is not available. Hence, an emission factor was determined for each
tank type and stored fluid on the basis of a set of conditions that are con-
sidered typical. For example, for gasoline stored in a fixed-roof tank, the
breathing losses might be calculated by means of the following typical
parameters:
Storage Temperature 63 °F
Average Daily Temperature Excursion 15°F
True Vapor Pressure 5.8 psia
Density 6.21b/gal
6-44
-------
Paint Factor 1.14
Tank Depth 48 ft
Tank Diamete r 110 "ft
Factor for Liquid Stored (Gasoline) 0.024
Although the above variables may be typical (average) for fixed-
roof gasoline storage, the real nationwide emissions as calculated by sum-
ming the emissions from individual tanks using the API equations do not
equal the emissions calculated from the EPA equations using an emission
factor based on the above typical values. The exact error is dependent on
the distribution and range of variation of the independent variables. This
error also results from the nonlinear effects of certain independent variables.
Section 6. 6 shows the error due to distribution of tank geom-
etry in calculated emissions using the EPA equation and a specific distribu-
tion and range of variation of tank diameter and height for fixed-roof gasoline
tanks. Although the distribution of the independent variables used in Section
6.6 is highly unusual, it is intended to show the maximum error for the one
emission factor concept. In addition to this error, an error in emission
calculated for a group of tanks results of the true average of a particular
independent variable was different from the assumed value. Section 6. 7
shows the effect of using an emission factor based on one set of conditions
when another set prevails.
The uncertainty of the emission factor was established either
as (1) 10 percent of the nominal level, or (2) the difference between the
emission factor listed in Ref. 6-8 and the one calculated from typical vari-
ables using the equation developed in Section 6. 5, whichever -was greater.
This represents an overall uncertainty, i.e., the composite effect of the
uncertainty of the individual parameters is reflected in the emission factor
uncertainty.
According to Ref. 6-13, the stocks of gasoline at the end of
the year have been essentially the same for the past six years. Since the
total storage capacity is a linear function of the average stock on hand (which
is based on politically decided reserves), no change in total gasoline capacity
6-45
-------
is forecast, at least through 1980. Based on a private communication with
Standard Oil of California personnel, it appears that the use of fixed-roof
storage tanks for gasoline may disappear as early as 1980. It is estimated
that approximately 20 percent of the storage loss will be made up by floating-
roof tanks and the remainder by variable vapor-space systems. The distribu-
tion of gasoline storage capacity among the three types of tanks is necessary
for breathing loss calculations.
Although the number of motor vehicles (as well as total vehicle
miles traveled) is expected to increase well beyond 1980, the estimated
gasoline demand for highway usage is expected to remain near 100-billion
gal/year. The primary reason that consumption is likely to remain
constant while the car population increases is the improved mileage of cur-
rent and future autos. Therefore, in estimating the working vapor losses of
gasoline, the total throughput is considered constant with 80 percent of fixed-
roof throughput being replaced by floating-roof facilities and 20 percent by
variable vapor-space systems.
The floating-roof tanks will take over the majority of the gaso-
line throughput formerly handled by the fixed-roof tanks because of their
superior control of HO emissions during filling and while empty. The vari-
able vapor-space system breathing losses during static storage are near zero
and consequently will represent about 60 percent of the gasoline storage
capacity by 1981.
6.4.4 Marketing and Transportation of Petroleum
Products
Point source emissions in 1976 from marketing and transporta-
tion of petroleum products are principally from operations involving the
splash loading of gasoline on tank trucks (0.14-million tons/year of HC and
the unloading of crude from marine vessels (0. 09-million tons/year of HC).
Emissions from these sources are expected to be reduced to 0. 05-million
tons/year and increased to 0. 2-million tons/year of HC vapors, respectively,
in 1981. Both activities will have lower emission factors in 1981, primarily
6-46
-------
through the implementation of vapor control techniques, such as use of the
submerged fill pipe. For example, for gasoline loading, the emission factor
with a submerged fill pipe is about one third as great as with the splash fill.
Although the vapor recovery system (either balance or vacuum assist) poten-
tially can capture and retain between 90 and 100 percent of the vapors formed,
few systems have been installed where the transfer is potentially from any
one of several sources or to one of several receptacle tanks. This is in
contrast to the system used in filling underground storage tanks at filling
stations which cycles the vapors from the tank to the truck through the annu-
lar coax line, which is integrated with the fill line.
Since no distinction was made between the petroleum move-
ment by tank trucks and railroad tank cars in the NEDS SCC system, The
Aerospace Corporation MSCC was adapted with a "1" in the 10th digit for
railroad tank cars and a "2" for tank trucks (motorized vehicles for highway
usage).
According to Ref. 6-14, the movement of gasoline by rail is
on the decline. Should the trend continue, that form of gasoline movement
may disappear by the early 1980s. That trend, coupled with.some imple-
mentation of emission control measures, indicates that emissions from the
loading of gasoline onto railroad cars (both splash and submerged) may be
near zero by 1981.
Although the movement of crude by rail has experienced many
ups and downs in the last decade, the trend seems to reflect a constant usage
rate. The splash loading technique is expected to be replaced by submerged
loading of crude.
The total petroleum loading movement (both gasoline and
crude) was apportioned between splash and submerged according to the split
that was reflected in the NEDS data.
6.5 EMISSION FACTORS DERIVED FROM
API ANALYSIS
In order that emission factors might be derived (or confirmed)
for evaporative losses from petroleum storage tanks, empirically derived
6-47
-------
equations from the API analysis described in Refs. 6-5 through 6-7 are
utilized. Values for the terms can be found in the respective references
when emissions are to be determined for specific conditions.
6.5.1 Fixed-Roof Breathing Losses
The API equation for fixed-roof breathing losses is taken
from Ref. 6-5:
Tv- / P \°-68 1.73 0.51AT0.50 ,
Ly- Cll4.7-P/ D H AT F (6-1)
where:
L = breathing loss (bbl/year)
C = adjustment factor for small tanks (C = 100 for D > 30 ft)
P = true vapor pressure based on average bulk temperature
(psia)
D = tank diameter (ft)
H = average vapor space depth (ft)
AT = average daily ambient temperature excursion (maximum.
minus minimum )(°F)
F_ = paint factor (no dimensions): 1.00 for all-white tank
^ with paint in good condition.
The following definitions apply:
., , ^Z 4V ., „
V = -— d or D = — j- (6-2)
D
D0.27
(6-2a)
1.73 _ 4V
~ j^O.27
irdD
6-48
-------
Q= 7.48 xlO"3V (6-3)
E = L X 42 (gal/bbl) X p (6-4)
and the following assumption was made:
H = 0.5 d (6-5)
average
where
V = tank volume capacity (cu ft)
d = equivalent height of cylindrical volume (ft)
Q = tank volume capacity (1000 gal)(SCC units)
E = evaporative loss by breathing (Ib/year)
p = liquid density at average bulk temperature (Ib/gal)
Substituting definitions of Eqs. (6-2a), (6-3), and (6-4) and the assumption,
Eq. (6-5), into the API equation, Eq. (6-1), for breathing losses yields:
E =
5020.33PC___
P \°-68 V^ F<
Q (6-6)
where the product of terms in the brackets represents the emission factor
in (lb/yr)/1000-gal capacity:
E = EF X Q (6-7)
which is the EPA equation form.
6-49
-------
6.5.2 Fixed-Roof Working Losses
The API equation for fixed-roof working losses is also taken
from Ref. 6-5:
F = CPVKt (6-8)
where
C = factor dependent on liquid stored
P = true vapor pressure based on average bulk
temperature (psia)
V = annual throughput (bbl/year)
K. = turnover factor (dimensionless)
F = working loss (bbl/year)
The following definitions apply:
(6.9)
E = F X 42 X p (6-10)
where
E = working loss (Ib/year)
Q = annual throughput (1000 gal/year)
p = density of liquid at average bulk temperature (Ib/gal)
Substituting Eqs. (6-9) and (6-10) into the API equation,
Eq. (6-8), for working losses yields:
E = [lOOO CpP Kt]Q (6-11)
where the product of terms in the brackets represents the emission factor in
(Ib/year)/1000-gal throughput.
