United States Industrial Environmental Research EPA-600/7-78-100
Environmental Protection Laboratory June 1978
Agency Research Triangle Park NC 27711
<®EPA Inventory of
Combustion- Related
Emissions from
Stationary Sources
(Second Update)
Interagency
Energy/Environment
R&D Program Report
-------
RESEARCH REPORTING SERIES
Research reports of the Office of Research and Development, U.S. Environmental
Protection Agency, have been grouped into nine series. These nine broad cate-
gories were established to facilitate further development and application of en-
vironmental technology. Elimination of traditional grouping was consciously
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The nine series are:
1. Environmental Health Effects Research
2. Environmental Protection Technology
3. Ecological Research
4. Environmental Monitoring
5. Socioeconomic Environmental Studies
6. Scientific and Technical Assessment Reports (STAR)
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This report has been assigned to the INTERAGENCY ENERGY-ENVIRONMENT
RESEARCH AND DEVELOPMENT series. Reports in this series result from the
effort funded under the 17-agency Federal Energy/Environment Research and
Development Program. These studies relate to EPA's mission to protect the public
health and welfare from adverse effects of pollutants associated with energy sys-
tems. The goal of the Program is to assure the rapid development of domestic
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essary environmental data and control technology. Investigations include analy-
ses of the transport of energy-related pollutants and their health and ecological
effects; assessments of, and development of, control technologies for energy
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This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.
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EPA-600/7-78-100
June 1978
Inventory of Combustion-Related
Emissions from Stationary Sources
(Second Update)
by
Vernon E. Kemp and Owen W. Dykema
The Aerospace Corporation
Environment and Energy Conservation Division
El Segundo, California 90245
Grant No. R803283
Program Element No. EHE624A
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
This report describes a three-year study performed by The
Aerospace Corporation to satisfy the Emissions Inventory phase of a federal
grant entitled "Analysis of NO^ Control in Stationary Sources. " The grant
defines a three-year program covering the period 15 July 1974 to 30 April
1978. 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 from recognized
major stationary combustion sources as well as from stationary source
categories in which combustion plays a secondary role. During the first year
of this study, the emissions inventory was determined for boilers, internal
combustion engines, chemical manufacturing, and petroleum refining. In
the second year, the inventory was obtained for point-source evaporation and
primary metals industries. The third year of the study added mineral
products, secondary metals, and wood products to the inventory and updated
the data base for the boiler category. This report now identifies more than
90 percent of all emissions of the four air pollutants from stationary point
sources.
This report is submitted by The Aerospace Corporation under
sponsorship of the Environmental Protection Agency in partial fulfillment
of Grant Number R8Q3283. The remainder of the grant involves an analysis
of the control of oxides of nitrogen in stationary systems. The first two-years
of the emissions inventory study have been reported by Aerospace in Inventory
of Combustion-Related Emissions from Stationary Sources (First Update),
EPA-600/2-77-066a, dated March 1977.
ii
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CONTENTS
Abstract
Figures u.
Tables
Acknowledgments V11
x
I. EXECUTIVE SUMMARY
1.1 Introduction
1.2 Study Summary
1.3 Inventory Summary 1-11
1.4 Data Acquisition 1-77
1. 5 Data Handling and Storage 1-82
1.6 References 1-88
XI. EXTERNAL COMBUSTION IN BOILERS 2-1
2.1 Introduction 2-l
2. 2 Summary 23
2.3 Approach 2_3
2.4 Data Analysis from Literature 2-25
2. 5 NEDS Data Analysis 2-36
2. 6 References 2-39
III. STATIONARY INTERNAL COMBUSTION ENGINES 3-1
3. 1 Introduction
3. 2 Summary 2 2
3. 3 Point Sources 3_2
3. 4 Total Emissions from Selected Stationary
IC Engines ^ _ 3-15
3. 5 References 3-20
ill
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CONTENTS (Continued)
IV. CHEMICAL MANUFACTURING 4-1
4. 1 Introduction 4-1
4.2 Summary . 4-1
4, 3 Emission Analysis 4-9
4,4 References 4-31
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 5-10
5.5 Petroleum Refinery Processes Evaluated 5-12
5. 6 Results and Discussion 5-16
5. 7 Petroleum Refinery Practices 5-17
5. 8 References 5-22
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
VIH. SECONDARY METALS . 8-1
8. 1 Introduction 8-1
8.2 Summary 8-18
8. 3 Processes Evaluated 8-18
8.4 Emissions Analysis. . . . 8-20
8.5 References 8-22
IX. MINERAL PRODUCTS 9-1
9. 1 Introduction 9-1
9.2 Summary 9-2
9.3 Approach . 9-25
9.4 Discussion 9-28
9.5 References 9-31
X. WOOD PRODUCTS . 10-1
10. 1 Introduction 10-1
10.2 Summary 10-2
10. 3 Processes Evaluated 10-11
10. 4 Data Analysis 10-14
10. 5 References 10-15
APPENDICES
A. CONVERSION FACTORS A-l
B. GLOSSARY . . . B-l
V'
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FIGURES
1-1 1977 and 1982 Emissions from Stationary Sources 1-7
3-1 Electric Utility Gas Turbine Fuel Demand . 3-12
4-1 Emissions from Chemical Manufacturing 4-18
4-2 Synthetic Ammonia Production 4-21
4-3 Total Carbon Black Production 4-26
4-4 Breakdown of Carbon Black Production 4-27
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
-------
tables
1-1. 1977 and 1982 Stationary Point Source Emissions 1-5
1-2. 1977 Distribution of Point Source Emissions 1-6
1-3. Uncertainties in 1977 Point Source Emission
Rates 1-10
1-4. Definition of Summary Categories 1-12
1-5-a. Summary of 1977 Emissions and Charge Rates 1-17
1-5-b. Summary of 1977 Emissions and Charge Rates
Uncertainty 1-30
1-6-a. Summary of 1982 Emissions and Charge Rates. 1-47
1-6-b. Summary of 1982 Emissions and Charge Rates
Uncertainty 1-59
1-7. Study List Emissions 1-78
2-1. Definition of External Combustion (Boiler)
Processes 2-4
2-2-a. 1977 External Combustion Emissions and
Charge Rates 2-8
2-2-b. 1977 External Combustion Uncertainties 2-11
2-3-a. 1982 External Combustion Emissions and Charge Rates . . 2-16
2-3-b. 1982 External Combustion Uncertainties 2-19
3-1. Definition of Internal Combustion Processes 3-3
3-2-a. 1977 Internal Combustion Emissions and Charge
Rates 3-4
3-2-b. 1977 Internal Combustion Uncertainties 3-5
3-3-a. 1982 Internal Combustion Emissions and Charge
Rates 3-7
3-3-b. 1982 Internal Combustion Uncertainties 3-8
Vii
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TABLES (Continued)
3-4. Internal Combustion Engine Distribution: Number
Versus End Use 3-13
3-5. 1980 Projection of Total Internal Combustion
Engine Emissions 3-16
3-6. 1980 Projection of Area Source Internal Combustion
Engine Emissions 3-17
4-1. Definition of Chemical Manufacturing 4-2
4-2-a. 1977 Chemical Manufacturing Emissions and Charge
Rates 4-3
4-2-b. 1977 Chemical Manufacturing Uncertainties 4-4
4-3-a. 1982 Chemical Manufacturing Emissions and
Charge Rates 4-6
4-3-b. 1982 Chemical Manufacturing Uncertainties 4-7
4-4. Nationwide Point Source Emissions 4-10
4-5. Industrial Process Emissions 4-11
4-6. Producers of Greatest Emissions in Chemical
Manufacturing 4-12
4-7. Producers of Greatest HC Emissions in Chemical
Manufacturing 4-13
4-8. Producers of Greatest CO Emissions in Chemical
Manufacturing 4-14
4-9. Summary of Chemical Manufacturing Emissions
and Charge Rates 4-17
5-1. Definition of Petroleum Industry Processes 5-2
5-2-a. 1977 Petroleum Industry Emissions and Charge Rates . . 5-3
5-2-b. 1977 Petroleum Industry Uncertainties 5-4
5-3-a. 1982 Petroleum Industry Emissions and Charge Rates . , 5-6
5-3-b. 1982 Petroleum Industry Uncertainties 5-7
5-4. 1973 Distribution of Petroleum Products 5-11
6-1. Definition of HC Evaporation 6-3
6-2-a. 1977 HC Evaporation Emissions and Charge Rates 6-7
6-2-b. 1977 HC Evaporation Uncertainties 6-13
6-3-a. 1982 HC Evaporation Emissions and Charge Rates 6-23
6-3-b. 1982 HC Evaporation Uncertainties 6-29
viii
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TABLES (Continued)
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
7-1. Definition of Primary Metals Processes 7-3
7-2-a. 1977 Primary Metals Emissions and Charge Rates .... 7-6
7-2-b. 1977 Primary Metals Uncertainties 7-9
7-3-a. 1982 Primary Metals Emissions and Charge Rates .... 7-14
7-3-b. 1982 Primary Metals Uncertainties 7-17
8-1. Definition of Secondary Metal Processes 8-2
8-2-a. 1977 Secondary Metals Emissions and Charge Rates . . . 8-6
8-2-b. 1977 Secondary Metals Uncertainties 8-8
8-3-a. 1982 Secondary Metals Emissions and Charge Rates . . . 8-12
8-3-b. 1982 Secondary Metals Uncertainties 8-14
9-1. Definition of Mineral Products Processes 9-3
9-2-a. 1977 Mineral Products Emissions and Charge Rates . . . 9-9
9-2-b. 1977 Mineral Products Uncertainties 9-12
9-3-a. 1982 Mineral Products Emissions and Charge Rates . . . 9-17
9-3-b. 1982 Mineral Products Uncertainties 9-20
9-4. Particulate Emissions 9-26
10-1. Definition of Wood Products Processes 10-2
10-2-a. 1977 Wood Products Emissions and Charge Rates 10-3
10-2-b. 1977 Wood Products Uncertainties 10-5
10-3-a. 1982 Wood Products Emissions and Charge Rates .... 10-7
10-3-b. 1982 Wood Products Uncertainties 10-9
ix
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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 containing 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 Warner B. Lee
Siumay Cheung Patricia L. Merryman
Otto Hamberg William J. Swartwood
Norman E. Kogen Elliot K. Weinberg
Robert B. Laube Herbert M. White
The overall emissions inventory project was managed by
Owen W. Dykema, and the project coordination and organization of this
report was accomplished by Vernon E. Kemp.
x
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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 pollution 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 conducted. Be-
cause 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 project 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 NEDS data base are continuing. However, as of
1977, the NEDS data were incomplete, contained some errors, and repre-
sented data from an average time period of about 1971. The NEDS contains
no means for projecting 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
-------
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 study, which was 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 (NOx), unburned hydrocarbons (HC),
particulate matter (PART), and carbon monoxide (CO). The study utilized
the NEDS original emission data base, as well as original data obtained
from other published studies and contacts with manufacturers' associations,
to generate a detailed inventory of emissions, with projections into the future.
The nationwide emissions inventory compiled by this study
is limited to atmospheric point source emissions. Point sources are
defined, for this study, 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
the area source is likely to be large compared to the point source.
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 com-
bustion, 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 were included 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 nationwide atmospheric stationary point
source emissions of particulates, NO , HC, and CO,
particularly from industries involving combustion.
b. Determine the uncertainty of current and future emission
rates,
1.1.4 Approach
The objectives of the study were accomplished by the
performance 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 X.
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 X. The summarized results are published in
Section 1. 3.
1.1.5. Organization of Report
Data tables presented throughout this report are for the
years 1977 and 1982. 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 1977 and 1982 emissions, charge rates,
and uncertainties for the broadest categories of the process studies; and
1-3
-------
(3) a description of the data acquisition techniques and the methods used
to perform the computational analyses. Each of the major processes
studied in the emissions inventory is presented separately in Sections II
through X. For the convenience of selective users, these sections are
independently oriented.
The overall study was a three-year effort. Each year a
selected industry, process, or group of sources was studied. Also, during
the third year, the inventory of the external combustion boiler category
was updated. The basic report was revised annually during the course of
the study, with subsequent inventories and the update of the boiler category
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
The percentage distribution of the emissions of the four air
pollutants among the stationary point source categories inventoried is
shown in Table 1-1. Table 1-2 shows the quantities of the emissions from
each of these categories and these same data are shown graphically in
Figure 1-1.
Table 1-1 shows that this inventory covered more than 90
percent of all of the stationary point sources of the four air pollutants.
This study was restricted to stationary point sources. In general, a point
source is defined as a single geographical location from which more than
100 tons of an air pollutant are emitted annually. Sources too small to
qualify as point sources are summed over certain geographical areas and
are cited as area sources. In that regard, this inventory covered more
than 80 percent of all stationary sources (point plus area) of all of the four
air pollutants except hydrocarbons (HC); only 62 percent of all of the
stationary sources of HC emissions (point plus area) were covered. The
large area source of HC emissions is primarily the unloading of tank
trucks and the filling of motor vehicles at retail gasoline service stations
(vapor displacement sources).
1-4
-------
Table 1-1» 1977 DISTRIBUTION OF POINT SOURCE EMISSIONS
Source Category
SL
Percent of Total Point Source Emissions
NO
X
HC
CO
PART
Steam Boilers
84
3
2
37
Internal Combustion Engines
6
6
Neg
Neg
Chemical Manufacturing
Neg
16
9
Neg
Petroleum Refineries
5
6
47
2
Evaporation
Neg
57
Neg
Neg
Primary Metals
Neg
3
33
8
Secondary Metals
Neg
Neg
3
1
Mineral Products
3
Neg
Neg
43
Wood Products
Neg
Neg
2
2
Total Inventoried
98
91
96
93
Other Point Sources
2
9
4
7
Total Stationary Point Sources
100
100
100
100
a,lNeg" is defined as less than 0. 5%.
Data from Nationwide Emission Summary, National Emissions Data
Systems, U. S. Environmental Protection Agency, Research Triangle
Park, North Carolina (November 15, 1976).
1-5
-------
Table 1-2. 1977 AND 1982 STATIONARY POINT SOURCE EMISSIONS
Emissions, million tons/yearc
Source Category
NO
x
HC CO PART
Steam Boilers
1977
8. 01
0. 20
0. 51
6. 59
1982
6.47
0. 25
0. 61
6. 35
Internal Combustion
1977
0.59
0. 38
Neg
Neg
Engines
1982
0. 55
0. 45
Neg
Neg
Chemical Manufacturing
1977
Neg
1. 10
2. 68
Neg
1982
Neg
1. 14
2. 82
Neg
Petroleum Refineries
1977
0. 49
0. 43
15. 07
0.28
1982
0. 31
0. 47
8. 97
0. 21
Evaporation
1977
Neg
3. 84
Neg
Neg
1982
Neg
2.26
Neg
Neg
Primary Metals
1977
0. 01
0.20
10.41
1. 38
1982
0. 01
0. 20
5. 72
0. 65
Secondary Metals
1977
0. 03
0. 02
0. 82
0. 16
1982
0. 03
0. 02
0. 38
0. 07
Mineral Products
1977
0. 29
0. 01
0. 06
7. 71
1982
0. 31
0. 01
0. 05
6.40
Wood Products
1977
Neg
0. 03
0. 66
0. 33
1982
Neg
0. 02
0.40
0. 34
'Neg" is defined as less than 1% of the emissions for that category.