6-50
-------
6.5.3 Standing Losses from Floating-Roof Tanks
The API equation for standing losses from floating - roof tanks
is taken from Ref. 6-6:
1' 5 '
L = K.K K K D' ( ,A „) (6-12)
y t s c p 1 14. 7 - PI v '
where
L = standing loss (bbl/year)
K. = tank-type factor
L
K = seal factor
s
K = fluid factor
K = paint factor
D = tank diameter (ft) . r
(for D > 150, replace D ' with 12. 25D)
w = average wind velocity (mph)
The following definitions apply:
(6-13)
(6-14)
42XpxL (6-15)
where
V = volumetric capacity (cu ft)
Q = volumetric capacity (1000/gal)
d = equivalent cylindrical depth of the tank (ft)
p = liquid density (Ib/gal) at average bulk temperature
6-51
-------
Substituting Eqs. (6-13) through (6-15) into the API equation,
Eq. (6-12), yields:
7149 pKJC K K
v t s c p
/ WP '
/FT A \ 14. 7 - P
\0.7
' ir a f* r\ I ITT t->
E =
Q (6-16)
where the product of terms in the brackets represents the emission factor in
(lb/year)/1000-gal capacity.
6.5.4 Working Losses from Floating-Roof Tanks
API developed a clingage factor, c, which reflects the barrels
of liquid per 1000 ft which cling to the wall and are exposed to the atmosphere
to evaporate during a withdrawal process, when the floating roof slides down
with the liquid surface.
This results in the following API emissions equation (Ref. 6-6):
E = (22.46 cp)Q (6-17)
where
c = clingage factor (bbl/1000 sq ft of wetted wall surface)
p = liquid density at average bulk temperature (Ib/gal)
Q = petroleum product withdrawn (1000 gal/year)
E = emissions (Ib/year)
6.5.5 Working Losses from Variable Vapor-Space
Tank Systems
«M—^^^_«wm^w«^B««^«^_ /
Except for unplanned leakage, no vapor is lost to the atmo-
sphere from variable vapor-space systems until vapor volume tends to exceed
the expansion capacity of the system; then it behaves essentially like a fixed-
roof storage facility. This is the basis for the equation which determines
the emission from the variable vapor-space system. The only difference
from the fixedToof working losses is that the throughput term Q of Eq. (6-11)
6-52
-------
becomes only that throughput which exceeds the available expansion remaining
at the start of the fill operation.
Let Q in Eq. (6-11) be replaced by AQ where AQ is defined as
the volume of liquid transferred after the vapor expansion system reached
its limit. Another way to express AQ is the difference between the total
liquid transferred and the expansion capability remaining at the start of
the operation.
To further simplify the referenced equation, three assumptions
are made that represent the average system and its operation:
a. Available expansion volume at the start of the operation is
one-fourth the total expansion capability of the system.
b. Each transfer involves a complete turnover; i.e., the quantity
transferred equals the capacity of the tank.
c. Expansion capacity equals three-fourths of total liquid capacity
of the tank.
The following equation represents the emissions expelled during
filling operations of the variable vapor space:
E = (810 CpP)Q (6-18)
where
E = emissions (Ib/yr)
C = factor dependent on liquid stored
p = density of liquid at average bulk temperature (Ib/gal)
P = true vapor pressure based on average bulk temperature
(psia)
Q = annual throughput (1000 gal/yr)
Reference 6-7 describes the variable vapor space system in greater detail.
Since the expansion capacity is seldom exceeded while the
system is in a standby mode, the breathing loss is considered negligible.
6-53
-------
6.6 COMPARISON OF API AND EPA EMISSION
EQUATIONS
Unless an extensive expansion of the SCC system is effected,
one emission factor (EF) value must be used for a broad range of variables.
Use of the EPA equation, which is a simplified version of the API equation,
introduces an error in the calculated emission. The limits of this error can
be determined from a comparison of the breathing losses of a group of fixed-
roof gasoline storage tanks calculated from the API and EPA equations,
respectively. The population of tanks is made up of two subgroups, one with
diameters that are 0.90 and the other 1 . 1 of the average diameter. Both
subgroups have an equal number n in the set. Although this is a highly
unusual distribution, it was selected for the comparison to show the upper
limit of the error. All other variables are the same for the entire group,
A similar comparison is made for varying depth.
From Section 6.5. i, the API equations yield the following
emissions in terms of D (average tank diameter) and Q, the capacity of the
tank with an average diameter D:
'
j7P_ J ' H°'51 v/AT Fp X 1(0. 9D)1 ' 73 + (1 . ID)1' 73j
1 73
Factoring D and substituting the following
Q = 7.481 X 10"3 V
Xd)
= 7.481 x 10'3 - x d) (6-20)
or rearranging
r»i-73_ 4Q
7.481 x 10 dD TT
.,
(6-
6-54
-------
and letting
H = 0.5 d (6-22)
and
5020.3 F pc / \0>68
d0.49D0P27ll4.7-P/
then, it is found that
(0.9'-
E = n XEF xQ (0.9"73 + l.l1'73
/ (6-24)
E = 2.01 Xn X EF
The EPA emission equation is simply the product of an emis-
sion factor EF and the tank capacity. Although the emissions can be calcu-
lated for each tank using its particular capacity, no provisions exist for
adjusting the emission factor from tank,to tank even though it is a function of
tank diameter. Instead the emissions from a group of tanks are calculated
from some representative emission factor based on a typical set of indepen-
dent variables, such as an average diameter of the group.
The EPA emission equation yields the following emissions for
a group of 2n tanks, using an emission factor EF based on the average
diameter D:
= nXEFX
(6-25)
l.l2)
= n x EF X Q X 2. 02
n XEF xQ (0.92 + l.l2)
6-55
-------
The ratio of true emissions to those calculated from an emission factor based
on an average diameter is 2.01/2.02 or 0.995, i.e., about a 0.5 percent
error.
If the diameters of the two tank groups are 0. 5 and 1. 5 of the
average diameter, the true to indicated emission is 2. 318/2. 506 or 0.927,
i.e., about a 7. 3 percent error.
A similar comparison is made for tank depth:
(0.9d)'
x nx °-9 Q +- - X n 1.1 Q
= 1.997 X EF X n X Q
The EPA equations then yield the following:
E = EF X QX n X (0.90 + 1.10)
(6-27)
= 2. 00 X EF X Q X n
The ratio of true to indicated emissions is 1.997/2.000 or 0.999, i.e., about
a +0.1 percent error.
For the 0.5 and 1. 5 depth ratios, the true to indicated emis-
sion ratio is 1.932/2.000 or 0.^66, i.e., about a +3.4 percent error.
6.7 ERROR OF EMISSION FACTORS BASED ON
API ANALYSIS
The API equations for vapor loss from petroleum tanks
express the emissions as functions of several independent variables to a
variety of powers. These equations are given in Section 6. 5.
The effect of calculating the emissions from a system of tanks
while using a value different from the effective or true value of certain vari-
ables is presented in Tables 6-5 through 6-8 and in Figures 6-1 through 6-4
6-56
-------
for fixed-roof breathing losses. The API equation for fixed-roof breathing
losses is as follows:
Ly= C(14.7 . pl D*"J-HW-J1 ATu'3Fp (6-28)
The symbols and terms used in Eq. (6-28) and in Tables 6-5
through 6-8 are defined in Section 6.5.
6.8 REFERENCES
6-1- S. Cheung, et al., "Computer Analysis of NEDS Point Source
Emission Data, "Contractor Magnetic Tape No. 74362, The
Aerospace Corporation, El Segundo, California (Log date,
November 10, 1975).
6-2. NEDS "Nationwide Emissions Report, " Computer printout of
National Emissions Data System, U.S. Environmental Protec-
tion Agency, Research Triangle Park, North Carolina
(September 3, 1975)(effective August 25, 1975).
6-3. Prioritization of Air Pollution from Industrial Surface Coating
Operations, EPA-650/2-75-019-a, U.S. Environmental Pro-
tection Agency, Research Triangle Park, North Carolina
(February 1975).
6-4. "Evaporation Loss in the Petroleum Industry - Causes and
Control, " API Bulletin No. 2513, American Petroleum Insti-
tute, Washington, D.C. (February 1959).
6-5. "Evaporation Loss from Fixed-Roof Tanks, " API Bulletin
No. 2518, American Petroleum Institute, Washington, D.C.
(June 1962).
6-6. "Evaporation Loss from Floating-Roof Tanks, " API Bulletin
No. 2517, American Petroleum Institute, Washington, D.C.
(February 1962).
6-7. "Use of Variable-Vapor Space Systems to Reduce Evaporation
Loss, " API Bulletin No. 2520, American Petroleum Institute,
Washington, D.C. (September 1964).
6-8. Compilation of Air Pollutant Emission Factors, 2nd ed., AP-42,
with Supplements 1 through 5, U. S. Environmental Protection
Agency, Research Triangle Park, North Carolina (April 1973).