1 -6
-------
I
-J
0
4
* 3
c
U-i
>: 2
on
Z
e i
2
2 o
l
5 16
1»
v>
8
s
m 4
0
l
8 r~
6
4
2
0
1
LMJ
1977 1982
STEAM
BOILERS
SECTION II
OXIDES OF NITROGEN
* LESS THAN 0.10
MILLION TONS/YEAR
FrVrt 11 i'hT
JBE3-J5&SL.
HYDROCARBON
C77I fPSS EZL
w n
i
1
m in r
CARBON MONOXIDE
17771
PARTICULATE MATTER
1977 1982
INTERNAL
COMBUSTION
ENGINES
III
1977 1982
CHEMICAL
MANU-
FACTURING
IV
1977 1982
PETROLEUM
REFINERIES
1977 1982
EVAPOR-
ATION
VI
1977 1982
PRIMARY
METALS
VII
1977 1982
SECONDARY
METALS
VIII
1
I
1977 1982
MINERAL
PRODUCTS
IX
1977 1982
WOOD
PRODUCTS
¦
1976
1976
OTHER
STATIONARY
POINT
AREA
SOURCES
SOURCES
(NEDS)
(NEDS)
Figure 1-1. 1977 and 1982 emissions from stationary sources
-------
Table 1-1 shows that the category called steam (utility
and industrial) boilers is clearly the dominant stationary source of NOx
emissions and the dominant stationary combustion-related source of
particulate (PART) emissions. Of the NO emitted from these steam
X
boilers, 85 percent is emitted from utility boilers and 74 percent from
the combustion of bituminous coal. Of all the particulate emissions from
steam boilers, 76 and 94 percent result from utility boilers and bituminous
coal combustion, respectively. The largest single source of particulate
emissions, as shown in Table 1-1, is the category called Mineral Products.
These particulates, however, are largely from stone processing and
cement and asphaltic concrete plants (noncombustion sources) and the
particulate species involved are not usually considered toxic.
Although the NOx and CO emissions shown in Table 1-1
for the point source category of Internal Combustion Engines are both
small, there may be very large amounts of both air pollutants being
emitted by very large numbers of small engines (grouped in an area
source). For example, well over one million gasoline-powered internal
combustion engines were shipped from manufacturers every year for the
last 10 years, for uses ranging from small power tools to compressors,
pumps and electrical power installations. Little data are available, how-
ever, on the actual applications of these small engines, their average
useful life, or their usage rates or duty cycles. Thus the magnitude of
this possible stationary area source of NO and CO is highly uncertain.
X
Under a worst case (but possible) set of assumptions, this area source
could represent the largest single stationary source of both NO and CO.
Efforts to accurately inventory this area source appear warranted.
Table 1-1 shows that the major stationary point source of
CO is the category called Petroleum Refineries. These CO emissions
result almost entirely from processes involved in the catalytic cracking
of petroleum during the refining process. The related combustion process
is the periodic regeneration of the catalyst by burning off the coke (with
air) which becomes deposited on the catalyst. There is, however, a great
1-8
-------
deal of uncertainty in the estimates of CO emissions from this source.
Table 1-2 shows that CO emissions from petroleum refineries in 1977
were estimated at 15. 1 million tons, but Table 1-3 shows that this estimate
is uncertain within 6.2 million tons (41 percent). These estimates of CO
emissions from this process are higher than those of the National Environ-
mental Data Systems (NEDS) by more than a factor of five. The large
uncertainties result primarily from the wide ranges of emission factors
found in various data sources. These emission factor uncertainties, in
turn, are thought to result from a lack of data on, and even the possible
day-to-day variations in, the type of after-treatment and/or use of the
CO-rich gases from the catalyst regeneration process in the various
refineries. Waste heat boilers, if in use, can be very effective in reducing
these CO emissions. There was not sufficient time in this study to resolve
these uncertainties.
Table 1-1 shows that the majority of the HC emissions from
stationary point sources result from evaporation of various hydrocarbon
fluids, primarily during various surface coating and petroleum storage,
transportation and marketing processes (noncombustion processes). This
category is an even larger source of HC emissions when the area source
associated with retail gasoline service station evaporation is also con-
sidered. The relatively large HC emissions shown in Table 1-1 in the
Chemical Manufacturing category are largely due to combustion processes
involved in the production of carbon black and ammonia.
Figure 1-1 graphically shows the preponderance of the
emissions from the source categories as discussed in this section.
Table 1-2 shows the related emission levels, in millions of tons per
year. In addition, Figure 1-1 shows the projected trends in the emissions
of the pollutants from each source category, to a time five years in the
future. In general, all emissions from all source categories show
decreasing trends with time. The total emissions of each of the
four pollutants from all of the stationary point sources inventoried all
show decreasing trends ranging from 20 to 32 percent over the five-year
1-9
-------
Table 1-3. UNCERTAINTIES IN 1977 POINT
SOURCE EMISSION RATES
Source Category
Uncertainty,
million tons /year3"
NO
X
HC
CO
PART
Steam Boilers
+ 0. 52
+ 0. 11
+0. 09
+ 0, 60
-0. 52
-0.03
-0. 06
-0. 60
Internal Combustion Engines
+0.40
+0.21
Neg
Neg
-0. 15
-0. 07
Neg
Neg
Chemical Manufacturing
Neg
+0. 12
+0. 49
Neg
Neg
-0. 12
-0. 44
Neg
Petroleum Industry
+ 0. 03
+0. 04
+6. 22
+0. 01
-0. 03
-0. 04
-6. 22
-0. 01
Evaporation
Neg
+0. 53
Neg
Neg
Neg
-0.44
Neg
Neg
Primary Metals
Neg
+ 0. 02
+ 1. 58
+0. 35
Neg
-0. 06
-1. 58
-0.26
Secondary Metals
Neg
Neg
+ 0. 13
+0. 05
Neg
Neg
-0. 13
-0.06
Mineral Products
+0. 04
Neg
Neg
+ 1. 01
-0. 02
Neg
Neg
-1. 05
Wood Products
Neg
Neg
+ 0. 40
+0. 17
Neg
Neg
-0. 40
-0.20
a"Neg" is defined when the nominal emissions are less than
1% of the total stationary point source emissions.
1-10
-------
period (best estimates). Even worst case estimates, within the
ranges of uncertainties, show little or no increases in total emissions
of any of the four air pollutants over that time period. The decreasing
trends are primarily the result of increasingly widespread application
of existing or planned near-term new source performance standards.
1. 3 INVENTORY SUMMARY
The categories studied are classified and summarized
under the processes contributing the stationary source emissions of
interest. In Table 1-4, the major process categories investigated are
listed and defined according to the Modified NEDS Source Classification
Code (MSCC) and charge rate units. The 1977 and 1982 emissions are
summarized by major process category in Tables 1-5-a and 1-6-a,
respectively. The respective uncertainties for these emissions are given
in Tables 1-5-b and 1-6-b.
In these tables, three levels of summarization are defined
by the 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, 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 combustion 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 millions of cubic feet per year. In some cases, third-
level summaries involve a single process type with the same units, e. g. ,
1010020000, bituminous coal in tons per year. In such cases, the appro-
priate MSCC unit of measure is shown in Table 1-4, and a charge rate
for this unit is listed in Tables 1-5 and 1-6.
(Continued on page 1-7 7)
1-11
-------
Table 1-4. DEFINITION OF SUMMARY CATEGORIES
MSCC
Source Category
Charge Rate Unita
100000000
External Combustion (Boiler)
101000000
Electric Generation
101002000
Bituminous coal
Tons burned/yr
101004000
Residual oil
1000 gal /yr
101005000
Distillate oil
1000 gal/yr
101006000
Natural gas
Million cu ft/yr
101007000
Process gas
Million cu ft/yr
102000000
Industrial
102002000
Bituminous coal
Tons burned/yr
102004000
Residual oil
1000 gal/yr
102005000
Distillate oil
1000 gal/yr
102006000
Natural gas
Million cu ft/yr
102007000
Process gas
Million cu ft/yr
200000000
Internal Combustion
201000000
Electric Generation
201001000
Distillate oil
1000 gal/yr
201002000
Natural gas
Million cu ft/yr
201003000
Diesel
1000 gal/yr
201999000
Miscellaneous fuel
N. A.
202000000
Industrial IC Engines
202001000
Distillate oil turbine
1000 gal/yr
202002000
Distillate oil reciprocating
1000 gal/yr
202003000
Natural gas turbine
Million cu ft/yr
202004000
Natural gas reciprocating
Million cu ft/yr
202999000
Miscellaneous fuels
Million cu ft/yr
1-12
-------
Table 1-4. DEFINITION OF SUMMARY CATEGORIES (Continued)
MSCC
Source Category
Charge Rate Unita
300000000
Industrial Processes
301000000
Chemical, Manufacturing
301002000
Ammonia production with
methanator
Tons /yr
301003000
Ammonia production with CO absorber
Tons/yr
301005000
Carbon black production
Tons/yr
301999000
Miscellaneous chemical manufacturing
Tons/yr
303000000
Primary Metals
N. A.
303001000
Aluminum reduction
Aluminum, tons/y
303002000
Aluminum ore calcined
Tons/yr
303003000
Coke metallurgical
Coal, tons/yr
303004000
Coke beehive
Coal, tons/yr
303005000
Copper smelters
N. A.
303006000
Ferroalloy production (open furnace)
Tons/yr
303007000
Ferroalloy production (closed furnace)
303008000
Iron production
N. A.
303009000
Steel production
Tons/yr
303010000
Lead smelters
N. A.
303011000
Molybdenum
N. A.
303012000
Titanium
N. A.
303030000
Zinc smelting
Tons/yr
303999000
Miscellaneous metallurgical processes
Tons/yr
304000000
Secondary Metals
304001000
Aluminum operations
Tons/yr
304002000
Brass/bronze melt
Tons/yr
(continued)
1-13
-------
Table 1-4. DEFINITION OF SUMMARY CATEGORIES (Continued)
MSCC
Source Category-
Charge Rate Unita
304003000
Gray iron
Tons/yr
304004000
Secondary lead smelting
Tons/yr
304006000
Secondary magnesium
Tons/yr
304007000
Steel foundry
Tons/yr
304008000
Secondary zinc
Tons/yr
304009000
Malleable iron
Tons/yr
304010000
Nickel
Tons/yr
304020000
Furnace electrodes
Tons/yr
304050000
Misc. casting & fabrication
Tons/yr
304999000
Misc. secondary metal activity
Tons/yr
305000000
Mineral Products
305002000
Asphaltic concrete
Tons/yr
305003000
Brick manufacturing
Tons/yr
305005000
Castable refractory
Tons/yr
305006000
Cement mfg. , dry
N. A.
305007000
Cement mfg. , wet
N. A.
305008000
Ceramic/clay mfg.
Tons/yr
305009000
Clay/fly ash sinter
Tons/yr
305010000
Coal cleaning
Tons/yr
305014000
Glass mfg.
Tons/yr
305015000
Gypsum mfg.
Tons/yr
305016000
Lime mfg.
Tons/yr
305018000
Per lite mfg.
Tons/yr
305020000
Stone quarry process
Tons /yr
305022000
Potash production
Tons/yr
305024000
Magnesium carbinate
Tons/yr
(continued)
1-14
-------
Table 1-4. DEFINITION OF SUMMARY CATEGORIES (Continued)
MSCC
Source Category
Charge Rate Unita
305025000
Sand & gravel processing
Tons/yr
305999000
Miscellaneous mineral products
N. A
306000000
Petroleum Industry
306001000
Process heater
N. A.
306002000
Fluid catalytic crackers
1000 bbl/yr
306003000
Moving bed catalytic crackers
1000 bbl/yr
306008000
Miscellaneous leakage
Capacity, 1000 bbl/y
306012000
Fluid coking
Feed, 1000 bbl/yr
307000000
Wood Products
307001000
Sulfate pulping
Tons/yr, air dried
307002000
Sulfite pulping
Tons/yr, air dried
307004000
Pulpboard mfg.
Tons/yr
307006000
Tall oil/rosin
Tons/yr
307007000
Plywood/particle board
Tons/yr
307008000
Sawmill operations
Tons/yr
307020000
Furniture manufacturing
Tons/yr
307999000
Miscellaneous wood products
Tons/yr
400000000
Point Source Evaporation
N. A
401000000
Cleaning Solvents
N. A.
401001000
Dry cleaning
Clothes, tons/yr
401002000
Degreasing
Solvent, tons/yr
401999000
Miscellaneous solvent use
Solvent, tons/yr
1-15
-------
Table 1-4. DEFINITION OF SUMMARY CATEGORIES (Continued)
MSCC
Source Category
Charge Rate Unit3-
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, 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
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 & Transportation
1000 gal/yr
406001000
406002000
Rail and truck transportation
Marine vessel transportation
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.
k
Although this category is made up of two MSCC's whose units are different,
only one (202999970) was studied.
1-16
-------
Table 1-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES
SUMMARY OF MAJO® CATEGC-IES
EXTERNAL CO"
3USTI0N, eClLG
R CATEGORY
PAGE 1
ANNUAL CHANGE
3ATES ANC EMISSIONS
°°C JECTE0 TO
19 77 RUN
3 AT F =
NOV 15 >1°7 7
MODIFIED
T AC (tP
EMISSIONS
(MILLIONS OF
TONS
/ YEAR)
see
(SCC tMTS)
NOV
HC
CO
P APT
100000000
8.0 06
. 201
.506
6.577
101000000
6. 123
. 106
.285
4. 497
101002000
438640000.
5. 0*1
. 080
.2?€
4. 381
101004000
24200000.
.631
. 024
.036
. 0 97
1010050 0 0
0.
0. 000
n. ooo
0 .000
0.00 3
101006000
259720 0•
• i*15
. 001
.022
.019
101007000
90390.
.mo
NEG
NFG
NEG
102000000
1. 878
. 095
.221
2. 079
102002000
107910000.
1. 043
. 050
.123
1. 7 74
102004000
18220000.
.128
.027
.04 2
. 210
102005000
6720000.
. 121
. 010
.013
. 050
10 2006000
5011000.
. 386
. 008
.0 43
.045
102007000
17*9 500.
.000
NEG
NEG
NEG
M SCC
Source Category
Charge Rate Unit
IOOOOOOOO
External Combustion (Boiler)
101000000
Electric Generation
101002000
101004000
101005000
101006000
101007000
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
102000000
Industrial
102002000
102004000
102005000
102006000
102007000
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 i-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
OF MAJOR
CATEGORIES.
INTERNAL
C 013UST
30 N E N GINF S
PAGE 1
ANNUAL CHA^G"
3ATES ANC EMISSIONS
PR0JECTE
n TO 1977
3 UN
DA T E =
NOV 16,1977
MODIFIED
see
T ACRF
(SCC I NITS)
EHIS
NOX
EIONS (MILLIONS OF
HC
TONS
CO
/ YE API
PAPT
200000000
. 590
. ?76
.16 7
. 017
201000000
. 2M
. 091
.017
.012
201001001
201002000
201003000
201999000
11 fc 310 0 .
319570.
76259.
. 129
. 091
. 011
.013
. 002
. 001
.001
. 090
.010
.00 0
.005
.00 2
. n 03
. coo
. C02
. 001
i
oo
MSCC
Source Category
Charge Rate Unita
200000000
Internal Combustion
201000000
Electric Generation
201001000
201002000
201003000
201999000
Distillate oil
Natural gas
Diesel
Miscellaneous fuel
1000 gal/yr
Million cu ft/yr
1000 gal/yr
N. A.
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 1-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY OF MAJOR CATEGORIES
INTERNAL
COMBUSTION ENGINES
PAGE
ANNUAL CHANGE
SATES ANC EMISSIONS
PROJECTE0 TO
1977
KUN
0 AT E =
NOV 16,1977
M00IFIEC
TACRF
EMISSIONS
(MILLIONS OF
TONS
/ YEAS)
see
(SCC UNITS)
M0X
HC
CO
PART
2 0 20 00000
. 341
.283
.050
.005
202001000
71*473.
. 054
.00 0
.002
. 001
202002000
914110.
.327
. 084
.Bfcl
.0 04
202003000
3933.
. 000
. 000
.003
.000
20 2004090
2*5971.
.005
. fJOO
.00?
. COO
202999000
2 7466.
.004
. 198
.001
. 000
MSCC Source Category Charge Rate Unit
202000000 Industrial IC Engines
202001000 Distillate oil turbine 1000 gal/yr
202002000 Distillate oil reciprocating 1000 gal/yr
202003000 Natural gas turbine Million cu ft/yr
202004000 Natural gas reciprocating Million cu ft/yr
202999000 Miscellaneous fuelsa Million cu ft/yr
Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table i-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
ANNUAL CHA=G'
MOOIFIEO
SCC
301000000
301002000
3 010 0 3000
301005000
301999000
SUMMARY Or MAJOP CATEGORIES
I NTUSTRI AL PROCESS * CHEMICAL MANUFACTURING
3ATES ANt EMISSIONS PROJECTED TO 19^7 RUN D ATE =
TAC3F
( SCC UNITS)
96 ?0 9 •
25^8600.
6119^00.
151180000.
EMISSIONS (MILLIONS OF TONS
NOX
NEG
MEG
NEG
NEG
NEG
HC
1. 098
.??3
. T33
.32^
. 518
CO
2 .680
.00 3
.Ofc?
2.2 9?
.336
P*GE 1
NOV 16,1977
/ YEAR)
P A°T
NEG
NEG
NFG
NEG
NEG
i
M
O
MSCC
Source Category
Charge Rate Unit
300000000
Industrial Processes
301000000
Chemical Manufacturing
301002000
Ammonia production with
methanator
T ons/yr
301003000
301005000
301999000
Ammonia production with CO
absorber
Carbon black production
Miscellaneous chemical
manufacturing
Tons /yr
Tons/yr
Tons/yr
-------
Table 1-5-a. SUMMARY OF 19 77 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY OF MAJO,? CATEGORIES
INOUST^IAL PROCESS, FFIMAFY METALS PAGE 1
ANNUAL CHA^G^ PATES ANC EMISSIONS P&OJECTEC TO 1977 RUN D ATE = NOV 16,1977
MODIFIED
T ACSP
see
(SCC UMTS)
N0X
HC
CO
303000000
.013
. 198
10.413
303001000
22328000.
NEG
KEG
NEG
303002000
90*16003.
NEG
NEG
NEG
303003000
458400000.
. 002
. 184
.056
303004000
1390000.
NEG
. 00 6
. Ofl 1
303005000
NFG
NEG
NEG
303006000
42^2500.
NEG
KEG
NEG
303007000
2520000.
NEG
NEG
NEG
MSCC
Source Category
Charge Rate Unita
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
Coali tons/yr
N. A.
Tons/yr
PAST
1.362
. 103
• R 37
.078
. 122
. 340
. 132
. 002
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 1-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY Of MAJOR CATEGORIES
INDUSTRIAL PROCESS, PFIMARY METALS PAGE 2
ANNUAL CHA RG~
RATES AMC EMISSIONS
PROJECTED TO
19 77
PUN OATE =
NOV 16»197 7
MCDIFIEO
T ACS F
EMISSIONS
CflLLTOt^S OF TONS
/ YEAR)
see
(SCC LNITSI
NOX
HC
CO
PART
303008000
NCG
NEG
6.51?
. mn
303009000
lkkb3 0000.
.010
. 006
3.835
. 073
303010000
67 f 0000.
. 000
. 000
NEG
.007
303011000
NEG
NEG
NEG
. 012
303012000
65000.
NE5
NEG
.002
NEG
303030000
155^000•
NEG
KEG
NEG
.0 05
30 399900 0
32000000.
. 001
. 001
.002
. 0*8
MSCC Source Category Charge Rate Unita
303008000
Iron production
N. A.
303009000
Steel production
Tons/yr
303010000
Lead smelters
N. A.
303011000
Molybdenum
N. A.
303012000
Titanium
N. A.
303030000
Zinc smelting
Tons /yr
303999000
Miscellaneous metallurgical 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.
-------
I
tVJ
U>
Table 1 -5-a.
SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY CF MAJOR C AT E
GOMES
INDUSTRIAL PROCESS, SECONDARY MFTALS
PAGE 1
A NN'UAL CHA3GC xATES ANO EMISSIONS PROJECTFC TO
1977
RUN D ATE =
NOV 16,
197"
modified
TACRF EMISSIONS
(PILLIONS OF TONS
/ YEA*?)
SCC (SCC UNITS) NOX
HC
CO
P A = T
304000000
.028
. 016
.816
. 159
304001000
3812^00. .001
. 003
NEG
.006
304002000
451900. .000
. 000
NEG
.001
304003000
62197000. .000
. no2
.792
.03<*
304004000
664790. MEG
. 000
NEG
.oan
3DUO0 6 con
18380. NEG
NEG
.000
NEG
304007000 167470000. .0*3
. 004
.01^
.10<+
304003000
570*00. NEG
. 00 4
NEG
.002
304009000
1090000. NEG
NEG
.0 0 8
.000
304010000
1^700. MEG
NEG
.001
NEG
304020000
275 f50. NEG
^G
NFG
. 000
304050000
1448*00. NEG
.001
NEG
.001
304999000
1108000Q. .092
. 002
NE G
. 010
MSCC
Source Category
Charge Rate Unit
304000000
Secondary Metals
304001000
Aluminum operations
Tons/yr
304002000
Brass /bronze melt
Tons/yr
304003000
Gray iron
Tons/yr
304004000
Secondary lead smelting
Tons/yr
304006000
Secondary magnesium
Tons/yr
304007000
Steel foundry
Tons/yr
304008000
Secondary zinc
Tons/yr
304009000
Malleable iron
Tons/yr
304010000
Nickel
Tons/yr
304020000
Furnace electrodes
Tons/yr
304050000
Misc. casting & fabrication
Tons/yr
304999000
Misc. secondary metal activity
Tons/yr
-------
I
4^
Table i-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY CP" HAJOR CATEGORIES
MC0IFIEC
SCC
305000000
30500 2000
10500 3009
305005000
305006000
305007000
3 0 500 8 00 C
305009000
3 0 5010000
305014000
305015000
305016000
305013000
305020000
305022000
305024000
30 5025000
305999000
TAGS F
(SCC UN'ITSI
10C ESS,
MINERAL
PRODUCTS
PAGE 1
PR0JECTET TO 1977 ?
UN 0ATE =
NOV 16,
1977
EMI
SSIONS
(HILLIONS
OF TONS
/ YEAR)
NOX
HC
CO
P AFT
.29*
. 014
.155
7.7 12
. 046
. 001
.00 U
.6 34
MEG
NEG
NFG
. 459
NEG
NEG
NFG
.003
. 061
jeg
NE G
.6 01
. 051
NEG
NFG
.5*8
.003
KFG
.00 1
. 182
NEG
NEG
NEG
. 021
.006
KEG
.00 1
.097
. 019
NEG
NEG
.013
. 002
NEG
NFG
.081
.003
. 000
.00 2
.3 88
NEG
NEG
NEG
. G02
. 053
. 002
.014
3.793
NEG
NEG
NEG
. 048
NEG
NEG
NEG
.009
. 3 32
NEG
.010
. 596
.018
.011
.02 4
.2 39
MSCC
Source Category
Charge Rate Unit
305000000 Mineral Products
305002000 Asphaltic concrete Tons/yr
305003000 Brick manufacturing Tons/yr
305005000 Castable refractory Tons/yr
305006000 Cement manufacturing, dry N. A.
305007000 Cement manufacturing, wet N. A.
305008000 Ceramic/clay manufacturing Tons/yr
305009000 Clay/fly ash sinter Tons/yr
305010000 Coal cleaning Tons/yr
305014000 Glass manufacturing Tons/yr
305015000 Gypsum manufacturing Tons/yr
305016000 Lime manufacturing Tons/yr
305018000 Perlite manufacturing Tons/yr
305020000 Stone quarry process Tons/yr
305022000 Potash production Tons/yr
305024000 Magnesium carbinate Tons/yr
305025000 Sand and gravel processing Tons/yr
305999000 Miscellaneous mineral products N.A.
-------
Table 1-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY OF MAJOR CATEGCPIES
INDUSTRIAL PROCESS, "ETFCLEU* PRODUCTS PAGE 1
ANNUAL CHANGE 3ATES ANT EMISSIONS PRCJECTEO TO 1977 R UN 0 AT E = NOV 16,1977
MODIFIEC
SCC
306000000
3 06 00100 0
306002000
306003000
306008000
306012000
TAC3P
(SCC LMTSI
1576000.
93100.
276 ?0000.
IHiOQO.
NOX
.1**7
. <»35
• 0 53
NEG
NEG
NEG
EMISSIONS ("'IL LIONS OF TONS / YE £3)
HC
. ^26
. 0«*9
. 174
. "04
. 198
NEG
CO
15.071
.036
1<*.159
.177
NFG
NEG
PART
.279
. 090
. 161
Nt G
NEG
.H28
in
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
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 1-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY OF MAJOR CAT EGG IES
ANNUAL CHA^G:
MODI FIE C
SCC
307000000
397001000
307002000
307004000
307006000
30 7007000
307008000
307020000
307999000
INDUSTRIAL °^OCESS, WCOO P-ODUCTS PAGE
RATES A N E EMISSIONS =>R0JECTEn TO 1977 =>UN 0 AT E = NOV 15,1977
TAC«F
(SCC LMTSI
11132000.
4W003.
62520000.
161900000.
2525000.
0.
N0X
.033
. 005
. oon
NEG
Nc G
. 003
NEG
NEG
0. 000
EMISSIONS I PILLIONS OF TONS / YEA®)
HC
. 027
. 00 5
NFG
. 00 9
. COl
. 006
. COl
. 004
. 000
CO
• 66 4
.63 7
.02?
NEG
NEG
.00 1
.001
NEG
i. o o n
PAFT
.3 31
. 273
.007
.001
NEG
. 022
. 021
. 0 07
1.000
MSCC
Source Category
Charge Rate Unit
307000000
Wood Products
307001000
Sulfate pulping
Tons/yr, air dried
307002000
Sulfite pulping
Tons/yr, air dried
307004000
Pulpboard mfg.
Tons/yr
307006000
Tall oil/rosin
Tons/yr
307007000
Plywood/particle board
Tons/yr
307008000
Sawmill operations
Tons/yr
307020000
Furniture manufacturing
Tons/yr
307999000
Miscellaneous wood products
Tons/yr
-------
Table 1-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY CF HAJCATFGQ-IES
HYDROCARBON EVAPORATION PAGE 1
ANNUAL CHA-GE ?ATES ANC EMISSIONS P'OJECTET TO 19 77 -UN 0 AT E = NOV 16,1377
MCHIFTEn TAC«F EMISSIONS (MILLIONS OF TONS / YEA3)
SCO < SGC LNITSI NOX HC CO PA*T
<~00000000 NEG 3.839 NEC .011
wOlOOOOOO NEG .129 NEG NEG
**01001000 ^ 20S 0• NEG .003 NEC N~G
i* oi oo 200 0 listen. meg .103 nfg meg
-01999000 113650. NEG . C23 NFG *-G
t\>
-J
MSCC
Source Category
Charge Rate Unita
400000000
Point Source Evaporation
N. A
401000000
Cleaning Solvents
N. A.
401001000
Dry cleaning
Clothes, tons/yr
401002000
De greasing
Solvent, tons/yr
401999000
Miscellaneous solvent use
Solvent, 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 1-5-a. SUMMARY OF 19 77 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY CF ^AJOR CATEGORIES
HY0P.3C4',e3N ZV0PO*ATT CN PAGE 2
ANNUAL CHA^GZ
SATES ANT EMISSIONS
P'OJECTE
C TO 1977
^UN DATE =
NOV 16,1977
M COIFI£ C
T ACRF
EHIS
SIGNS (PILLIONS Op TONS
/ YEA9)
see
(SCC UMTS)
MO X
HC
CO
P4PT
<.02000000
1*861000.
NEG
2. 003
NEG
- »S 11
402001000
470730.
NEG
. 715
NE C-
NE G
402002000
9437EOO.
NEG
. ^11
NEG
NEG
M2003000
2*59730.
NEG
. 178
NEG
NEG
4 0200400 0
eoise.
NEG
. 053
NEG
NEG
4020(15000
3 15150.
NEG
. 163
NFG
NEG
<~02006000
95 9 730.
NEG
.461
NEG
NEG
402007000
1597EO0.
NEG
. 231
NEG
NEG
402003000
180700.
NEG
. 099
NEG
NEG
402999001
1539^00.
NEG
. 192
NEG
. Oil
MSCC Source Category Charge Rate Unit
402000000
Surface Coating
Coating,
tons/yr
402001000
Paint
Coating,
tons/yr
402002000
Paper coatings
Coating,
tons/yr
402003000
Varnish and shellac
Coating,
tons/yr
402004000
Lacquer
Coating,
tons/yr
402005000
Enamel
Coating,
tons/yr
402006000
Primer
Coating,
tons/yr
402007000
Fabric coatings
Coating,
tons/yr
402008000
Oven coatings
Coating,
tons/yr
402999000
Miscellaneous coatings
Coating,
tons/yr
-------
Table i-5-a. SUMMARY OF 1977 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY
OF MAJ1P CATIGCTIES
HYDROCARBON rVOFCrHTICN
p AGr i
ANNUAL "HA^GE
^ATES £ N l EMISSIONS
Pp 0 J EC T F 0 TO 1077
~ UN
DATE =
NOV 16,1977
'•'ODIFIEC
see
T ACSF
(SCC UNITS)
EMISSIONS 1 "• ILL I0KS CF
N0X HC
TONS
CO
/ YE
P APT
ui?ooooon
MEG 1.J51
NEC-
NEG
•~(1 3001000
40 ?00?010
*03003010
40399900T
18360003.
150f0000.
NEG 1.007
NEG .194
NEG .CHI
WES . <369
HE G
NEG
NEG
NEG
NEG
NEG
NEG
NFG
406000003
1997=0000.
KEG .357
NE C
NEG
*06001001
406002000
821^000.
11760000 0.
NEG .210
NCG .147
NEG
NEG
NEG
NEG
i
IV
vO
MSCC
Source Category
Charge Rate Unita
403000000
Petroleum Storage
N. A.
403001000
Fixed roof
N. A.
403002000
Floating roof
N. A.
403003000
Variable vapor space
1000 gal/yr
403999000
Miscellaneous storage
1000 gal/yr
406000000
Petroleum Marketing and Transportation
1000 gal/yr
406001000
Rail and truck transportation
1000 gal/yr
406002000
Marine vessel transportation
1000 gal/yr
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-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY
SUMMARY OF MAJOR CATEGORIES
EXTERNAL COMBUSTION, ECU-TP OAT EGO 5 Y CAGE 1
TACR A ND ELUSION UNCE PTAI hTIES PRCJECTE"* TC 1977 PUN QATl = NOV 16,1977
MODIFIED
TACR f
EMI
SSIONS
fMILLIONS
OF
TONS /
YEA?)
see
(SCC LNITSI
NOX
h n
CO
PART
100000000
«¦
.522
~
. 11?