6-57
-------
6-9. Sales Survey for the Year 1974, National Paint and Coatings
Association (July 1975).
6-10. Ward's Automotive Yearbook (1975).
6-11. Motor Truck Facts, Motor Vehicle Manufacturer's Associa-
tion (1974).
6-12. Technological Improvements to Automobile Fuel Consumption,
TSC-OST-74-39, Vol. II-A, U.S. Department of Transporta-
tion, Washington, D.C., prepared by the Southwest Research
Institute (December 1974).
6-13. Annual Statistical Review, Petroleum Industry Statistics 1965-
1974, American Petroleum Institute, Washington, D. C. ~
(May 1975).
6-14. Energy Statistics. DOT-TSC-OST-74-12, U.S. Department of
Transportation, Washington, D. C. (August 1974).
6-58
-------
Table 6-5. VAPOR PRESSURE EFFECTS ON FIXED-ROOF
BREATHING LOSSES
LTI
vO
Vapor
Pressure
P.a
0.5
1.0
1.5
2.0
3.0
4.0 —
6.0
8.0
/ , \0.68
r/14.7 - P)
0.103
0.169
0.228
0.285
0.396
~~- ~ 0.512" ~
0.777
1.128
Ratio of Emissions Ej/Eg
(Case of Interest -f Baseline Case)
p =1
*B l
0.609
1.000
1.349
1.686
PB=2
0.593
0.800
1.000
1.389
1.796
PB-4
0.557
0.773
1.000
1.504
2. 203
PB = 6
0.510
0.659
1.000
1.452
Terms subscripted with "i" correspond to case of interest;
terms subscripted with "B" correspond to baseline case.
-------
Table 6-6. DIAMETER EFFECTS ON FIXED-ROOF BREATHING LOSSES
Diameter
D.a
6
8
10
11
12
14
20
30
40
60
80
110
140
170
210
250
C
0.30
0.40
0.50
0.55
0.60
0.70
0.88
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
D1.73
22.19
36.50
53.70
63.33
73.62
96.12
178.15
359. 27
590.97
1191-80
1960.40
3401.02
5161.80
7222.32
10409.73
14074.60
CXD1'73
6.66
14.60
26.85
34.83
44.17
67.28
156.77
359.27
590.97
1191.80
1960.40
3401.02
5162.00
7222.00
10410.00
14075.00
Ratio of Emissions E^/Eg
(Case of Interest 4- Baseline Case)
DB=10
0.248
0.544
1.000
1.297
1.645
2.506
5.839
DB=30
0.075
0.097
0.123
0.187
0.436
1.000
1.645
DB = 60
0.301
0.496
1.000
1.645
2.854
DB=110
0.350
0.576
1.000
1.518
2.123
DB = 170
0.471
0.715
1.000
1.441
1.949
lTerms subscripted with "i" correspond to case of interest;
terms subscripted with "B" correspond to baseline cases.
-------
Table 6-7. ULLAGE DEPTH EFFECTS ON FIXED-ROOF BREATHING LOSSES
Ullage
Depth
H.a
2
3
5
7
10
15
20
25
30
35
H0.51
1.424
1.751
2.272
2.698
3.236
3.979
4.608
5.164
5.667
6.130
Ratio of Emissions E-/Eg
(Case of Interest -s- Baseline Case)
HB = 5
0.627
0.771
1.000
1. 188
1.424
-
HB = 10
0.702
0.834
1.000
1.230
1.424
HB = 20
0. 707
0.863
1.000
1.121
1.230
HB=25
0.771
0.892
1.000
1.097
1.187
Terms subscripted with "i" correspond to case of interest;
terms subscripted with "B" correspond to baseline cases.
-------
Table 6-8. TEMPERATURE EXCURSION EFFECTS ON FIXED-ROOF BREATHING LOSSES
Temperature
Excursion
AT.a
2
5
9
15
22
30
40
50
/?
1.414
2.236
3.000
3.873
4.690
5.477
6-325
Ratio of Emissions Ej/Eg
(Case ol Interest -s- Baseline Case)
ATB = 5
0.632
1.000
1.342
1.732
ATB = 9
0.745
1.000
1.291
1.563
ATB = 15
0.775
1.000
1.211
1.414
ATB = 22
0.826
1.000
1.168
1.349
AT_, = 30
o
0.856
1.000
1.155
1.291
lTerms subscripted with "i" correspond to case of interest;
terms subscripted with "B" correspond to baseline cases.
-------
BASELINE PRESSURE
00
•I-
UO
LU
to
<
o
t/i
O
CO
l/l
O
O
<
o:
1.6
1.5:
1.4
1.3
1.2
1.1
1.0
0.9
0.8
0.7
0.6
0.5
^DISTILLATE
KEROSENE
AP-42 BASELINE
CRUDE GASOLINE
6 psi
0
3 4 5
TRUE VAPOR PRESSURE, psia
Figure 6-1. Effects of vapor pressure on fixed-roof breathing losses
-------
00
-------
1.5
ON
I
Os
Ul
UJ -I A
CO 1. **
03
i 1.3
i—
CO
I 1-2
I 1.1
o
to 1.0
o
z? 0.9
o
£0.8
I 0.7
o
2 0.6
06
0.5
BASELINE DEPTH
5tt
10ft
JP-4
KEROSENE
CRUDE
DISTILLATE
AP-42 ULLAGE DEPTH
= 50% OF TANK HEIGHT
1 \
GASOLINE
1,
0123456 7
10
15 20
ULLAGE DEPTH, ft
25
30
25ft
J
35
Figure 6-3. Effects of ullage depth on fixed-roof breathing losses
-------
BASELINE TEMPERATURE EXCURSION
5°
45
50
DAILY TEMPERATURE EXCURSION. F
Figure 6-4. Effects of daily temperature excursion on fixed-roof breathing losses
-------
SECTION 7
PRIMARY METALS
7.1 IN TRODU C TION
The metallurgical industries are considered to be part of the
industrial processes category of the National Emissions Data System (NEDS)
source classification coding system. The primary metals industry uses ore
for its production, while the secondary metals industry primarily uses scrap
metal. The Source Classification Code (SCC) number which represents the
primary metals industry is 3-03-xxx-xx.
Table 7-1 describes the metallurgical processes studied and
gives the corresponding modified SCC (MSCC) numbers and annual charge
(or usage) rate units. The study list was formed from those primary metal
processes which had one or more of the four pollutants of interest with an
emission rate greater than 500 tons/year according to Ref. 7-1. The
four pollutants of interest in the study are oxides of nitrogen (NO ), hydro-
j£
carbon (HC), carbon monoxide (CO), and particulate matter (PART). Ex-
cept for a few isolated cases, the only significant quantities of emissions from
the primary metals industry are CO and PART.
7.2 SUMMARY
The annual CO emissions from the primary metals industries
in 1976 were 11-1/3 million tons compared to about 37-2/3 million tons from
all stationary point sources. These are principally from blast furnaces
(6 X 10 tons) and basic oxygen furnaces (4 X 10 tons) used, respectively, for
7-1
-------
pig iron and steel production. In 1981, the CO from, primary metals is
expected to be reduced to 6-2/3 million tons through the implementation of
improved control techniques.
The PART emissions from the primary metals industry in
1976 were nearly 3.6-million tons. The estimated nationwide total PART
emissions in 1975 from stationary point sources were 13. 5-million tons.
The estimated 1981 PART emission rate from primary metals
is 0.86-million tons. Most of this reduction is attributed to the improved
control techniques which are forecast for copper smelters.
A detailed list of emissions and charge rate data is listed
in Tables 7-2 and 7-3 for the years 1976 and 1981, respectively.
7.3 PROCESSES EVALUATED
A total of 72 primary metal processes is listed in the NEDS
data bank (Ref. 7-1). Fifty-two were found to show 500 or more tons of at
least one of the four emissions of interest. Although the year of effectivity
was between 1971 and 1973, these 52 categories were considered potential
contributors to air pollution in 1976 and 1981 and therefore served as the
basis for selection of the primary metal operations to be studied. A brief
description of the most significant emitters of CO and PART follows.
7.3.1 Blast Furnace and Related Operations
Blast furnaces are used to produce pig iron by packing coke,
iron ore, and limestone into brick-lined chamber. Much of the carbon is
reacted to CO., (10 percent of blast furnace gas), but substantial quantities of
CO (27 percent) are generated. From 1300 to 1800 Ib of CO are generated
for each ton of pig iron produced. Much of the CO produced is collected,
cleaned of PART, and burned as a secondary fuel in the steel mill. Although
the blast furnace gas (mostly CO) has a heat content of about 100 Btu/cu ft,
its use as a fuel is secondary, in this-study, to the emission control aspects
of the burning.
(Continued on page 7-22)
7-2
-------
Table 7-1. DEFINITION OF PRIMARY METALS PROCESSES
MSCC
303001000
303001010
303001020
303001030
303001040
303001050
303001990
303002000
303002010
303003000
303003010
303003020
303003030
303003040
303003050
303003990
303004000
303004010
303005000
303005020
303005030
303005040
303005050
303005060
303005990
Source Category
Aluminum electrode reduction
Prebake cells
Horizontal stud soderberg
Vertical stud soderberg
Materials handling
Anode bake furnce
Other, not classified
Aluminum ore calcined
General
Coke metallurgical byproduct
General
Oven charging
Oven pushing
Quenching
Unloading
Other, not classified
Coke beehive
General
Copper smelter
Roasting
Smelting
Converting
Refining
Ore crushing,
material handling, and
miscellaneous activity
Other, not classified
Charge Rate Unit
Aluminum, tons /yr
Aluminum, tons/yr
Aluminum, tons /yr
Aluminum, tons /yr
Aluminum, tons/yr
Aluminum, tons/yr
Aluminum, tons/yr
Aluminum, tons/yr
Aluminum, tons /yr
Coal, tons/yr
Coal, tons/yr
Coal, tons/yr
Coal, tons/yr
Coal, tons /yr
Coal, tons/yr
Coal, tons/yr
Coal, tons/yr
Coal, tons/yr
a
Copper, tons/yr
_; * i ___ . _ _.__ __ * _T _^_
Copper, tons/yr
Copper, tons/yr
Copper, tons/yr
Copper, tons/yr
Ore, tons/yr
7-3
-------
Table 7- 1. DEFINITION OF PRIMARY METALS PROCESSES (Continued)
MSCC
Source Category
Charge Rate Unit
303006000
303007000
303007010
303007020
Ferroalloy production, open
furnace
Produced, tons/yr
303006010
303006020
303006030
303006040
303006050
303006990
50% ferrosilicon
75% ferrosilicon
90% ferrosilicon
Silicon metal
Silicomanganese
Other, not classified
Produced, tons/yr
Produced, tons/yr
Produced, tons/yr
Produced, tons/yr
Produced, tons/yr
Produced, tons/yr
Ferroalloy production, semi-
coyered furnace
Feromanganese
General
Produced, tons/yr
Produced, tbns/yr
Produced, tons/yr
303008000
303008010
303008020
303008030
303008040
303008050
303008060
303008990
Iron production
Blast furnace charge
Blast furnace, aggolmerates change
Sintering general
Ore-crush, handle
Scarfing
Sand handling operation
Other, not classified
Produced, tons/yr
Produced, tons/yr
Produced, tons/yr
Ore, tons/yr ,
Processed, tons/yr
Sand-baked, tons/yr
Produced, tons/yr
303009000
303009010
303009020
303009030
303009040
Steel production
Opnhearth oxlance
Opnhearth noxlance
Basic oxygen furnace (general)
Electric arc with lance
V
Produced, tons/yr
Produced, tons/yr
Produced, tons/yr
Produced, tons/yr
Produced, tons/yr
7-4
-------
Table 7-1. DEFINITION OF PRIMARY METALS PROCESSES (Continued)
MSCC
Source Category
Charge Rate Unit
303009050
303009990
Electric arc, no lance
•Other, not classified
Produced, tons/yr
Produced, tons/yr
303010000
303010010
303010020
303010990
Lead smelters
Sintering
Blast furnace
Other* not classified
Ore, to'ns/yr
Ore, tons/yr
Ore, tons/yr
303011000
303011010
303011020
303011990
Molybdenum
Mining, general
Milling, general
Process, other
Mined, 100 tons/yr
Product, tons/yr
Processed, tons/yr
303012000
303012010
Titantium processes
Chlorination stat
Product, tons/yr
303030000
303030010
303030040
Zinc smelting
General
Horizontal retorts
Processed, tons/yr
Processed, tons/yr
Processed, tons/yr
303999000
303999990
Miscellaneous metallurgical
operations
Not elsewhere classified
Processed, tons/yr
Produced, tons/yr
1This represents a collection of processes whose charge rate units are
different from one another.
7-5
-------
Table 7-2-a. 1976 PRIMARY METALS EMISSIONS AND CHARGE RATES
ANNUAL CHARGE
HONIED
303000010
303001000
303001010
303001020
303001030
303001040
3030010SO
303001990
303002000
303002010
303003000
303003010
303003020
303003030
181881818
303003990
303004000
303004010
303005000
303005020
303005030
303005040
303005050
303005060
303005990
INOUSTRIA
RATES AND EMISSIO
JACRP
CSCC UNITS)
19660000.
22082000.
2491000.
1124000.
991000.
3450000.
142*noo.
126G> /OO.
8964000.
8964000.
458400000.
81900000.
81900000.
88000000.
11888888:
36700000.
1390000*
1390000.
175000
300000000
1654000
L PROCESS*
NS PROJECT
NOX EHI
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.002
.000
.001
NEGLIGIBLE
mmm
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLi
NEGLIGIBLi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
MISSIONS (MILLIONS OF TONS /
PAGE 1
RUN DATE- MAR 22*1977
EAR)
NEGLIGIBLE
NEGLIGIBLE
Nf
Nl
BLE
8LE
NEGLIGIBLE
NEGLIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.184
.061
.102
.009
• Oil
.006
.006
NEGLIGIBLE
NEGLIGIBLE
Nf
*
Nl
NEGLIG
NEGLIG
B
B
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.056
.025
.025
.003
.004
.001
.001
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE.
NEGL GIBLfc
NEGLIGIBLi
NEGLIGIBLE
NEGLIGIBLE
PART
.006
.115
.033
.030
.013
.006
.000
.034
.045
.045
.088
.003
.037
.017
.002
.132
.132
.347
.000
303006000
4333800.
NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE
.004
.300
.003
.160
-------
Table 7-2-a. 1976 PRIMARY METALS EMISSIONS AND CHARGE RATES (Continued)
ANNUAL CHARGE
MODIFIED
SCC
181882828
303006030
303006940
303006050
303006990
303007000
18!88?818
303008000
303008010
303008020
303008030
181881818
303009000
303009010
303009020
303009030
303009040
303009050
303009990
303010000
mmm
303010990
303011000
INDUSTRIA
RATES AND EMISSIO
TACRP
ISCC UNITSI
illftg:
310850.
L PROCESS* PRIMARY METALS
NS PROJECTED TO 1976
750000.
107400.
2710000.
2480000.
80000000.
80000000.
51000000.
11
147490000.
8200000.
10100000*
64000000.
20900000.
6586400.
37700000.
6742000.
J?i888:
5200000.
NQX
EMISSIONS
m
"to
H
N|
KEGLl
BL
8LE
NEGLIGIBLE
iititilti
NEGLIGIBLE
NEGLIGIBLE
Ng
HE
010
NEGL
;L
NE
KE
BLI
BLI
BLI
.010
,000
.000
NEGLIGIBLE
(MILLION
HC
PAGE 2
RUN DATE* MAR 22*1977
)
mm
NEGLIG
HI
N_
NE
NEGL
BL
8
NEGLIGIBLE
NEGLIGIBLE
Uift
mi
NEG
,008
G
008
000
BL!
B
B
BLE
BLE
N
N
GLIGIBLj
GTlGIBTi
.000
s OF TONS / YEAR:
CO
Hf&igmi
NEGL
NEGL
BLE NEGL1
GIBLE
NEGLIGI8L
GIBLE
GIBLE
NEGLIGIBLE NEGLIGIBLE
HiitiiiStl
7.020
6.000
0.000
1.020
gittf ifstisfiti
4.271
0.000
0.000
4.000
.188
.059
.024
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
.034
.005
.003
.486
.048
.017
.096
.083
\m
• 093
.022
.013
.016
.014
.004
.024
.012
:88I
.001
.013
-------
Table 7-2-a. 1976 PRIMARY METALS EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS* PRIMARY METALS PAGE 3
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1976 RUN DATE- MAR 22*1977
MODIFIED . TACRP . EMISSIONS IMILLIQNS OF TONS / YEARI
SCC ISCC UNITS) NOX HC CO PART
303011010 112000000. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE .006
303011020 56500000, NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE .003
303011990 168000000. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE .004
303012000 65000. NEGLIGIBLE NEGLIGIBLE .002 NEGLIGIBLE
303012010 65000. NEGLIGIBLE NEGLIGIBLE .002 NEGLIGIBLE
303030000 15: 000. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE .005
303030010 61*000. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE .003
303030040 940000. NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE .002
303999000 31200000, .001 .001 .002 .047
i
00 303999990 31200000. .001 .001 .002
-------
Table 7-2-b. 1976 PRIMARY METALS UNCERTAINTIES
INDUSTRIAL PROCESS* PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976
EMISSIONS
MODIFIED
SCC
303000010
303001000
303001010
303001020
303001030
303001040
303001050
303001990
303002000
303002010
303003000
303003010
303003020
303003030
303003040
303003050
TACRP
(SCC UNITS)
4-
*•
8828500.