+
.090
+
. 595
—
.51?
—
. 025
-
.061
-
.59£*
loionooon
+
. *91
+
. Ill
+
.050
. 539
—
. i»73
—
. 017
-
.053
-
.5 39
101002000
+ 9195800.
~
. <»<»9
~
. 110
+
.077
+
. 5 38
91^6500.
-
. 4V9
-
. (16
-
.05 2
—
. 5 3 8
lOlOOWO
~ i»9 11 50 0.
«-
.195
~
. 011
+
.017
~
.020
3609100.
-
. 1<»1
-
. 008
-
.011
-
. 012*
101005000
~ 0.
+
0. 000
~ 0
. 000
+
C.OO 0
+
0.000
0.
-
0. 000
- 0
. 000
—
0. 00 0
-
0.0 00
101006000
~ 127590.
~
.0 39
~
. 001
~
.00 0
~
. 0 01
125150.
-
• 0 39
-
.000
-
.006
-
. 0 01
101007000
~ 15220.
+
. 000
NEG
NEG
NEG
1522 0.
-
. 000
NEG
NEG
NEG
MSCC
Source Category
Charge Rate Unit
lOOOOOOOO
External Combustion (Boiler)
101000000
Electric Generation
101002000
Bituminous coal
Tons burned/yr
101004000
Residual oil
1000 gal/yr
101005000
Distillate oil
1000 gal/yr
101006000
Natural gas
Million cu ft/yr
101007000
Process gas
Million cu ft/yr
-------
Table 1-5-b.
SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF hajjr CATEGORIES
= XTE2NA. COMBUSTION,
7ACR ANT E
-------
Table i-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY
OF MAJOR
CATFGO FIES
internal
COMBUSTION ENGINES
PAGE
TACR AND
EMISSI
ON UNCERTAINTIES FR tJECTED
TO 1977
RUN DATE =
NOV lo,
1977
MODIFIED
T ACSP
EMIS
SIGNS
(MILLIONS OF TONS
/ YEAP)
see
(SCO UNITS)
NOX
HC
CO
PA F T
200000000
«¦
. 400
~
. 210
+ .039
~
. 0?5
-
. 151
—
. 073
- .01^
-
. 0 09
201000000
*
. 331
+
. 018
+ .030
+
.0 25
—
. 133
•
. 017
- .010
—
. 009
201001000
«-
33£
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATEGORIES
INTERNAL COMBUSTION ENGINES
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1977
MODIFIED
see
202000000
202001000
202002000
202003000
202004000
202999000
TACxF
(SCC UNITS)
:-3032.
33032.
6 21400.
211690.
1626.
1626.
26177.
26177.
9^53.
9453.
EMI
SSI0NS
(MILLIONS OF
TONS
NOX
HC
CO
. 121
+
. 209 +
.025
.076
—
.071
. 01 P
.002
•f
. 000 ~
.00 1
. 002
. QOO
.001
.121
~
. 032 ~
.024
.076
—
. 019
.01 P
.000
~ ¦
. 000 +
.003
. 000
. 000
.001
.005
~
. 000 +
.00 2
• 005
-
. 000
.0132
. 001
~
. 20 7 ~
. 00 0
. 001
—
. 068
. 00 0
PAGE 2
RUN DATE = NOV 16,1977
/ YEAP)
PAPT
. 0 05
. 0 0^
.0 00
. COG
. 005
.
.0 00
. 0 00
* 0 00
.000
.000
. 000
MSCC
Source Category
Charge Rate Unit
202000000 Industrial IC 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
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATEGORIES
INDUSTRIAL PROCESS, CHEMICAL MANUFACTURING PAGE 1
TACR A NO EMISSm UNCESTAI MIES F9CJECTED TC 1977 3UN OATE = NOV 16,1977
MOOIFIEC
T AC^F
EMIS 5I0NS
(MILLIONS
OF
TONS
— - - - / - '
/ YEA«?)
see
(SCC LNITS)
NOX
HC
CO
PA^T
30iooooon
NEG
~
. 103
.377
NEG
NEG
-
. 10 3
-
.37 7
NEG
301002000
4-
239S90•
NEG
~
• H29
.00 1
NEG
239590.
NEG
-
. 129
-
.001
NEG
301003000
~
56*97.
NEG
~
. 004
+
.033
NEG
-
56*97.
NEG
-
. T04
-
.333
NEG
301005000
~
228200.
NEG
~
. 07*»
~
.35 3
NEG
—
22e300.
NEG
—
. 07U
—
. 352
NEG
301999000
~
17h6A000.
NEG
•f
.0 65
~
.129
NEG
-
17
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OP MAJOR CATEGORIES
INDUSTRIAL PROCESS, PFIMARY METALS DAGE 1
TACR ANT E^IiSION UNCEFTAI ^IES PROJECTED 7C 1977 RUK' JA T E = NOV 16,1977
MCniFIEO
SCC
303030010
TACSP
(SCC UNITS)
NOX
EMISSIONS (PILLIONS OF TONS / YEAR1
no?
010
HC
. 022
. 06i»
303001000
~
38^9^00.
NEG
NEG
—
39
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATEGORIES
INDUSTRIAL PROCESS, PRIMARY METALS PAGE 2
TACR A NO e"issiot, UNC EST AI f>TI£S
FRCJEGTET
TO 1977
RUN
Q ATE =
NOV 16,
1^77
MCDIFIEC
TAC5F
EMISSIONS
(MILLIONS OF
TONS
/ YEAR)
see
CSCC UNITS)
NOX
HC
CO
P APT
303008000
NEG
?:eg
+
1.151
¦f
.2^7
NEG
KEG
-
1.151
-
.222
303009000
~
14310000.
~
. 002
~
. 002
~
1.0 8 5
+
.0 31
—
1V310000.
-
. 010
-
. no8
-
1.08 6
-
.033
303010010
~
1116500.
+
.000
~
. 000
NEG
+
.003
-
1116500.
-
. 000
-
. coo
NEG
-
.005
303011000
NEG
KEG
NEG
«¦
.0 03
NEG
NEG
NE G
—
• G0h
303012000
~
11 €61.
NEG
NEG
+
.002
NEG
-
11€61.
NEG
NEG
-
. 001
NFG
303030000
~
2191^3.
NEG
NEG
NEG
. 002
-
2191^0.
NEG
NEG
NFG
-
.002
303999000
f
5 0C00G0.
*
. 000
~
. 00 0
+
. 00 0
~
. 009
—
5000000.
-
. 031
-
. C01
-
. 00 1
-
.009
MSCC
Source Category
Charge Rate Unita
303008000
Iron production
N. A.
303009000
Steel production
Tons / yr
303010000
Lead smelters
N. A.
303011000
Molybdenum
N. A.
303012000
Titanium
N. A.
303030000
Zinc smelting
Tons /yr
303999000
Miscellaneous metallurgical 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 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY
OP MAJOR
CATEGORIES
INDUSTRIAL
PR0CFSS, S
EC 0 N 9 A Y METALS
Pfl
GF 12
TACR ANO EMISSION
UNCERTAINTIES
tJECTET
TO 1977
SUN
DATE =
NOV 16,
1977
MODIFIED
T ACS F
EM IS
EIONS (MILLIONS
OF
TONS
/ YEA?)
SCC tSCC UMTS)
NOX
HC
CO
DflPT
304000000
~
.003
~ . noi
~
.131
~
. Of 0
-
. flog
- . 003
—
.131
~
.05b
3Q400100T1 «•
116990.
~
. 000
.000
NEG
~
. 0 01
116990.
—
. 000
- .001
NEG
-
. 001
304002000 ~
2Mf25.
. 000
~ .coo
NEG
~
.001
24625.
.000
- . 000
NEG
-
. 001
304003ono ~
3073(00,
~
. 000
~ . (00
~
.131
+
.019
30 73600.
-
. 000
- . noi
-
.131
-
. 021
304004000 ~
27123.
NEG
+ . 000
NEG
•f
.000
27123.
NEG
- . 000
NEG
—
.000
304006000 «¦
1979.
NEG
fEG
~
. 000
NEG
1979.
NEG
NEG
—
.000
NEG
MSCC
Source Category
Charge Rate Unit
304000000
Secondary Metals
304001000
Aluminum operations
Tons/yr
304002000
Brass /bronze melt
Tons/yr
304003000
Gray iron
Tons/yr
304004000
Secondary lead smelting
Tons/yr
304006000
Secondary magnesium
T ons/yr
-------
Table i-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY 0" 1AJ0R CATtGOrIES
INDUSTRIAL PROCESS» SECONDA = v METALS PAGE lb
TACR A NO EMISSION UNC£FT AINTIES
PRCJECTE"!
TO 197 7
RUN DATE =
NOV 16,
197 7
MODIFIED
TACR F
em:s
SIONS
MILLIONS OF TONS
/ YEAR!
see
(SCC UMTS)
NOX
HC
CO
PART
304007000
~ 6209800.
«¦
.003
~
. 001
~ .011
~
.046
62 0 9€0 0.
-
.009
—
.002
- .00 u
-
.051
304008000
~ 63268.
NEG
+
. (01
NEG
+
.0 01
6 326 8.
NEG
-
.001
NEG
-
. 0 02
304009000
~ 171600.
NEG
NEG
~ .00 5
4-
. 000
171E0Q.
NEG
NEG
- .00 5
-
.000
304010000
~ 4104.
NEG
NEG
~ .001
NEG
4104,
NEG
NEG
- .00 1
NEG
304020000
* 59095.
NEG
NEG
NEG
+
. 000
55095.
NEG
NEG
NEG
-
.0 03
304050000
* 345400.
NEG
~
. noo
NEG
~
.0 01
345*00.
NEG
-
. 001
NEG
-
. 001
3049990 0 0
~ 2250000.
+
. 001
~
.000
NEG
+
.005
2250000.
-
.001
—
. 001
NEG
-
. 003
MSCC
Source Category
Charge Rate Unit
304007000
Steel foundry
Tons/yr
304008000
Secondary zinc
Tons/yr
304009000
Malleable iron
Tons/yr
304010000
Nickel
Tons/yr
304020000
Furnace electrodes
Tons/yr
304050000
Misc. casting & fabrication
Tons/yr
304999000
Misc. secondary metal activity
Tons/yr
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATEGORIES
INDUSTRIAL PRCCFSS, MINERAL PRODUCTS
TACR ANO EMISSION UNCECTAI MIES c?>cJECTEn TO 197? ?UN 0 ATE = NOV
MC0IFIEO
see
305000000
305002000
3 0 500 300 0
305005000
305006000
305007000
305008000
305009000
i T AC1?? EMISSIONS
MILLIONS 0^
TONS / V
< see
UNITS) M0X
HC
CO
I
~ . 0*1
+
. 003
+
.007
- .0 22
—
. GO 3
-
.007
1
~ .009
~
.000
~
. 001
- . 009
-
. noo
-
.001
1
NEG
NEG
NEG
NEG
NEG
NEG
1
NEG
NFG
NEG
NEG
NEG
NEG
1
4- .013
NEG
NEG
- .008
NEG
NEG
1
~ .006
NEG
NEG
- . 011
NEG
NEG
1
~ . 000
NEG
~
.000
- . 000
NEG
—
. 000
1
NEG
NEG
NEG
NEG
NEG
NEG
MSCC
Source Category
Charge Rate Unita
305000000
Mineral Products
305002000
Asphaltic concrete
Tons/yr
305003000
Brick manufacturing
Tons/yr
305005000
Castable refractory
Tons/yr
305006000
Cement mfg. , dry
N. A.
305007000
Cement mfg. , wet
N. A.
305008000
Ce ramie /clay mfg.
Tons/yr
305009000
Clay /fly ash sinter
Tons/yr
PAGE 1
16,1977
Afi)
PART
1.013
1. 0u9
. 2h1
.294
. 09S
• 0 9 3
. 0 01
.001
.257
. 280
.275
• 298
.037
. OVfl
. CC<»
.0 0^
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-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATEGORIES
INDUSTRIAL PROCESS, MINERAL PRODUCTS PAGE 2
T/VCR AND F
MISSION UNCERTAINTIES
o
30JECTE")
TO 197
7
PUN
DATE -
NOV 16,
197 7
MODIFIED
T ACP
EMISSIONS
MILLIONS OF
TONS
/ YEA")
see
(SCC UNITS 1
NOX
HC
CO
PART
305010000
f
. 001
KEG
*¦
.000
+
• 02^4
-
. 001
NEG
-
.00 0
. 03 3
30501*4000
+
. 005
NEG
NEG
~
. 002
-
.005
NEG
NFG
.0 C2
305015000
+
. 036
KEG
NEG
«¦
.023
-
. 031
KEG
NEG
.033
305016000
~
. 000
+
. 000
+
• ooo
+
.180
—
.000
—
. 000
—
.00 n
. 209
305018000
NEG
NEG
NEG
~
. 001
NEG
NEG
NEG
.001
3050?0000
+
.012
~
. 001
~
.00 <4
4
.86*4
-
.012
-
. C01
-
.00 6
.872
305022000
NEG
NEG
NEG
•f
. 016
NEG
NEG
NEG
. 016
30502
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATPGO-TES
INDUSTRIAL PROCESS, ^ETRCLEUM PRODUCTS
TACR Ahn EMISSION UNCERTAINTIES PROJECTED TO 1977 «=UN D AT E = NOV
MODIFIED
TAC^P
SCO
(SCC UMTS)
NO*
H C
CO
soeoooonn
¦4-
. 027
«¦
. 038
~
6.21c
~
—
. 0?7
-
. 039
—
6.21 6
-
306001000
~
.027
. 00 6
~
.005
~
-
. 0 27
-
. 006
-
.00 ~
-
306002000
~
72971.
¦f
.03*
~
. 012
~
6.21c
~
-
72571.
-
-
. 012
—
6.216
-
306003000
«-
8 €33.
NEG
«¦
. 000
+
.019
-
fi €33.
MEG
-
. 000
-
.319
306038000
~
590690.
NEG
~
. 036
NEG
-
590690.
NEG
-
. 036
NFG
306012000
~
520 5.
NEG
NEG
NEG
~
-
5205.
NEG
NEG
NEG
-
PAGE 1
16,1977
EMISSIONS (MILLIONS CP TONS / YEA')
P A FT
.01?
.01?
. 0 fJ5
. nop
.0 11
. mi
NEG
KEG
NEG
MEG
. 0C2
. 002
MSCC
Source Category
Charge Rate Unit3,
306000000
Petroleum Industry
306001000
Process heater
N. 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 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 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY Of MAJJF CATEGORIES
I NO USTHIA L PROCESS ? HOOD P-OOUCTS PAGE 1
TACR AND EMISSION UNCERTAINTIES PR GJFCTE 9 TO 1977 RUt' DATE = NOV 16,197 7
MCOIFIEO
TACSP
EMISSIONS
MILLIONS
OF
TONS /
YEAR)
see
(SCC UMTS!
NO X
HC
CO
PART
307000000
f
.038
¥
. 002
+
.197
~ .172
. 003
-
. 002
-
.39 7
- .202
307001000
+
.038
~
. 001
~
.39 7
~ .172
—
. 003
-
. toi
-
.39 7
- .201
307002000
+
.000
NEG
+
. 002
+ .001
-
. 000
K'EG
-
.032
- .001
307004000
*¦ 225620.
NEG
+
. 000
NEG
~ .000
225620.
NEG
-
. coo
NE G
- .000
307006000
~ 50062.
NEG
+
. 000
NEG
NEG
50062.
NEG
-
. 000
NEG
NEG
307007000
~ 21Rf30.
+
. 000
+
. 000
~
. 00 0
* .0 0 3
218630.
-
. 0 00
-
. 000
.00 0
- .003
307008090
* 0.
NEG
t-
0. 00 0
~
0.00 0
~ 0.000
0.
NEG
-
0. 000
-
0.00 0
- .0 17
307020000
~ 200000.
NEG
*
. 000
NE G
+ .0 01
20 0000.
NEG
-
. coo
NEG
- .001
307999000
* 0.
+
0. 0 00
~
0. 000
~
0.00 0
~ 0.000
0.
-
0. 000
-
0. 000
-
0.00 0
- 0.000
MSCC
Source Category
Charge Rate Unit
307000000
Wood Products
307001000
Sulfate pulping
Tons/yr, air dried
307002000
Sulfite pulping
Tons/yr, air dried
307004000
Pulpboard mfg.
Tons/yr
307006000
Tall oil/rosin
Tons/yr
307007000
Plywood/particle board
Tons/yr
307008000
Sawmill operations
Tons/yr
307020000
Furniture manufacturing
Tons/yr
307999000
Miscellaneous wood products
Tons/yr
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
TACK AND F
^CDIFI^n
SCC
tfOQOOOOOO
^oionnooa
<+01001000
*~01002000
1*019990011
MSCC
Source Category
Charge Rate Unita
400000000
Point Source Evaporation
N. A.
401000000
Cleaning Solvents
N. A.
401001000
Dry cleaning
Clothes, tons/yr
401002000
Degreasing
Solvent, tons/yr
401999000
Miscellaneous solvent use
Solvent, tonp/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.
SIMMARY OF MAJOR CATEGC'IES
HY0jnCA^R0N r
V AFC* AT
IGN
PA
G- 1
SlOh UNCEFTAINTIES PROJECTS
TC 147
UN [) AT E =
nov ie»
197^
TACP f
EMI
SSI0NS
(MILLIONS
OF TOMS
/ YEA')
(SCO LMTS1
N0X
HP
CO
PART
NEG
f
. 533
NE G
. 0 02
NEG
-
.
NEG
-
.002
NEG
+
. 05 9
NEG
N r r-
NEG
~
. 05 9
NEG
NEG
* 2510-*.
NEG
*¦
. C04
NEG
NE j
15396.
NEG
-
.no?
NEG
NEG
~ 6:0930.
NEG
4-
. 058
NE G
NEG
60
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OP MAJOR CATEGORIES
HYDROCARBON EVAPORATION PAGE ?
TACR AND EMISSIOh UNCERTAINTIES PROJECTED TO 1977 RUN OATE = NOV 16,1977
MODIFIED
TACRF
EMISSI 0NS
IMILL
IONS OF TONS / YE
AR)
see
(SCC
UMTS!
M0 X
HC
CO
PART
<~02000000
*¦ 3936200.
NEG
+
. 282
NEC
*¦
• 0 02
3903100.
NEG
-
.262
NEG
-
.002
*~02001000
NEG
~
. 036
NEG
NEG
<< 5 9<» 6.
NEG
-
. (36
NEG
NEG
<~02002000
~ 3922000.
NEG
~
. 217
NEG
NEG
3 8 9370 0.
NEG
-
. 189
NEG
NEG
<*02003000
«•
3U25.
NEG
~
. Q27
NEG
Ni£G
31425.
NEG
—
. 027
NEG
NEG
<~02004000
~
13532.
NEG
~
.011
NEG
NEG
13532.
NEG
—
. Oil
NEG
NEG
<~02005000
*¦
53 <0 7.
NEG
~
. 031
NEC
NEG
53907.
NEG
. 031
NEC-
NEG
<~02006000
*
102430,
NEG
~
.113
NEG
NEG
102430.
NEG
—
.113
NEG
NEG
<~02007000
~
106670.
NEG
~
. 120
NEG
NcG
106670.
NEG
—
. 122
NEG
NEG
<~02009000
~
33707.
NEG
~
. 021
NEG
NEG
33707.
NEG
—
. 021
NFG
NEG
<~02999000
~
287690.
NEG
. 04l»
NEG
f
. 002
-
287690.
NEG
—
• 044
NE G
m
.002
MSCC
Source Category
Charge Rate Unit
402000000
Surface Coating
Coating, tons/yr
402001000
Paint
Coating, tons/yr
402002000
Paper coatings
Coating, tons/yr
402003000
Varnish and shellac
Coating, tons/yr
402004000
Lacquer
Coating, tons/yr
402005000
Enamel
Coating, tons/yr
402006000
Primer
Coating, tons/yr
402007000
Fabric coatings
Coating, tons/yr
402008000
Oven coatings
Coating, tons/yr
402999000
Miscellaneous c
oatings
Coating, tons/yr
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY 1c HAJT- CATTGOUES
HYSROC^ON rV£FORATTCN PAGE 1
TACR ANT rilSSIOh U NCE c T AI MIES
PROJECTS 1 TO 19
?? P
UN HATE -
NOV 16,1977
MODIFIEC
T AC^P
EMISSIONS
OILLtONS
CF TONS
/ YE A c)
see
(SCC UMT'jl
NOX
HC
CO
PART
un3000000
NEG +
. u?7
NEG
NEG
NEG
. **3?
NEG
NEG
tojooioon
NEG ~
.4? 5
NEC
NLG
NEG
. 7?1
NF G
NrG
40300201"!
MEG ~
. 0 89
NEC-
NEG
NEG
. (85
NEG
NEG
40300300Q +
h£9
-------
Table 1-5-b. SUMMARY OF 1977 EMISSION AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY of MAJOR CATEGORIES
HYDROCARBON EVAPORATION PAGE i*
TACR AKQ E MISSIO UNCERTAINTIES PROJECTED TO 1977 RUN 0 ATE = NOV 16,1977
MODIFIED T AC'P EMISSIONS t MILLIONS OF TONS / YEAP)
SCC (SCC UNITS) NOX HC CO PART
<~06000000 ~ 21351000. NEG ~ .100 NEG N^G
21350QOQ. NEG - .093 NEG NEG
<+06001000 ~ 8773 700. NEG ~ . 093 NEG NEG
8773000. NEG - .C85 NEG NEG
<~06002000 «¦ 19<+65000. NEG ~ . 037 NEG NEG
19465000. NEG - .C39 NEG NEG
MSCC
Source Category
Charge Rate Unit
406000000
Petroleum Marketing & Transportation
1000 gal/yr
406001000
Rail and truck transportation
1000 gal/yr
406002000
Marine vessel transportation
1000 gal/yr
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES
SU^MA^Y OP MAJ3C CflTfGOCI£S
cXTESNA. COMBUSTION, 50ILIF: CATEGORY PAGE 1
ANNUAL CHA^GF
•RA TtS ANC MISSIONS
DROJECTFD TO
lOP?
-UK'
0 AT r" =
NOV 16,1977
MODIFIrD
see
TAC
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY
OF MAJ9P CATEGORIES
INTERNAL
COMBUSTION EhGINES
p AG^
ANNUAL CHAxG?
RATES ANC EMISSIONS
PROJEC TEO TO 1982
RUN
OATE =
NOV 16,1977
MOOIFIEO
see
T ACSF
( 3CC UNITS)
EMISSIONS (MILLIONS OF
NOX HC
TONS
CO
/ YEA*)
PAkT
?noonooan
. 553 .*446
.06 5
. C19
291000030
.259 .110
.019
. 0 14
201001000
201002000
201003000
201999000
13 5 0 {0 0 •
271340.
86009.
.149 . 002
.077 .000
.012 .001
.020 .107
.012
.00 0
.00 6
.002
. 010
. 000
. 002
. G02
MSCC
Source Category
Charge Rate Unita
200000000
Internal Combustion
201000000
Electric Generation
201001000
201002000
201003000
201999000
Distillate oil
Natural gas
Diesel
Miscellaneous fuel
1000 gal/yr
Million cu ft/yr
1000 gal/yr
N.A.
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 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY
Or MAJOR CATEGORIES
INTERNAL
G0T3USTICN ENGINES
DAGE
ANNUAL Oh'A^GE
'ATE S A N C EMISSIONS
P'.OJEC Tc C TO 19 82 3 UN
0 AT F =
NOV 16,1977
MODIFIED
T ACRF
EMISSIONS (MILLIONS
TONS
/ YEAR)
see
(SCC LNIT3)
N0X HC
CO
P AP T
202000000
• ° 9^ .335
.0^5
. 005
202001000
t-5273.
•015 .001
.392
.0 01
202002000
7e^<*70.
.276 .
.0 3 5
.003
202003000
5090.
.001 .001
.00 U
. 0 00
202004000
3^96.
.007 .001
.00 3
. C 00
202999000
36*61 .
.005 .263
.002
. 0 00
i
-X)
MSCC
Source Category
Charge Rate Unit
202000000
Industrial IC Engines
202001000
Distillate oil turbine
1000 gal/yr
202002000
Distillate oil reciprocating
1000 gal/yr
202003000
Natural gas turbine
Million cu ft/yr
202004000
Natural gas reciprocating
Million cu ft/yr
202999000
Miscellaneous fuels a
Million cu ft/yr
Although this category is made up of two MSCCs whose units are different,
only one (202999970) was studied.
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY OF MAJOR CATEGORIES
INDUSTRIAL PROCESS, CHEMICAL MANUFACTU^ING PAGE 1
ANNUAL CHARGE RATES ANC EMISSIONS FROJECTEC TO 1982 3UN 0ATE = NOV 16.1977
/ YEA5?)
MODIFIED
SCC
3 0100000 0
301002030
301003000
301005000
301999000
T ACS F
(SCC UMTS)
7^73800.
2988200*
6262100.
151180000.
NOX
NEG
NEG
NEG
NEG
NEG
EMISSIONS (MILLIONS OF TONS
HC CO
1 • 1M»
.256
. 038
.331
.518
2.81 5
.00 3
.056
2.^20
.33 6
PA FT
NFG
NEG
MEG
NEG
NEG
MSCC
Source Category
Charge Rate Unit
300000000
Industrial Processes
301000000
Chemical Manufacturing
301002000
Ammonia production with
Tons/yr
mcthanator
301003000
Ammonia production with CO
Tons/yr
absorber
301005000
Carbon black production
T ons/yr
301999000
Miscellaneous chemical
Tons/yr
manufacturing
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
iUMrtA'Y OF M4J0P, CAT EGO-IE S
INDUSTRIAL O'OTESS, PFIM\fV METALS PAGE 1
ANNUAL CHURC,'
?ATES fiSC tM!SJIONS
°?CJECTFn TO 1^52
-UN DATE =
NOV 16,1977
MODIFIEr
T ACSF
EMISSIONS ( PILL
IONS OF TONS
/ YEA ?1
see
tSCC LN1TS)
NOX H (
CO
OA RT
203000001
.013 ,19ft
5.71 e
. 6*. 6
30 3001000
23613001.
MEG Kr G
NEG
.0 27
393002000
9^56000.
NEG fEG
NEG
. 019
3 0 300 3000
458<*G0Q03.
.002 .
.056
. 02U-
30 300U000
1390000.
NEG .00 6
.00 1
. G u?_
303005000
NEG NEG
NEG
.312
303006000
•+O6&OU0.
NEG >'F G
NEG
. 0 22
30 3007000
27?0000.
NEG NEG
NEG
. 0 01
I
in
MSCC
Source Category
Charge Rate Unit
303000000
Primary Metals
N. A.
303001000
Aluminum reduction
Aluminum, tons/yr
303002000
Aluminum ore calcined
Tons/yr
303003000
Coke metallurgical
Coal, tons/yr
303004000
Coke beehive
Coal, tons/yr
303005000
Copper smelters
N. A.
303006000
Ferroalloy production (open furnace)
T ons/yr
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.
-------
Table i-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY OP MAJOR CATEGORIES
INDUSTRIAL
PROCESS, PRIMARY METALS
PAGE
ANNUAL CHANGE
RATES AND EMISSIONS
PROJECTFC TO
19 e? r<
UN OAT£=
NOV 16,1977
MODIFIED
TACxF
EMISSIONS
{MILLIONS
OF TONS
/ YEAR)
see
(SCC UNITS)
NOX
HC
CO
PART
3 Q 300 80 0 0
NEG
NEG
. 0 0 »
.125
303009000
136670003.
. 010
. C08
1.651
.0 19
303010000
6970000.
. 000
.000
NEG
. 004
303011000
KEG
KEG
NEG
. 006
303012000
65000.
MEG
f>EG
.000
NEG
303030000
155<»O0O.
NEG
NEG
NE G
.001
30 3999 GOO
36000000.
. 002
. 001
.00 2
MSCC
Source Category
Charge Rate Unita
303008000
Iron production
N. A.
303009000
Steel production
T ons/yr
303010000
l
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMM/W v
QF MAJTP CATIGOFIES
INDUSTRIAL PRCCESSt
seccnqa^ mstals
PAGE 1
ANNUAL CHA ?<»•
: ^A^es ANC EMISSIONS
P=OJ£CTEC TO 195-2 ?UN
DATE r
NOV 16,1977
MODIFIED
TAC~ F
EM
TSSICNS CMILLIONS OF
TONS
/ YE A3)
see
ISCC UNITS)
NOX
HC
CO
PA=>T
3Qi»000000
.030
. 017
.379
.072
sowooionn
£4222200.
.002
. 00 3
NEG
. 0 05
3 0<»002000
**512011.
.000
. 002
.365
.017
30*00<»0ar)
7 QCm^Q,
NEG
. 000
NEG
. 001
30t»00600Q
21830.
NEG
NEG
.00 0
NEG
sq<»QG7onn
17^20000,
• 25
. r,o<+
.0 10
.03*
30U009000
5 7 0^0 0 •
NEG
. oo<+
NEG
. 0 0(1
30U009000
10S0000.
NEG
NEG
.00 3
.000
3 0^*010000
1®C50.
NEG
r.EG
.0 0 0
NEG
3!)i* 020000
312350.
NEG
NEG
NEG
.000
30^050000
162S400.
NEG
.301
NEG
.000
304999000
12580000.