3899300*
177490.
177490*
8000000*
1124000.
73082.
73082.
335410.
335410.
148000.
3710800.
mm:
715940.
715940,
24758000*
24758000.
9130200.
9130200.
9130200.
9130200.
11893000.
11893000.
U 893000.
893000.
9130200.
9130200*
NOX
NEGLIGIBLE
NEGLIGIBLE
:GL
:GL
EGL
NEGL
NEGL
NEGL
NEGL]
GIBLI
BLI
3LI
BLI
G]
0.000
BLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
«• .000
- .001
+ .000
- .000
+ .000
,001
EGLIGIBLE
EGLIGIBL
(MILLIONS
HC
RUN DATE
OF
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
BLE NEGL
BLE NEGL
BLE NEGL
G
61
:G
BLI
BLI
BLI
BLf
BLE
BLE
GIBLE
NEGLIGIBLE
0.000
NEGLIGIBLE
nmitiiti
NEGLIGIBLE
NEGLIGIBLE
EGLIGIBLE
...ilXGIBLL
NEGLIGIBLE
TONS
CO
PAGE
MAR 22,1977
/ YEAR)
mmim mmm mwmt
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
NEGL
EGIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
GIBLE
NEGLIGIBLE
0.000
NEGLIGIBLE
Rieusmi
NEGLIGIBLE
NEGLIGIBLE
1- .005
i
<
i
- .027
f .004
- .025
* .004
i
• .010
+ .000
•i
N
N
N
N
• .001
EGLIGIBLE
IGLIGIBLE
IGLIGI8LE
EGLIGIBLE
PART
.21*
«• .025
- .026
+ .212
- .030
* .009
- .013
* .005
- .006
+ .000
- .015
i :m
* .037
- .045
* .035
- .039
* .002
- .001
+ .031
- .035
* .OIL
- .011
+ .011
- .012
* .002
- .002
-------
Table 7-2-b. 1976 PRIMARY METALS UNCERTAINTIES (Continued)
-j
i-**.
j>
INDUSTRIAL PROCESS* PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE
PAGE 2
MAR 22»1977
303003990
303004000
303004010
303005000
303005020
303009030
303005040
303005050
303005060
303005990
303006000
303006010
303006020
303006030
303006040
303006050
4-
4-
!SCC"*88!TS>
8944300*
8944300.
1325TO.
132570*
132570.
132570.
mm:
128060v
28060
28060.
128
986
34<
34986000.
128060.
128060.
933990.
933990.
13536.
13536.
8451.
8451.
275860.
275860.
85440.
854*0.
NOX
EMISSIONS {MILLIONS OF IONS / \TEARi
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
MH
Rllt:
NEGL
NEGL
tltt
GIBL
GIBL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
wi» t
NEGL]
G
G
SI
G:
G:
BLE
BLE
NEGLIGIBLE
NC /* I T /* T Q I C
flllti
IGLIGIBLE
* .003
- ,003
4- .001
- .001
• .001
- .001
NEGLIGIBLE
NEGLIGIBLE
LIGIBLE
LIGI
N
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
EG
EG
G]
G
B
B
.6
MEG
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* .001
- .001
* .000
- .000
«• .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE
silt
iiit
NEGL
NEGL
N
NEGL
NEGL
NEGL
GIBLI
BLE
,
G
BLI
BLi
BLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
GIBLE
GIBLE
...ML.
NEGLIG1BL!
NEGLIGIBLL
NEGLIGIBLE
NEGLIGIBLE
LIGI8LE
LIGIBLE
PART
* .001
- .001
* .029
- .021
* .029
- .021
+ .051
- .054
+ 1014
; :8U
- .019
4- .002
- .003
4- .046
- .046
* .003
- .003
4- .142
- .075
4- .002
- .002
4- .019
- .024
4- .059
- .069
* .004
- .004
-------
Table 7-2-b. 1976 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS* PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE'
PAGE 3
MAR 22*1977
MODIFIED
SCC
303006990
303007000 +
303007010 *
303007020 *
303008000
303008010 4
303008020 *
303008030 +
303008040 +
303008050 *
303008060 +
303008990 *
303009000 +
303009010 «•
303009020 +
303009030 +
TACRP
(SCC UNITS)
885300.
885300*
569650.
569650.
5*0830.
540830.
8352200.
8352200.
8352200.
8352200.
H1I8888:
2030*000.
20304000.
656050.
656050.
2030*000.
2030*000.
12158000.
12158000.
*069700.
*069700.
4903100.
4903100.
6676100.
6676100.
NOX
EMISSIONS (MILLIONS OF TONS / YEAR)
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
UttUMI
Eg:
m
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
it!
fi
Ni
is:
9 b A 1
iti!
EGLIG
H8
NEGLIG
NEGLIG
NEGLIG
BLE
BLE
BLE
BLE
* .002
- .010
NEGLIGIBLE
N
N
it
It
EGL]
HC
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mt,
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
tit
• .002
- .008
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
CO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
PART
1.016
1.016
0.000
0.000
•Ml
tgfltf
GIBLE
fftigift
NEGLIGIBL
NEGLIGIBL
NEGLIGIBL
* .760
- .760
* 0.000
- 0.000
* .759
- .759
+ .127
- .005
+ .002
- .002
T .
i :88!
* .025
- .0*8
* .009
- .017
••• .025
: :84f
- .001
* .263
- .226
+ .039
- .0*2
* .023
- .013
* .009
- .016
-------
Table 7-2-b. 1976 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS* PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE"
MODIFIED
SCC
303009040
303009050
303009990
303010000
303010010
303010020
303010990
303011000
303011010
303011020
303011990
303012000
303012010
303030000
303030010
+
*
+
TACRP
(SCC UNITS)
3981200.
3981200.
665920.
665920.
6809000.
6809000.
1010100.
1010100.
10J300.
mm-.
998890.
15620000
23431000.
9999.
9999.
191010.
191010.
NOX
EMISSIONS
(MILLIONS
HC
OF TONS
CO
PAGE 4
MAR 22*1977
/ YEAR}
PART
NEGLIGIBL!
NEGLIGlBLi
NEGLIGIBLl
NEGLIG IBLi
* .002
- .010
NEGLIGIBLE
RlitllllH
NEGLIGIBLE
* .OCO
- .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBL
NEGLIGIBL
NEGLIGIBL
NEGLIGIBL
KEGLIGIBL
NEGLIGIBLE
NEGLI
NEGLI
IBL
IBL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
+ .002
- .008
.1
. I
)0
)0
NEGLIGIBLE
RittiiiSti
NEGLIGIBLE
• .000
- .000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Rfltlfiltf
: :8U
4- .009
- .011
• .005
- .02*
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
Rfitiilgtf
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIG
NEGLIG
NEGLIG
Kilt!!
NEGLIGIBLE
BLE
.III
Itf
.001
.001
NEGLIGIBLE
NEGLIGIBLE
+ .003
- .004
+ .024
- .024
+ .006
- .008
«• .004
• .
- «225
+ .000
- .000
+ .003
- .003
+ .001
- .001
Ml
Ni
NEGLIGIBwi
NEGLIGT3LI
* .001
- .001
-------
Table 7-2-b. 1976 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS* PRIMARY METALS PAGE 5
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1976 RUN DATE- MAR 22*1977
MODIFIED
SCC
303030040
303999000
303999990
TACRP
(SCC UNITS!