.002
• 00 2
NEG
.011
MSCC
Source Category
Charge Rate Unit
304000000
Secondary Metals
304001000
Aluminum operations
Tons/yr
304002000
Brass/bronze melt
Tons/yr
304003000
Gray iron
Tons/yr
304004000
Secondary lead smelting
Tons/yr
304006000
Secondary magnesium
T ons/yr
304007000
Steel foundry
Tons/yr
304008000
Secondary zinc
Tons/yr
304009000
Malleable iron
Tons/yr
304010000
Nickel
Tons/yr
304020000
Furnace electrodes
Tons/yr
304050000
Miscellaneous casting and
Tons/yr
fabrication
304999000
Miscellaneous secondary metal
Tons/yr
activity
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
i
(ji
SUMWY OF 1AJTR CATEGORIES
INDUSTRIAL PROCESS, MINERAL PPODUCTS
ANNUAL CHANGE
rtATES ANC EMISSIONS PROJECTED TO 13^2 RUN
DATF "
HCDI*IEn
TAC3F EMISSIONS ("ILLIQNS OF
TONS
see
(SCC UMTS) MO X HC
CO
3 05 000000
.306 .013
.050
305002000
.001
.00 3
305003001
MEG NEG
NEG
305005000
NEG NEG
NEG
305006000
. 078 NEG
NEG
305007000
.0^5 N'EG
NEG
3 05008000
.0 03 NEG
.001
305009000
NEG NEG
NEG
305010000
.005 NEG
.000
30501^000
.020 NEG
NEG
305015000
. 0 02 NEG
NEG
305016000
. 00<4 .000
.00 2
305018000
NEG NEG
NEG
305020000
.058 . CO 2
.012
305022000
NEG NEG
NEG
3O5O2«»OO0
NEG NEG
NEG
305025050
.031 NEG
.008
30 5999000
.017 .009
.023
MSCC Source Category Charge Rate Unit
PAGE
305000000
Mineral Products
305002000
Asphaltic concrete
Xons/yr
305003000
Brick manufacturing
T ons/yr
305005000
Castable refractory
Tons/yr
305006000
Cement manufacturing, dry
N. A.
305007000
Cement manufacturing, wet
N. A.
305008000
Ceramic/clay manufacturing
Tons/yr
305009000
Clay/fly ash sinter
Tons/yr
305010000
Coal cleaning
Tons/yr
305014000
Glass manufacturing
T ons/yr
305015000
Gypsum manufacturing
Tons/yr
305016000
Lime manufacturing
Tons/yr
305018000
Perlite manufacturing
Tons/yr
305020000
Stone quarry process
Tons/yr
305022000
Potash production
T ons/yr
305024000
Magnesium carbinate
Tons/yr
305025000
Sand and gravel processing
Tons/yr
305999000
Miscellaneous mineral products
N. A.
/ YEA *)
PART
6.397
.5 00
. 38?
. 002
.1*33
.27?
. 15 7
. 01 *~
. 063
. Cll
.068
.307
. 0 Ci
3.337
. 0*0
. 00
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY OF MAJOR C AT EGO - IES
INCUST.'UAL PROCESS, ^F Tf CLEUM PRODUCTS PAGC 1
ANNUAL CHA^G^ 3 A T ES ANC EMISSIONS PROJECTED TO 19^2 =UK O A T F = NOV 18,1977
MODIFIED
T AC ^ F
EMISSIONS
(MILLIONS
OF TONS f
YEA9)
see
(SCC IN ITS!
NCJX
HC
CO
p A RT
306000011
. 312
. U71
8.965
.209
3 06 001000
. 253
. '16 0
.0 3 9
.077
306002000
17F6000.
.059
. 183
• 8 2 6
. 102
306003000
5^60 0.
NEG
. 00 2
.100
NEG
306009030
31290000.
NEG
. 22 6
NFG
NFG
306012000
12*000.
MEG
MEG
NFG
. C3G
I
in
v\
MSCC
Source Category
Charge Rate Unit a
306000000
Petroleum Industry
306001000
Process heater
N.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
dL
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 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY
OF MAJOR CATEG
0 FIE S
I NQ
l J STRIAL
PROCESS, W009
D ~ 00ICT S
page
ANNUAL CHA3GF
RATES ANC EH
ISSIONS
OROJECTEC TO 1
9 52 R
UN DATE=
NOV 16.1977
MODIFIED
T AC 3 F
EHISSI ONS
(MILLIONS
CF TONS
/ YE4P)
see
(SCO UMTS)
NO*
HC
CO
PA»T
307000000
. 002
. 017
.398
. 239
307001001
NEG
NEG
.575
. 255
307002000
. 000
NEG
.021
. CQ6
307004000
13297000.
NFG
. 007
NEG
.001
307006000
3 9200 0.
NEG
. noi
NEG
NEG
30700^00(1
70520000.
.002
. C0h
.00 1
. 023
307008000
162^00000.
NEG
. 001
.001
. 0 21
307020000
26-0000.
NEG
. OOit
NEG
. 0 0J+
307999000
0.
0. 000 0
. noo
0.00 0
O. 0 00
MSCC
Source Category
Charge Rate Unit
307000000
Wood Products
307001000
Sulfate pulping
Tons/yr, air dried
307002000
Sulfite pulping
Tons/yr, air dried
307004000
Pulpboard mfg.
Tons/yr
307006000
Tall oil/rosin
Tons/yr
307007000
Plywood /particle board
Tons/yr
307008000
Sawmill operations
Tons/yr
307020000
Furniture manufacturing
Tons/yr
307999000
Miscellaneous wood products
Tons/yr
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY MAJ0P CATEGORIES
HYDROCARBON EVAF0RATT0N <=AGE 1
ANNUAL CHA 'Gr 3A T£S ANC EMISSIONS P^OJECTET TO 19 82 -UN GATE = NOV 16,1977
MCniFIE!0 TAC^F EMISSIONS MILLIONS OF TONS / YEAR)
SCC (SCC Li NIT SI NO X HC CO PART
<~00000000 NEC Z.258 NEC .012
<~01000000 MEG .136 NFG NEG
*~01001000 A3230. NEG . ntJ 1 MEG NEG
<~010020*10 H«»eOO. NEG .091* NEG NEG
*.01999000 133700. NEG .nil NFG NFG
-3
MSCC
Source Cate gory
Charge Rate Unita
400000000
Point Source Evaporation
N. A.
401000000
Cleaning Solvents
N. A.
401001000
Dry cleaning
Clothes, tons/yr
401002000
Degreasing
Solvent, tons/yr
401999000
Miscellaneous solvent use
Solvent, 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 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY
OP MAJOR CATEGORIES
hydrocarbon
"V CPOR AT ICN
PAGE 2
ANNUAL CHANGE
SATES AN C EMISSIONS
PROJECTFC TO 19 62
RUN
DATE =
NOV 16,
197 7
MCOI FIEQ
TACSF
EM
IS SI ON S (MILLIONS OF
TONS
/ YEAR)
see
ISCC UMTS)
NOX
HC
CO
PAPT
402000000
12516000.
NEG
1 . 330
NEG
.012
*~0 20 01000
634340.
NEG
. 118
NEG
NEG
**02002000
59^^200.
NEG
. 259
NEG
NEG
4Q 200 300 0
427530.
NEG
. 113
NEG
NEG
402004000
10 2 440•
MEG
.030
NEG
NEG
402005000
399150.
MEG
. 092
NEG
NEG
402006000
1378300.
NEG
. 293
NEG
NEG
402007000
16 66 ECO.
NEG
.241
NEG
NEG
402008000
231000.
NEG
. 056
NEG
NEG
402999000
1732200.
MEG
. 129
NET,
. 0 12
MSCC
Source Category
Charge Rate Unit
402000000
Surface Coating
Coating, tons/yr
402001000
Paint
Coating, tons/yr
402002000
Paper coatings
Coating, tons/yr
402003000
Varnish and shellac
Coating, tons/yr
402004000
Lacquer
Coating, tons/yr
402005000
Enamel
Coating, tons/yr
402006000
Primer
Coating, tons/yr
402007000
Fabric coatings
Coating, tons/yr
402008000
Oven coatings
Coating, tons/yr
402999000
Miscellaneous coatings
Coating, tons/yr
-------
Table 1-6-a. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES (Continued)
SUMMARY
OF MAJOR CAT
EGOr-IES
HYDROCARBON ^VflPOx
ATICN
paGc 3
ANNUAL ChA?GE
RATES ANC EMISSIONS
projected TO
19 82
RUN
DATF =
NOV 16,1977
MODIFIED
T AC9F
EMISSIONS (MILLIONS CF
TONS
/ YEA'?)
see
(SCC UNITS)
NOX
HC
CO
PAST
U03000000
NEG
. 326
NEG
N£G
<~03001000
NEG
. "32
NEG
NEG
<~03002030
NEG
. '17
NEG
MEG
403003COH
35860000.
NEG
. 157
NEG
NEG
*~03999000
15000000.
NEG
. 069
NEG
NEG
406000000
196220000.
NEG
. 296
NEG
NtG
<*0600 1000
83616000,
NEG
. 057
NEG
NEG
<~06002000
112600000
NEG
. 239
NEG
NEG
i
U1
v£>
MSCC
Source Category
Charge Rate Unit3,
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 & Transportation
1000 gal/yr
406001000
406002000
Rail and truck transportation
Marine vessel transportation
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 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY
SUMMARY OF MAJOR CATEGGRIES
EXTERNAL COMBUSTION, BOILER CATEGORY PAGE 1
T A CP AM) EMISSION UNCERTAINTIES PRCJECTE1 TO 1982 RUN OATE = NOV 16,1977
MODIFIED
TACRP
EMISSIONS
tMlLLIONS
OF TONS /
YEAR)
see
(SCC UNITS!
NOX
HC
CO
PART
100000000
+
1. 021
~
. 136
~ .113
~
1. 089
—
.969
-
.034
- .07 e
-
1. 094
101000000
+
.951
~
. 133
+ .099
¥
1. 016
—
. 927
-
. 024
- .066
-
1. 014
101002000
f
25840000.
*
• 926
*
. 132
. 09 k
~
1. 013
—
25567000.
-
. 926
-
. 019
- .062
1. 012
10100 4000
~
17150000.
~
. 213
~
. 021
*¦ .032
-f
.069
12302000.
-
. 045
—
. 015
- .022
.049
101005000
*¦
0.
¦f
3. 000
+
0. 000
+ 0.000
~
0. 000
-
0.
-
0. 000
-
0. 000
- 0.000
-
0.0 00
101006000
~
4 10340.
+
.030
«¦
.000
+ .00 6
~
.0 03
-
322310.
-
. 008
-
. coo
- .00 k
-
.002
101007000
15220.
~
. 000
MEG
NEG
NEG
-
15220.
-
.000
NEG
NEG
NtG
MSCC
Source Category
Charge Rate Unit
lOOOOOOOO
External Combustion (Boiler)
ioioooooo
Electric Generation
101002000
Bituminous coal
Tons burned/yr
101004000
Residual oil
1000 gal/yr
101005000
Distillate oil
1000 gal/yr
101006000
Natural gas
Million cu ft/yr
101007000
Process gas
Million cu ft/yr
-------
Table 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJJR CAT~GO-IES
EXTERNAL 2OM9USTI0N, 5CILrF rA TEGOFY
TACF AM E»: SSIOH UNCEFTAIMTES P^ltCTEl TC 198? RUN DATE = NOV 15,1977
"°SCCIE0 «sccAlnits> MO* E,,:sslCNt: millions of to^ / YE,5)
102000000 f ,3
r->
291 - . (2^
102002000 li»3C3000. + . 252 «. ^ Q?1
10200«*000 * 12U16600l ~ lloo ~ I 015
102005000 Z ^6 63£80• I I 073 I \Joe
102006000 f SlIIoS: ~ ;til ; :Soi
102007000 Z itUlt ~ : 000 *
1^2990. - .003 Seg
CO P a.-^T
127
+
• 0 5 <<
~
. 392
• DM
-
.*.12
4-
. o<* ?
+
. 591
—
. 03C
-
.^11
*
.319
f
. 02 3
—
.017
<•
.023
~
.007
~
.0 05
—
. 00 5
-
.0 05
+
.322
.00**
.015
-
» 0
MEG
NEG
MEG
NEG
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 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJ9P CATEGORIES
INTERNAL COMBUSTION ENGINES PAGE i
TACR AM3 EMISSION UNCERTAINTIES FRCJECTE9 TO 198?
-------
Table 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATEGORIES
INTERNAL COMBUSTION ENGINES
TACR AhO EMISSION UNCERTAINTIES PROJE^TE") TO 198?
RUN' DATE = NOV
modified
SCC
202000000
202001000
202002000
202003000
20200*»000
202999000
TAC=?P
(SCC UNITS)
£ 3<«20 .
60420.
6e?c.10,
3?2670.
2769.
2769.
26695.
2 € €9 5 •
13^61.
18^61.
10 X
EMISSIONS
. 153
. 120
. 003
. 003
. 153
. 119
.033
. 010
.005
. 005
.003
. 033
(MILLIONS
HC
. ?95
. 136
. 000
. 000
. OAO
. (30
. noo
. 000
. (10II
. COO
. 29?
. 133
OF
TONS /
CO
.02 9
.015
.001
. 00 1
.027
. 31 5
.00 4
.00 2
.002
.002
• 001
.001
Y£
PAGE
16.197 7
A3)
DART
. C05
.033
. oci
. a oi
.0 (15
.003
. 0 00
. 000
. oco
.000
. m
.000
MSCC
Source Category
Charge Rate Unit
202000000
202001000
202002000
202003000
202004000
202999000
Industrial IC 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 i-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY
OF MAJOR
CATE
GORIES
INDUSTRIAL PROC
ESS « CHEMICAL
VA NUF ACT UrING
PAGE 1
TACR ft NO
EMISSION UNCEfTAINTIES PROJECTED
TO 198? RUN
DATF =
NOV 16»1977
MODIFIED
TACSF
EMISSIONS
(MILLIONS OF
TONS
/ YEAR)
see
(SCC UNITS)
NOX
HC
CO
PAPT
301000000
NEG
>
. 12if ~
.2+67
NEG
NEG
—
. 115
• kh 0
NEG
301002000
~ 335720.
NEG
*
. 035 ~
. 001
NEG
335720.
NEG
-
. 035
.001
NEG
301003000
~ 79*80.
NEG
+
. 005 +
. 038
NEG
79980•
NEG
—
. 005
.038
NEG
301005000
+ 2 *»7220 .
NEG
~
. 099 ~
.<~69
NEG
2 *1630•
NEG
-
. 088
.U18
NEG
301999000
~ 17i*6^t0Q.
NEG
f
. 065 +
.129
NEG
17<*6<*000.
NEG
-
. €65
.129
NEG
MSCC
Source Category
Charge Rale 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 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continue
SUMMA?
Y OP MAJOP C AT r
GO-IFS
industrial
P'OCESS, FFIMARY METALS
PAGE
TflCC AW E MISS10 h UNCERTAINTIES
PPCJECTE1 TO 118? SUN
OATE"
NOV 16,1977
MCOlPIEt
T ACRF
EMISSIONS
(MILLIONS OF
TONS
/ YEA?)
see
(SCC IMTSI
NOX
HC
CO
PA FT
393000000
~ .004 ~
. nu9 +
4.217
+ .111
- .010
. 120
2.019
- . 113
303001000
«• 90 1 0 20 0 .
N w 3
NEG
NEG
~ .072
303002000
*~3 0730 0.
NEG
NFG
MEG
.015
«¦ 799700.
NEG
NEG
NEG
«- .003
303003000
799700.
NEG
NEG
NFG
• C09
~ 77840000.
~ .001 ~
.0^3 ~
.01^
+ .0 09
30300«*000
7 78^6003.
- .not
.120
• 0 3 F
. V! Q9
v 166*80.
NEG 4-
.001 +
.000
~ .042
303005000
1 €6*489.