166430
166430
nm
iliil
NOX
EMISSIONS (MILLIONS OF TONS / YEAR)
KEGLIGIBLI
NEGLIGIBU
HC
NEGLIGIBLI
NEGLIGIBLi
Ni
Ni
CO
iLIGIBLl
JLIGI3LI
PART
.001
.001
.006
.008
-------
Table 7-3-a. 1981 PRIMARY METALS EMISSIONS AND CHARGE RATES
INDUSTRIAL PROCESS* PRIMARY METALS
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981 RUN DATE*
MAR
303000010
303001000
303001010
303001020
303001030
303001040
303001050
303001990
303002000
303002010
303003000
181881818
1818818^
mmm
303004000
303004010
303005000
303005020
303005030
181881828
mmm
303006000
20560000.
23362000.
2576000.
1164000.
1026000.
3600000.
1496000.
13SUOOOO.
9374000.
9374000.
458400000.
1390000.
1390000.
0.
1654000.
30?
NOX
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
ELIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.002
EMISSIONS JMILLIONS OF
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
NEGLIG]
4127300.
mim
mtm
NEGLIGIBLE
.£
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
• 184
NEGLIBLE
NEGLIGIBLE
• 006
.006
NEGLIGIBLE
0,0(
EGL1
B
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
0.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.056
NEGLIGIBLE
NEGLIGIBLE
.001
.001
NEGLIGIBLE
IE NEGL
1 Nf
Ni
0.000
NEGL
NEGL
[8L
It
PAGE 1
22*1977
.001
.039
.015
.014
.000
.005
.009
.009
.032
.
:88f
.056
.056
.312
:88i
NEGLIGIBLE NEGLIGIBLE
• *
.030
-------
Table 7-3-a. 1981 PRIMARY METALS EMISSIONS AND CHARGE RATES (Continued)
Ul
INDUSTRIAL PROCESS* PRIMARY METALS
ANNUAL CHARGE RATES AND EMISSIONS PROJECTED TO 1981
HONIED
303006010
303006020
(03006030
3030060*0
303006050
303006990
303007000
303007010
303007020
303008000
303008010
303006020
303008030
303008040
303008050
303008060
303006990
303009000
ISi
303009030
303009040
303009050
303009990
303010000
mmm
303010990
303011000
iscf'SSSfrs)
NOX
EIUSSIONS
88200.
451000.
mm:
50400.
2710000.
2680000.
1160000.
1520000.
80000000.
80000000.
51000000.
82200000.
117000000.
4400000.
117000000.
135420000.
64000000
26900000.
6819400.
37700000.
6932000.
5200000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGLI
NEGL
NEGL]
NEGL
NEGL
G
6]
BLE
BLE
BLE
BLE
BLE
BLE
.010
1:888
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
O
O
.000
.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE
NEGLIG
NEGLIG
NEGLIG
NEGLIG
NEGLIG
NEGLIG]
NEGLIG
BLE
BLE
BLE
BLE
BLE
BLE
BLE
.008
NEGLIGIBLE
NEGLIGIBLE
PAGE 2
RUN DATE" MAR 22*1977
OF JONS / YEAR)
.000
.000
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE NEGLIGIBLE NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
4.510
4.000
0.000
.510
NEGLIG]
NEGLIGIBL
NEGLIG
NEGLIG
BL1
BLI
8LI
2.087
8:
1.760
.242
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.001
.006
.007
.015
.000
.001
.001
.000
.001
.144
.048
.017
.043
.008
.002
.002
.023
021
8:
.016
.003
•'
.004
• i
looo
.007
-------
Table 7-3-a. 1981 PRIMARY METALS EMISSIONS AND CHARGE RATES (Continued)
ANNUAL CHARGE
MODIFIED
SCC
mum
303011990
303012000
303012010
303030000
303030010
303030040
303999000
303999990
INOUSTRIA
RATES AND EMISSIO
TACRP
CSCC UNITS)
122000000.
61500000.
183000000.
65000.
65000.
15!,%000.
61*000.
940000.
35200000.
35200000.
L PROCESS* PRIMARY METALS
NS PROJECTED TO 1981 RUN DATE-
PAGE 3
MAR 22,1977
NOX
EMISSIONS (MILLIONS QF TONS / YEAR)
HC
C£J
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.002
.002
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.001
.001
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.000
.OCO
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
.002
.002
PART
.003
.001
.002
NEGLIGIBLE
NEGLIGIBLE
.002
.001
.001
.053
.053
-------
Table 7-3-b. 1981 PRIMARY METALS UNCERTAINTIES
INDUSTRIA
TACR AND EMISSION UNCERTAINTIES
!ScJA88?TSI
* *
303000010
303001000 +
303001010 *
303001020 +
303001030 +
3030010*0 +
303001050 +
303001990 +
303002000 *
303002010 +
303003000 «•
303003010 +
303003020 +
303003030 *
303003040 +
303003050 +
00.
8970700.
*222000.
217710.
"SHI:
*2*260.
186130.
*02*900.
779610.
779610.
68177000.
68177000.
27586000.
27586000.
27586000.
27586000.
11811888:
31822000.
31822000.
W>.
L PROCESS* PRIMARY METALS
PROJECTED TO 1981
NOX EHISSI°NS
NEGLIGIBL!
KlGLlGIBLi
M
M
IS:
iti!
.in
_ ;LI<
EGLIGl
O.OC
BLE
8
B
IB
^
8
- O.OC,
NEGLIGliLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* .000
- .001
* .000
- .000
• .000
- .001
ditiiiiti
NEGLIGIBLI
NEGLIGIBLf
NEGLII
NEGLIl
NEG
NEG_
* 0
,0(
.IBL1
ilBLI
B
B
B
B
B
81
B
n
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
* .0*2
- .116
* .022
- .059
•f .036
- .099
i :!
PAGE 1
RUN DATE' MAR 22,1977
OF TONS / YEAR)
M
Nl
Nl
Nl
Nl
VISIBLE
ELIGIBLE
NE6L
NE6
NE6
m
NEG
GJ
BLE
* 0.000
BLE
NEGLIGIBLE
mwmt
NEGLIGIBLE
NEGLIGIBLE
4- .012
- .03*
* .009
- .025
+ .009
- .02*
+ .096
- .022
* .01*
- .3015
* .095
- .01*
4- .002
- .000
* .000
* .
- .005
+ .008
- .009
+ .008
- .009
* .011
- .011
+ .000
- .000
+ .006
- .006
mmm
+ .000
- .001
+ .006
- .006
-------
Table 7-3-b. 1981 PRIMARY METALS UNCERTAINTIES (Continued)
00
INDUSTRIA
TACR AND EMISSION UNCERTAINTIES
L PROCESS* PRIMARY METALS PAGE 2
PROJECTED TO 1981 RUN DATE- MAR 22*1977
303003990
303004000
303004010
30300SOOO
303005020
303005030
303005040
303005050
303005060
303005990
303006000
303006010
303006020
303006030
303006040
303006050
(SC
TS)
*
+
158690.
158690.
158690.
158690.
0.
0.
359033.
111818:
359030.
359030.
69778000.
mm:
1595700.
1586000.
27018.
27018.
140090.
140090.
14566.
488470.
182480;
50'00.
NOX
EMISSIONS (MILLIONS OF TONS / YEAR)
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
itititt!
+ 0.000
- 0,000
NEGLIGIBLE
KiitiiitU
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
«...,.
NEG
HI
KEG
[G
tftl
:!
G
Ac"
.001
.003
,001
,003
NI
NE
* I V *"*
jLIG
> 0.000
NEG
Sit
NEC
NE6L
LE
lit
E6LIGI
Itti!
GIB
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
.IGIBLE
NEGL
NEGL
NEGL
Gl
B
BL
BL
i
«• .000
- .000
+ .000
- .030
NEGLIGIBLE
NEGLIGIBLE
+ 0.000
NEGLIGIBLE
lit
EGL
EGL1
i!
GIBLE
GIBLE
ii
G
G
G
BL
NEGLIGIBLE
NEGLIGIBLE
NEGL
NEGL
NEGL
NEGL
NEGL
GIBLE NEGL
GIBLE
III
BLE
BLE
B
B
BLI
Bit
BLE
tl
PART
.056
.056
.056
.056
0.000
0.000
.007
.*002
.001
.1
.'
.076
.000
.000
.026
• 018
.001
.CJ6
, 006
* .0
- .015
«• .001
- .000
-------
Table 7-3-b. 1981 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS* PRIMARY METALS
TACR ANO EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN DATE"
MODIFIED
SCC
303006990
303007000
303007010
303007020
303008000
TACRP
(SCC UNITS}
1501300*
1501300*
NOX
EMISSIONS (MILLIONS OF TONS
*
+
303009000 +
303009010 +
303009020 *
303009030 +
877350.
877850,
303008010
303008020
303008030
303008040
303008050
303008060
303008990
+
_
» *
«•
4-
_
+
•
•f
„
+
~
-------
Table 7-3-b. 1981 PRIMARY METALS UNCERTAINTIES (Continued)
-g
o
INDUSTRIAL PROCESS* PRIMARY METALS
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981
RUN DATE'
MODIFIED
SCC
303009040
303009050
303009990
303010000
303010010
303010020
303010990
303011000
303011010
303011020
303011990
303012000
303012010
303030000
303030010
*
*
*
*
*
TACRP
(SCC UNITS!
9749400.
11922000.
193130.
193130.
mm-.
1606100.
1606100.
24166000.
24166000.
12083000.
12083000.
36249000^
36249000.
18973.
18973.
18973.
18973.
mm:
mm:
NOX
NEGLIGIBLE
EMISSIONS
- .010
*
NEGLIGIBLE
NEGLIGIBLE
+ .000
- .000
NEGLIGIBLE
NEGLIGIBLE
i
BL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
mmi
(MILLIONS OF TONS
HC
NEGLIGIBLE
NfiiiiBkf
NEGLIGIBLE
+ .003
- .008
NEGLIGIBL
NEGLIGIBL
NEGLIGIBLE
NEGLIGIBLE
.E NEGL
' ^4 ff* 4*
i
:BL
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
CO
.092
PAGE 4
MAR 22,1977
I YEAR)
PART
* .002
- .038
4 .008
- .024
•m nfgtiiitti
NEGLIGIBLE
NEGLIGIBLE
Kiitiiiiti
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
NEGLIGIBLE
GIBLE NEGL
4* v n • I* k* £ £ f
•GL
lit
•GL
GIBL
GIB
GIB
£!§!-
GIBL
GIBL
.003
.000
* .003
- .000
RfStffiltf Nfgtigittl
Ni
N(
• 1
\Q(
• 0(
.001
.000
.001
•
!ooo
.000
.004
.004
.003
.003
.001
:88I
.002
iLIGIBLi
JLIGIBL!
NEGLIGIBLE
NEGLIGIBLE
.0
.0
-------
Table 7-3-b. 1981 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, PRIMARY METALS PAGE 5
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1981 RUN DATE* MAR 22*1977
MODIFIED
see
303030040
303999000
303999990
TACRP
CSCC UNITS!
294110.
294110.
7800000.
7800000.
7800000.
7800000.
EMISSIONS (MILLIONS OF TONS / YEAR)
NQX HC CO
NEGLIGIBLE
NEGLIGIBLE
* .000
* .002
* .000
- .002
NEGLIGIBLE
NEGLIGIBLE
* .000
- .001
* .000
- .001
NEGLIGIBLE
NEGLIGIBLE
+ .000
- .002
+ .000
- .002
1
*
*
PART
•82!
.001
.013
.013
.013
.013
-------
Although nearly 90 percent of the CO forme does get collected
and burned, approximately 150 Ib of CO per ton of pig iron escape to the
atmosphere. Much of these losses occur during charging exercises, but some
are lost through leaks and inadvertent bypass procedures. Most of the CO
and PART lost to the atmosphere occurs during "slips." A slip is caused
when a bridge of stock forms in the furnace just above the molten slag. The
bridge eventually collapses after the material beneath moves downward far
enough to remove its support. Accompanying the collapse of the bridge is a
rush of blast furnace gas to the top of the furnace, creating a momentary high
pressure condition. The dust and CO-laden gas escapes through relief valves
and bleeder ports to the atmosphere. Closer control of charge material has
helped to reduce the occurrence of slips. Also, the increased operating
pressure of the furnace and dust collection system has reduced the frequency
at which the relief valves are opened to dump the emissions into the atmor
sphere. Few improvements are expected in the collection of blast furnace
gas without substantial costs. These costs may become acceptable if the CO
could be used as a chemical reactant to produce a useful product such as
methanol rather than to burn it as the low grade fuel.
According to Ref. 7-2, the blast furnace gas contains 7 to
30 grains of dust per standard cubic foot (scf). Before the gas can be effec-
tively used as a fuel, the PART must be removed. The first stage of dust
removal involves either a cyclone or settling chamber, which removes about
60 percent of the pollutant. The second stage is normally a wet scrubber,
which removes about 90 per cert of the remaining dust. The final stage typ-
ically is an electrostatic precipitator, which can remove 90 percent of the
remaining solid emissions. The system yields a 99.6 percent overall effi-
ciency of particle collection.
For the purpose of this inventory, the general sintering opera-
tion is considered to be a part of pig iron production. The sinter operation
supplies the blast furnaces with pellets consisting of a mixture of concentrated
7-22
-------
iron ore and fine coal. This operation is also a major source of CO and PART
emissions. Control techniques are much the same as for the blast furnace,
i.e., a dust collection system consisting of cyclone separators and electro-
static precipitators.
7-3.2 Basic Oxygen Furnaces
The basic oxygen furnace (BOF) is used in producing steel from
the molten pig iron from blast furnaces (70 percent) and from scrap metal
(30 percent). Unlike the blast furnace, no fuel such as coke is added to the
charge in the BOF. Instead, the carbon, silicon, and other impurities are
oxidized by injecting a stream of oxygen toward the molten metal charge. The
oxidized silicon, manganese, and phosphorus slip into the slag, but the oxi-
dized carbon evolves as CO. Attempts at collection for future burning in
waste heat boilers are hampered by PART removal and especially by the
tendency to create an explosive atmosphere in the furnace exhaust system.
The furnace gas contains CO, which is generated at the rate of
120 to 160 Ib/ton of steel produced. Usually, an excess of air is simply
mixed with the CO and the mixture burned as a flare, instead of being cleaned
and burned in waste heat boilers. This eliminates the possibility of an ex-
plosion within the exhaust system. The CO concentration after combustion is
reduced to about 3 Ib/ton of steel produced. The bulk of the CO emissions, to
the atmosphere results from leakages and failure to collect all of the furnace
gas.
As much as 40 to 50 Ib of PART are generated per ton of steel
produced by the BOF. Reference 7-3 lists standards of performance which
when implemented would limit the particulate emissions to undiluted 0.022
grains/scf from newly installed BOFs. The limits can be achieved with high
energy venturi scrubbers.
7.3.3 Primary Copper Smelting and Refining
The yield is low for copper ore (about 0.005 percent accord-
ing to Table 2 of Ref. 7-4). As a result, dust and PART are emitted simply
7-23
-------
because of the large quantity of ore that must be handled to roduce the
copper refined in the U.S. Four major processes in the smelting of copper
are the primary sources of PART emissions.
The first process, roasting, is performed only on ores with
high sulfur content. Other ores can be fed directly to the reverberator fur-
nace. Recent improvements in furnace design may eliminate the need for
roasting. The use of the older multiple hearth roasters has been phased out
of some plants, according to Ref. 7-5. The roasters operate at a tempera-
ture near 12°F, and consequently dust collection is easily managed without
elaborate cooling equipment.
The second process takes place in the reverberatory furnace
which melts the metal-bearing charge and forms the copper entrained matte
stream. Approximately 50 percent of the PART is less than 37 |xm; conse-
quently, collection and recovery of dust from the furnace gas is difficult.
The third process occurs in the copper converter which ac-
cepts the molten matte from the reverberatory furnace. The function of the
converter is to oxidize and remove iron and sulfur from the matte stream.
About 80 percent of the particulate matte in the gas stream from the con-
verter is large enough to settle out in the flue system. The remainder is
processed through scrubbers, collectors, and electrostatic precipitators.
Based on the per unit amount of concentrated ore entering the roaster or
furnace, the emission factor of PART from the converter is the highest of
any process in copper smelting.
Refining is the final process in copper production. This pro-
cess enables copper products to meet the high purity specifications for many
copper products.
7.4 EMISSIONS ANALYSIS
This section describes certain hypotheses, assumptions, and
observations that were made in the process of establishing the data base on
which the charge rate and emission rate calculations were made.
7-24
-------
7-4-l Blast Furnace and Related Operations
Although there is good agreement among technical sources re-
garding the quantities of CO generated in the blast furnaces used to produce
pig iron, Ref. 7-6 lists a value of 1750 Ib of CO per ton of iron for an emis-
sion factor. Since this is a value near the typical number reported as the
total CO generated per ton of iron, this can be used as a representative
emission factor only if no controls are in effect, i.e., if all of the CO gen-
erated is permitted to escape to the atmosphere.