NEG
. 004
. 000
. Q-+2
NEG
>EG
NEG
+¦ . 0 8 *+
303006010
NEG
NEG
NEG
- . . 054
~ 1727000.
NEG
NEG
NFG
~ . 0 ?0
303007000
17 Q4 £00.
NEG
MEG
NEG
.013
* 1032700.
NEG
NEG
N£G
*¦ .001
10 32 70 0.
NEG
NFG
NEG
- . o ni
MSCC
Source Category
Charge Rate Unita
303000000
Primary Metals
303001000
Aluminum reduction
Aluminum, tons/yr
303002000
Aluminum ore calcined
Tona/yr
303003000
Coke metallurgical
Coal, tons/yr
303004000
Coke beehive
Coal, tons/yr
303005000
Copper smelters
N. A.
303006000
Ferroalloy production (open furnace)
Tons/yr
303007000
Ferroalloy production (closed furnace)
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-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY CP MAJOR CATEGORIES
INDUSTRIAL PROCESS, PRIMARY METALS PAGE 2
TACP AKO EMISSION UNCERTAINTIES PRCJECTE1 TG 1982 RUN OATE= NOV 16,1977
MCOIFIEC
TACRF
EMIS
SI ONS
(MILLIONS
OF TONS /
YEAR)
see
CSCC UNITS!
NOX
HC
CO
PART
303008000
NEG
NEG
~ 2.765
+
. 047
NEG
NEG
- 1.519
-
. 061
303009000
*
22515000.
4-
. 00<*
4-
. 003
+ 3.181.
+
. 010
-
22515000.
-
.010
-
. 008
- 1.329
. 016
3Q301000n
~
17€9700.
+
. 000
. 000
NEG
+
. 003
-
1769700.
-
. 000
—
. 000
NEG
-
.003
303011000
NEG
NEG
NEG
~
.0 03
NEG
KEG
NEG
-
. 0 03
303012000
~
20880.
NEG
NEG
~ .00*
NEG
-
20890.
NEG
MEG
- .000
NEG
303030000
«-
372780.
NEG
hEG
NEG
~
. 0 01
tm
372780.
NEG
NEG
NEG
-
.001
303999000
+
85^000.
+
.000
~
. 000
~ .000
+
. 01W
85^4000.
-
. 002
-
. 001
- .002
-
.01^
MSCC
Source Category
Charge Rate Unit
303008000
Iron production
N. A.
303009000
Steel production
T ons/yr
303010000
l^ead smelters
N. A.
303011000
Molybdenum
N. A.
303012000
Titanium
N. A.
303030000
Zinc smelting
T ons/yr
303999000
Miscellaneous metallurgical processes
Tons /yr
aN. A. (not applicable) is listed under "Charge Rate Unit" where the MSCG
number is made up of two or more MSCCs whose charge rates are different.
-------
Table i-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY
0" MAJOR CATEGORIES
INDUSTRIAL
ACCESS, SECONDA
SY METALS
PAGE 12
TACP ANH r
MISSION UNCERTAINTIES
p=»0JECTET TO 1982
3UN
DATE =
NOV 16,
197 7
MCOIFIEC
TACRF
EMISSIONS
(MILLIONS
OF
TONS
/ YEAR)
see
(SCr UNITS)
NOX
HC
CO
PACT
3(11*000000
.014 +
. 00 2
*
.340
~
. 026
—
.014
. 005
.340
-
.030
304onioon
* 3 2110 0.
.000 *
. noo
NEG
+
. 0 03
3 2 110 Q .
-
. 001
. 001
MF G
-
.001
304002000
*¦ 79617.
«-
. 008 ~
. roo
Nc.G
~
.0 00
7 9 617.
-
.noo
. 000
Nt G
-
. o on
3 0 <*003000
~ 11 d0 800 0 •
+
. 010 +
. 001
+
.340
.011
11608000.
. ooa
. 002
.340
-
.on
304004000
~ 54591.
NEG ~
. noo
NFG
. 0 00
5 4 ?91.
NEG
. 000
NE C-
-
.000
304006000
~ 5096.
N~G
NEG
+
.001
NEG
5396.
NEG
NEG
-
.000
NEG
3 04 007 00 0
* 10 7 7 ?00 0 .
~
. 004 ~
. 001
~
.320
+
. 023
10779000.
-
.014
. 004
—
.10 1
-
. 027
304008000
«¦ 1 3 3 A90 .
NEG +
. 001
NEG
«¦
.000
133^90.
NEG
. 003
NEG
-
. noo
30 4009000
* 287310.
NEG
NEG
~
.010
~
.000
287310.
NEG
NEG
-
.002
*»
.000
MSCC
Source Category
Charge Rate Unite
304000000 Secondary Metals
304001000 Aluminum operations
304002000 Brass/bronze melt
304003000 Gray iron
304004000 Secondary lead smelting
304006000 Secondary magnesium
304007000 Steel foundry
304008000 Secondary zinc
304009000 Malleable iron
Tons/yr
Tons /yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
-------
Table 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SU,JMA°Y OF MAJOR CATEGORIES
INDUSTRIAL
ACCESS, SECONDARY
METALS
PAGE
TACR ANH E
MISSION UNCERTAINTIES
P^OJECTET TO 198?
RUN 0 AT E =
N0V 16,1977
MCOIFIEC
TAC^F
EMISSIONS
-------
Table 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OP" MAJOR CATEGORIES
INDUSTRIAL
P?CCESS,
MINERAL c£. 0 CUC T S
PAGE 1
TACP A NO F
MISSION uncertainties
CJE0Tc
TO l-id? -.UN
HATE =
NOV 16,1977
"CO I FIE0
T AC-rP
EM
ISS2CN5 (MILLION? CF
TONS
/ YE A°)
see
(SCC UNITS)
NOX
MC
CO
PAF T
305000000
*¦
. 050
«¦ .00^ ~
.313
+ 1.0*1
. 023
. c-nu
.00 8
- 1. Ik?.
305002000
~
. 011
. n00 *¦
.00 1
~ .359
3 0500 3000
—
. on
.000
. 00 0
. U 0 k
N ~ j
NEG
NEG
~ .116
305005000
NEG
NFG
NEG
. 1^5
NEG
NEC,
NEG
+ .0 01
NEG
NFG
NE C
.0 01
3050060m
. 012
N z. G
MEG
~ .322
3 0E0070T)
—
. 012
NEG
NEG
. 330
4-
. 010
NEG
NEG
~- . 2 30
3 0500300 0
-
.007
keg
NEG
- .236
~
.000
NEG +
.00 0
~ . 0 M
305009000
-
. 003
NEG
.000
.061
NET,
\'EG
NEG
*¦ .005
305010000
NEG
NEG
NEG
- .0 05
+
. not
NFG *
.30 0
~ . G23
—
. 001
f>EG
.on o
- . OhI
MSCC Source Category Charge Rate Unita
305000000
Mineral Products
305002000
Asphaltic concrete
Tons/yr
305003000
Brick manufacturing
Tons/yr
305005000
Castable refractory
Tons/yr
305006000
Cement mfg. , dry
N. A.
305007000
Cement mfg. , wet
N. A.
305008000
Ceramic/clay mfg.
Tons/yr
305009000
Clay/fly ash sinter
Tons/yr
305010000
Coal cleaning
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 1-6-b.
SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY CF MAJOR CATEGORIES
INDUSTRIAL PROCESS, MINERAL PRODUCTS
TACK AND MISSION UNCERTAINTIES PROJECTS! TO 1982 RUN (1 ATE =
MODIFIED
see
3O5O1UOO0
305015000
305016000
305018000
305020000
305022000
30502*»000
305025000
3 059^9000
TACRf
(SCC UNITS)
NOX
EMISSIONS
005
006
042
000
001
000
NEG
NEG
014
010
NEG
NEG
NEG
NEG
009
009
007
035
(MILLIONS
HC
NEG
NEG
NEG
NEG
. 000
. ^00
NEG
NEG
. GQ1
. 001
NEG
MEG
NEG
NEG
NEG
NEG
. QQU
. 00J+
OF TONS
CO
NEG
NEG
NEG
NEG
~ .001
- .00 1
NEG
NEG
~ .007
. 0 0 k
NFG
NEG
NEG
NEG
+ .003
- .002
~ .007
- .007
PAGE 2
NOV 16,1977
/ YE Aft)
PAPT
.003
. 0 03
. 0M
. 050
.237
. 28 5
.001
.001
.828
.910
. 0 18
. 020
.002
.002
. 179
. 179
0?2
072
MSCC
Source Category
Charge Rate Unit a
305014000
Glass mfg.
Tons/yr
305015000
Gypsum mfg.
Tons/yr
305016000
Lime mfg.
Tons/yr
305018000
Perlite mfg.
Tons/yr
305020000
Stone quarry process
Tons/yr
305022000
Potash production
Tons/yr
305024000
Magnesium carbinate
Tons/yr
305025000
Sand & gravel processing
Tons/yr
305999000
Miscellaneous mineral products
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 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF «AJQP CATEGORIES
INCU3T-:IAL P=>0HESS, 3ETFCLEUW PRODUCTS PAGE 1
TACR ANT EMISSION UNCEFTAI NTIES PROJECTED 7C 198? ?UH 0 A T t = NOV 16,1977
MCDIFIED
T AC*F
em:
S SIGNS
(> ILLIONS
OE
TONS /
YEAR!
see
(SCC LNITS)
NO*
HC
CO
PACT
30600000^
. 055
+
. 052
~
7.022
4
. 0 1?
-
. 0 15
-
. 052
-
7.32?
-
. 017
3H6oniono
~
.0X1*
4-
. 00 7
+
.00 7
f
.0 08
-
. 0 3*
-
. 00 5
-
.007
-
. n n<3
306002000
~
2 3^/fcO.
+
.009
~
. 026
~
7,021
4-
.0 is
«¦>
23<»7<*0.
-
. 013
-
. 026
-
7,021
-
. 0 15
336003000
*
29326.
NEG
~
. C01
~
. 054
MFG
-
23326.
NEG
-
. 001
-
.05 u
N?G
30 6008000
~
1911600.
NE3
~
. 0i*U
NEG
NFG
-
1911600.
NEG
-
. «]<~<~
MEG
NEG
30 6012000
~
16658.
NEG
NEG
NEG
.005
-
16659.
NEG
f£G
NEG
-
. 0 05
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 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY CP MAJOR CATEGORIES
INDUSTRIAL PROCESS, WCOO o-GDUCTS
PAGE
TACR ANT EMISSION
UNCEPTAINTIES PRCJECTEH TO
1982
RUN
DAT E = NOV 16,
1977
MODIFIED
TACRF
EMISSIONS (MILLIONS OF
TONS / YEAR)
see
(SCC UNITS)
NO*
H r
CO
P AFT
307000000
4-
. 009
~ . 001
f
• 6 8
. 170
—
.000
- . 001
-
.287
.2 03
307001000
NEG
MEG
+
• t* 68 ~
. 170
NEG
MEG
-
.28 7
.202
307002000
~
. 000
KEG
+
.00 5 ~
.001
-
. 000
NEG
-
.0 0 5
.0 01
30?00<*0tl0
~
387260.
NEG
~ . 000
NEG +
.0 00
367260.
NEG
.00 0
NEG
.00 0
307006000
~
S02i»9.
NEG
«- . 000
NEG
NEG
502<*9.
NEG
- . 000
NE G
NEG
307007000
~
3^0^80.
. 000
~ . too
~
. 00 0 +
.00^
ZkOUBO,
. 000
- . 000
-
.00 0
.0 0<+
307008000
~
0.
NEG
0.000
+
0.000 +
0.000
0.
NEG
- 0.000
-
0.000
. 017
307020000
¥
200000.
NEG
+ . 000
NEG +
.000
2G0000.
NEG
- . 000
NEG
.000
307999000
0.
0. 000
~ 0.000
~
0.000 ~
0. 000
•
0.
•
0.000
- 0.000
•
0.000
0. 000
MSCC
Source Category
Charge
Rate Unit
307000000
Wood Products
307001000 Sulfate pulping
307002000 Sulfite pulping
307004000 Pulpboard mfg.
307006000 Tall oil/rosin
307007000 Plywood/particle board
307008000 Sawmill operations
307020000 Furniture manufacturing
307999000 Miscellaneous wood products
Tons/yr, air dried
Tons/yr, air dried
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
Tons/yr
-------
Table 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
summary
- CATE
GO IrS
HY 0^OCA3 ~ ON -
\l flFCHATICN
PAGE 1
TftCP A MD EMISSION UNCERTAINTIES ?
90JECTE0
TC 1982
•r UN
0ATF =
NOV 16,1977
MODIFIPC
TACSF
EMI
SSI0N3
(vILLICKS CF
TONS
/ YEA®)
see
(SCO UMTS)
MO X
H C
CO
PART
400000000
MEG
+¦
.f 83
NEG
~ .003
N-G
—
. - 36
MEG
- .003
-niooooon
MEG
4-
. 104
NEG
NEG
MEG
-
. 18 8
NEG
NFG
401001000 «¦
35391.
NEG
~
. 00 6
NEG
NEG
-
22099.
MEG
—
. 000
NEG
NEG
401002000 ~
110720.
NEG
¦f
. 102
NEG
NEG
-
<=7663.
NEG
-
. 098
NE G
NEG
401999000 ~
34675.
NEG
«¦
. 018
NEG
NEG
34275.
MEG
-
. 011
NEG
N£G
MSCC
Source Category
Charge Rate Unita
400000000
Point Source Evaporation
N. A.
401000000
Cleaning Solvents
N. A.
401001000
Dry cleaning
Clothes, tons/yr
401002000
Oegreasing
Solvent, tons/yr
401999000
Miscellaneous solvent use
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 i-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATEGORIES
HYDROCARBON EVfPORATICN
TACR AfO EMISSION UNCERTAINTIES PROJECTED TO 198? RUN DATE =
MODIFIED
TACRP
see
(SCC LMTSI
NOX
*02000000
*¦ 75 €2 ^0 0 .
NEG
5501600.
NEG
<*02001000
~ e*£i*.
NEG
a* a*.
NEG
*02002000
~ 7563000.
NEG
5*7*<0Q.
MEG
402003001
~ 56378.
NEG
56378,
NEG
*0200*000
~ 261**.
NEG
*02005000
261**.
NEG
~ 10*260.
NEG
10*260.
NEG
*02006000
~ 183970.
NEG
*02007000
183970.
MEG
~ 107080.
NEG
107080.
NEG
*02008000
~ 65220.
NEG
65220.
NEG
*02999000
~ *70300.
NEG
*70300.
NEG
EMISSIONS MILLIONS OF TONS
HC
CO
.618
NEG
. 361
NEG
. 17*
NEG
. 08*
NEG
. 277
NEG
. 131
NEG
. 165
NEG
.085
NEG
. 033
NEG
. 017
NEG
. H98
NEG
. 053
NEG
. *53
NEG
. 218
NEG
. 125
NEG
. 186
NEG
. (62
NEG
. 03*
NEG
. 112
NEG
. 112
NEG
PAGE 2
NOV 16 * 197 7
/ YEAR)
PART
+ . 003
- . 003
NEG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
+ . 0 03
- .003
MSCC
Source Category
Charge Rate Unit
402000000
Surface Coating
Coating, tons/yr
402001000
Paint
Coating, tons/yr
402002000
Paper coatings
Coating, tons/yr
402003000
Varnish and shellac
Coating, tons/yr
402004000
Lacquer
Coating, tons/yr
402005000
Enamel
Coating, tons/yr
402006000
Primer
Coating, tons/yr
402007000
Fabric coatings
Coating, tons/yr
402008000
Oven coatings
Coating, tons/yr
402999000
Miscellaneous coatings
Coating, tons/yr
-------
Table 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY CF MAJ1P CATEGORIES
HYDROCARBON EV fPCRATICN PAGE 3
TACR AND EMISSIQf' UNCEKTAI MIES PROJECTED TC 1982 3 UN DATE = NOV 16,1977
EMISSIONS (MILLIONS OF TONS / YE A P)
MODIFIED
SCC
403000000
4 02001000
403002000
U03003000
4 Q399900H
T ACSF
(SCC UNITS)
~
9C4490.