In this analysis, an effective CO emission factor was derived
from the NEDS data by dividing the CO emissions (in pounds) by the charge
rate (in tons) from Ref. 7-1. Although CO is likely to escape to the atmo-
sphere from the blast furnace during any of many operations including ore
and agglomerate charging and especially during the "slips" described in
Section 7.3. 1, all of the CO emissions from blast furnaces in this study are
grouped under MSCC 303008010, entitled Blast Furnace Ore Charging.
So that the emissions might be based on the latest data, the
base line charge rates were extracted from Ref. 7-7.
7.4.2 Basic Oxygen Furnace
CO is generated in the basic oxygen furnace (BOF) at a rate
of about 150 Ib/ton of steel produced. Although this can be reduced to near
zero (3 or 5 Ib/ton) by flaring or another combustion process, energy con-
servation tends to motivate the use of CO in waste heat boilers. The collec-
tion and cleaning of PART, necessary before using the CO as a fuel, impose
a potentially explosive atmosphere.
Both of these two techniques for combustion of the CO waste
have undesirable features. No safe means of collecting and cleaning the gas
has been demonstrated. It was assumed, therefore, that the effective emis-
sion factor in 1975 was the one that corresponded to uncontrolled conditions
(139 Ib/ton of steel). The effective emission factor, however, is expected
to decrease linearly to near zero by 1985.
7-25
-------
The 1976 CO emissions from the EOF are - ±0.75 million
tons. In 1981, these will be reduced to 1.75 plus 2.75 or minus 1.75 mil-
lion tons. The inordinately .large uncertainty is due primarily to the unknown
element of time in developing a safe collection system.
7.4.3 Copper Smelters
Good data exist on production rates of refined copper. How-
ever, most emission factor data are based on raw or, more often, on con-
centrated ore (Ref. 7-6). The ratio of concentrated ore to refined copper is
approximately 4.0, according to page 139 of Ref. 7-5. This is the ratio that
was used in calculating the emissions from copper smelters and related
operations. Production rates were extracted from Refs. 7-4, 7-5, and 7-7
to establish baseline charge rates and slopes.
The quantities of PART emissions generated in each opera-
tion are highly sensitive to such factors as the chemical composition of the
copper matte, the temperature of the converter, the fineness of the charge,
and the degree of agitation in charging. As a result, a high degree of un-
certainty exists for the uncontrolled emission factor. Fifteen percent un-
certainty was used in these analyses.
7.5 ; REFERENCES
7-1. "Computer Analysis of NEDS Point Source Emission Data," Con-
tractor Magnetic Tape No. 74362, The Aerospace Corporation,
El Segundo, California (log date November 10, 1975).
7-2. Control Techniques for Carbon Monoxide Emissions from Station-
ary Sources, U.S. Department of Housing, Education, and Welfare,
Washington, D. C. (March 1970).
7-3. Background Information for Proposed New Source Performance
Standards," Vol. 1, U.S. Environmental Protection Agency,
Washington, D. C. (June 1973).
7-4. Minerals Yearbook 1972, U.S. Bureau of Mines, Washington,
D.C. (1974).
7-26
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7-5. Particulate Pollutant System Study, U.S. Environmental Protection
Agency, Washington, D. C., prepared by Midwest Research Institute.
7-6. Compilation of Air Pollutant Emission Factor, 2nd ed., AP-42, with
Supplements 1 through 5, U.S. Environmental Protection Agency,
Research Triangle Park, North Carolina (April 1973).
7-7. Survey of Current Business, U. S. Department of Commerce,
Washington, D. C. (February 1976).
7-27
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APPENDIX A
CONVERSION FACTORS
To Convert From To Multiply By ;
Barrel (42 gallons) Cubic meters 1.590 x 10"
3
British thermal unit Joules 1.055 x 10
Fahrenheit (temperature) Kelvin TR =-|(Tp + 459. 67)
Foot Meters 3.048 X 10"4
Gallon (U.S. liquid) Cubic meters 3.785X10"3
,2
Horsepower s 50 - Watts 7.457X10
-a
Inch Meters 2.54X10"^
Lbf (pound force) Newtons 4.448
Lb (pound mass) Kilograms 4.536x10
Ton (short, 2000 pounds) Kilograms 9.072x10"
Lb per gallon Kilogram per cubic meters 1. 198 X 10
-2
Cubic feet Cubic meters 2.832 X 10
Lb per cubic foot Kilograms per cubic meter 1.602 X 10
m
Btu per ton Joules per kilogram 1. 163
Btu per gallon Joules per cubic meter 2.787 X 10
4
Btu per cubic foot Joules per cubic meter 3.726 X 10
aExact.
A-l
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APPENDIX B
GLOSSARY
ACR
API
bhp
BTX
CO
EEI
EPA
H2
HC
1C
KPPH
MMBtu/hr
MSCC
N
NEC
NEDS
nm
NH3
NO
annual charge rate
American Petroleum Institute
brake horsepower
benzene, toluene, xylene
carbon monoxide
Edison Electric Institute
Environmental Protection Agency
hydrogen
hydrocarbons
internal combustion
thousands of pounds per hour
millions of British thermal units per hour
modified source classification code
nitrogen
not elsewhere classified
National Emissions Data System
nanometer (formerly millimicron)
ammonia
oxides of nitrogen
B-l
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PART
PPM
SCC
SIC
S02
TACRP
particulate matter
parts per million
source classification code (NEDS)
standard industrial classification
sulfur dioxide
total annual charge rate projected
temperature, degree Fahrenheit
temperature, Kelvin
B-2
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TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
EPA-600/2-77-066a
2.
3. RECIPIENT'S ACCESSION-NO.
T,TLEANOSUBT.TLE INVENTORY QF COMBUSTION-
RELATED EMISSIONS FROM STATIONARY SOURCES
(First Update)
5. REPORT DATE
March 1977
6. PERFORMING ORGANIZATION CODE
. AUTHOR(S) " ' '
OwenW. Dykemaand Vernon E. Kemp
8. PERFORMING ORGANIZATION REPORT NO.
ATR-76(7549)-l (Reissue B)
9. PERFORMING ORGANIZATION NAME AND ADDRESS
The Aerospace Corporation
Environment and Energy Conservation Division
ElSegundo, California 90245
10. PROGRAM ELEMENT NO.
1AB014; ROAP 21ADG-089
11. CONTRACT/GRANT NO.
Grant R803283-02
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
13. TYPE OF REPORT AND P
Phase; 7/74-7/76
14. SPONSORING AGENCY CODE
JEPA/60Q/13
15. SUPPLEMENTARY NOTES IERL_RTP project officer for this report is R.E. Hall, Mail Drop
65, 919/549-8411 Ext 2477. EPA-600/7-76-012 was 1st report in this series.
16. ABSTRACT
The report describes the first 2 years of a study covering the combustion-
related emissions phase of a 3-year program entitled, 'Analysis of NOx Control in
Stationary Sources.' The study is aimed at assisting in the establishment of priorities
for detailed studies of techniques for the control of combustion-related emissions
from stationary sources. The inventory includes emissions of oxides of nitrogen,
hydrocarbons, carbon monoxide, and particulate matter, not only from stationary
sources primarily involving combustion, but also from other stationary sources where
combustion plays a secondary role. During the first year of the study, emissions
were established for 1975 and 1980 from boilers, internal combustion engines, chemi-
cal manufacturing, and petroleum refining. During the second year, emissions were
established for 1976 and 1981 for primary metals and hydrocarbon evaporation, as well
as for the four industries studied the first year. The third year will cover mineral
products, secondary metals, and wood products. The report identifies approximately
68% of particulate matter and between 93% and 97% of NOx, hydrocarbon, and carbon
monoxide emissions from stationary sources.
17.
KEY WORDS AND DOCUMENT ANALYSIS
a.
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS
c. COSATI Field/Group
Air Pollution, Combustion, Exhaust Gases
Nitrogen Oxides, Hydrocarbons
Evaporation, Carbon Monoxide, Dust
Boilers, Internal Combustion Engines
Chemical Industry, Petroleum Refining
Coal, Fuel Oil, Natural Gas
Air Pollution Control 13B,21B
Stationary Sources 07B, 07C
Emissions Inventory 07D, ,11G
Primary Metals 13A,21G
Hydrocarbon Evaporatior 07A,13H
Evaporative Emissions 21D
8. DISTRIBUTION STATEMENT
Unlimited
19. SECURITY CLASS (ThisReport)
Unclassified
21. NO. OF PAGES
351
20. SECURITY CLASS (Thispage)
Unclassified
22. PRICE
EPA Form 2220-1 (9-73)
B-3
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