90(4*90.
20100000.
15000000.
X
HC
CO
P APT
MEG
*¦
.179
NEG
NEG
NEG
—
• 189
NEG
NEG
NEG
4-
. 017
NEG
NEG
NEG
-
. 035
NEG
NEG
NEG
~
. 149
NEG
MEG
NEG
-
. 140
NEG
NEG
NEG
~
. 027
NEG
NEG
NEG
-
. 101
NEG
NEG
NEG
+
. t93
NE G
NEG
NEG
-
, 069
NEG
NEG
MSCC
Source Category
Charge Rate Unit1
403000000 Petroleum Storage
N. A.
403001000 Fixed roof
403002000 Floating roof
403003000 Variable vapor space
403999000 Miscellaneous storage
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 1-6-b. SUMMARY OF 1982 EMISSIONS AND CHARGE RATES UNCERTAINTY (Continued)
SUMMARY OF MAJOR CATEGORIES
HYDROCARBON EVAPORATION PAGE k
TACR AND EMISSION UNCEFTAINTIES PRCJECTE1 TO 198? ?UN QATE = NOV 16,1977
MOOIFIEC T ACS F EMISSIONS (MILLIONS OF TONS t YEAR)
see
(SCC UNITS!
NOX
HC
CO
PAPT
uoeoooooo
~
45022000.
MEG
4-
. 20 5
NEG
NEG
-
190 6500 0.
NEG
—
. 12 8
NEG
NEG
W06001000
17757000.
NEG
+
. 170
NEG
NEG
13908000.
N€G
-
. 035
NEG
NEG
<*06002000
*¦
41372000.
NEG
~
. 114
NEG
NEG
-
13068000.
NEG
-
. 123
NEG
NEG
MSCC
Source Category
Charge Rate Unit
406000000
Petroleum Marketing and Transportation
1000 gal/yr
406001000
Rail and truck transportation
1000 gal/yr
406002000
Marine vessel transportation
1000 gal/yr
-------
The major source categories summarized here are
further classified and detailed in Sections II through X.
1. 4 DATA ACQUISITION
1.4.1 Data Selected for Study
It was determined at the outset, by EPA, that this study
would be restricted to stationary sources of emissions and that the
emissions of interest were oxides of nitrogen (NOx), 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 processes 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 1-7 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 1-7 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 -77
-------
Table 1-7. STUDY LIST OF EMISSIONS*1
Percent of Total Stationary
Source Emissions
Source Category —
NO
X
HC
CO
PART
Utility Boilers
48. 4
0. 8
0. 8
23. 1
Industrial Boilers
9. 6
0. 9
1.0
9.8
Process Gas Combustion
0. 9
-
..
0. 1
Stationary IC Engine s^
2. 6
0. 5
0. 1
0. 1
Petroleum Industry
22. 6
9.7
13. 9
6. 6
Chemical Manufacturing
1. 1
22. 3
18. 4
1. 5
Evaporation
-
30. 8
-
0. 1
Primary Metals
0. 1
1. 1
24. 3
10. 1
Mineral Products
1. 4
0. 1
0. 1
25, 4
Secondary Metals
0. 1
-
4. 1
1. 1
Wood Products
0. 1
0. 2
2.8
2.9
Point Source Emissions Selected
for Study
86.9
66.4
65. 5
80.8
Remaining Point Source Emissions
-
3. 6
18. 0
4.7
Total Area Source Emissions
13. 1
30. 0
16. 5
14. 5
Total Stationary Source Emissions
100. 0
100. 0
100. 0
100. 0
aData extracted from Ref. i-4, dated January 1975.
^Internal combustion (IC) engines.
1 -78
-------
20 percent of all NOx from stationary sources originated from process
gas combustion. This information was supported by the large process
gas combustion rates listed in Ref. 1-4. Study of the actual data stored
in the NEDS (from a data tape) showed that large errors in the original
data for two users of process gases accounted for nearly all of the pre-
viously reported nationwide process gas usage rates and, therefore, for
nearly all of the reported NO^ 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 1-7.
The stationary internal combustion engines category,
although contributing only small quantities of emissions (Ref. 1-4), was
chosen because the NC>X 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
categories were selected because of the high emissions of NO , CO,
and HC. These categories are reported in Sections IV and V, respect-
ively.
Although the categories under study have been referred to
as NEDS categories, the NEDS was not the only source, or even in some
cases the major source, of original data. Extensive reviews of the
literature were also conducted to obtain other original data as well as
the rationale for projection of the data into the future. The data obtained,
consisting 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 -79
-------
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. 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 number of SCC categories accounted for nearly all of the
emissions of each type in the general category chosen for study. There-
fore, the total of emissions of some types for 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 considered 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 correspond-
ing 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 "neg" (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
1 -80
-------
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 for further review. Many cases were
found, in this manner, where the listed charge rates were 100 to 1000
times that considered reasonable for a large plant (in some cases even
larger than the entire national capacity). In most categories, no equiv-
alent 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 com-
paring 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 de-
creased 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-digit
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
1 -81
-------
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 of
1-01-002-02 identifies raw, original data stored for the category:
external combustion, boiler (1-xx-xxx-xx); electric generation
(1 -01 -xxx-xx); bituminous coal (1-01-002-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 fourth-level summary because the additional breakdowns
101002021 through 101002024 have 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 program at The Aerospace Corporation, then, represents
a careful and judicious sum from other sources as well as NEDS.
i- 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 hand-
ling. A total of 413 MSCC data categories have been defined for storage
of significant data. In each of the MSCCs, 40 separate items of infor-
mation must be entered into storage. In any particular MSCC, a
1 -82
-------
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 more than 16, 000 entries were entered into the program.
The general form of the data storage and handling program
is based on two major considerations:
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 were three years older at
the time of the first 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 un-
certain 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 pro-
jections can be evaluated as to their accuracy, a data storage and hand-
ling program was developed. As in the NEDS summary system,
emissions of each of the four air pollutants NOx» CO, HC, and PART
are calculated from charge rates and emission factors as shown in
eq. (1-1):
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.
1 -83
-------
For NO , CO, and HC emissions, the appropriate
emission 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 pro-
cesses represented by the MSCC. Since the degree of control may change
with time, either because of more effective control or more widespread
application of the same degree of control, the emission factor must be
projected into the future independently of the charge rates.
Particulate (PART) emissions, however, are normally
controlled by special hardware. Since these are recognizable pieces
of hardware with relatively well-established 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 cal-
culated from an uncontrolled emission factor for the process and 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, how-
ever, 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
1 -84
-------
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 storage 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 and stored in the data storage and handling pro-
gram. 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 cal-
culate emissions from the projected values according to Eqs. (1-1)
and (1-2). In this report, the current charge rate and emissions raw
data base are generated by projecting all of the data to the current year.
A further 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 then
1 -85
-------
from the energy shortage, make projections 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.
Even an estimate of the uncertainties in the data is
difficult because of the lack of data. Adequate data are not available
from a sufficient number of original sources that a reasonable statist-
ical estimate of uncertainty can be made. The use of small data sample
statistics results in unrealistically large uncertainties. Inmost 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 electrical demand and total installed electric-generating capacity
are reasonably widely studied and well documented. By using engineer-
ing judgment to set various realistic upper and lower bounds on less
well-documented data, such as a breakdown of electric-generating
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 description 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
1 -86
-------
in the data storage and handling program, and the program will not
allow the NO^, CO, or HC 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 pressure in all areas to reduce air
pollution, the assumption was made in this 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 un-
symmetrical uncertainties in projected data levels. For example, the
1977 NO emission for MSCC 101004000 is
x
0. 641 +q- HI (MILLIONS OF TONS PER 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 gen-
erate these estimates underlines the need to provide the user with the
documentation of the uncertainty of these data. These uncertainties
are not statistical quantities. It is necessary, 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 -87
-------
REFERENCES
Guide for Compiling a Comprehensive Emission
Inventory, revised, APTD-1135, U. S. Environmental
Protection Agency, Research Triangle Park, North
Carolina (March 1973).
Compilation of Air Pollutant Emission Factors, AP-42,
2nd ed. (and supplements), U. S. Environmental
Protection Agency, Research Triangle Park, North
Carolina (April 1973).
Compilation of Air Pollutant Emission Factors. AP-42,
U. S. Environmental Protection Agency, Research
Triangle Park, North Carolina (February 1972).
Nationwide Emissions Summary, National Emissions
Data System, U. S. Environmental Protection Agency,
Research Triangle Park, North Carolina (January 10,
1975).
W. U. Roessler, et al, Assessment of the Applicability
of Automotive Emission Control Technology to Stationary
Engines, EPA-65012-74-051, The Aerospace Corporation,
El Segundo, California (July 1974).
1-88
-------
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
xndustrial 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
8lngle stationary source of both oxides of nitrogen (NOx) and particulate
(PART) emissions. NO emissions of over 8 million tons per year repre-
aented about 59 percent of NOx emissions from all stationary sources and
akout 36 percent of NO^ emissions from all sources inventoried by the NEDS.
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-
°xide (CO) emissions from sources in this category represented less than
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,
inclading 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, for electric generation and various 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 NOx and PART, respectively, from the ex-
ternal combustion, boiler category result from the combustion of bitumin-
ous coal. Other fuel combustion which contributes significantly to the
emission of NO and PART includes that of natural gas and oil.
x
At the time that the fuels to be studied in this portion of the
inventory were selected, the then existing NEDS emission summary
(dated December 19, 1973) indicated that process gas combustion in in-
dustrial boilers and heaters was the source of 2. 6 million tons per year
13
of NO and resulted from the annual combustion of more than 2x10
x
cu ft/year of such 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 percent of the listed NO^ emissions from
process gas combustion. These errors have subsequently been corrected
in the NEDS data bank. The NEDS emissions 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 category was studied, however, it is in-
cluded 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
X
and PART generated 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 NC>x and PART, respectively,
from this category. The more general category of wood products, includ-
ing wood combustion, also represents a significant source of CO emissions.
2. 2 SUMMARY
The NEDS Source Classification Code (SCC) for external
combustion (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 1977 and 1982 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. The uncertainties in the
emission and charge rate data for 1977 and 1982 are given in Tables
2-2-b and 2-3-b, respectively.
2> 3 APPROACH
Study of fuel usage, emission factors, and projection data
ln the external combustion (boiler) category was initiated in this study
solely from the available literature. In many areas, however, the avail-
able data did not provide a sufficient breakdown of firing types nor sufficient
multiple sources to evaluate data accuracy (or uncertainty). As a result,
a c°mputer tape was obtained from the NEDS data bank containing card
1naages of all stored point source data for utility and industrial boilers,
(Continued on page 2-24)
2-3
-------
Table 2-1. Definition of External Combustion (Boiler) Processes
MSCC
Source Category
TACRP Unit
101000000
Utility Boilers
101002000
Bituminous coal
Tons/yr
101002010
>100 MMBtu/hr pulverized wet
Tons/yr
101002020
>100 MMBtu/hr pulverized dry
Tons/yr
101002021
Tangential firing
Tons/yr
101002022
Opposed firing
Tons/yr
101002023
Single-wall firing
Tons/yr
101002024
Vertical firing
Tons/yr
101002030
>100 MMBtu/hr cyclone
Tons/yr
101002040
>100 MMBtu/hr spreader stoker
Tons/yr
101002050
>100 MMBtu/hr overfeed stoker
Tons/yr
101002060
10 to 100 MMBtu/hr pulverized wet
Tons/yr
101002070
10 to 100 MMBtu/hr pulverized dry
Tons/yr
101002080
10 to 100 MMBtu/hr overfeed stoker
Tons/yr
101002090
10 to 100 MMBtu/hr underfeed stoker
Tons/yr
101002100
<10 MMBtu/hr overfeed stoker
Tons/yr
101002110
<10 MMBtu/hr underfeed stoker
Tons/yr
101002120
<10 MMBtu/hr pulverized dry
Tons/yr
101004000
Residual oil
1000 gal/yr
101004010
>100 MMBtu/hr general
1000 gal/yr
101004011
Tangential firing
1000 gal/yr
101004012
Opposed firing
1000 gal/yr
-------
Table 2-1. Definition of Externa.! Combustion (Boiler) Processes (Continued)
M SCC
Source Category
TACRP Unit
101004013
Single-wall firing
1000 gal/yr
101004014
Vertical firing
1000 gal/yr
101004020
10 to 100 MMBtu/hr general
1000 gal/yr
101004030
<10 MMBtu/hr general
1000 gal/yr
101005000
Distillate oil
1000 gal/yr
101005010
>100 MMBtu/hr general
1000 gal/yr
101005020
10 to 100 MMBtu/hr general
1000 gal/yr
101005030
<10 MMBtu/hr general
1000 gal/yr
101006000
Natural gas
Million cu ft/yr
101006010
>100 MMBtu/hr general
Million cu ft/yr
101006011
Tangential firing
Million cu ft/yr
101006012
Opposed firing
Million cu ft/yr
101006013
Single wall firing
Million cu ft/yr
101006014
Vertical firing
Million cu ft/yr
101006020
10 to 100 MMBtu/hr general
Million cu ft/yr
101006030
<10 MMBtu/hr general
Million cu ft/yr
101007000
Process gas
Million cu ft/yr
101007010
>100 MMBtu/hr general
Million cu ft/yr
101007020
10 to 100 MMBtu/hr general
Million cu ft/yr
101007030
<10 MMBtu/hr general
Million cu ft/yr
-------
Table 2-1. Definition of External Combustion {Boiler) Processes (Continued)
MSCC
Source Category
TACRP Unit
102000000
Industrial Boilers
102002000
Bituminous coal
Tons / yr
102002010
>100 MMBtu/hr pulverized wet
Tons/yr
102002020
>100 MMBtu/hr pulverized dry
Tons/yr
102002030
>100 MMBtu/hr cyclone
Tons/yr
102002040
>100 MMBtu/hr spreader stoker
Tons/yr
102002050
10 to 100 MMBtu/hr overfeed stoker
Tons/yr
102002060
10 to 100 MMBtu/hr underfeed stoker
Tons/yr
102002070
10 to 100 MMBtu/hr wet pulverized
Tons/yr
102002080
10 to 100 MMBtu/hr dry pulverized
Tons / yr
102002090
10 to 100 MMBtu/hr spreader stoker
Tons/yr
102002100
<10 MMBtu/hr overfeed stoker
Tons/yr
102002110
<10 MMBtu/hr underfeed stoker
Tons/yr
102002120
<10 MMBtu/hr dry pulverized
Tons/yr
102002130
<10 MMBtu/hr spreader stoker
Tons/yr
102004000
Residual-oil-fired
1000 gal/yr
102004010
>100 MMBtu/hr residual-oil-fired
1000 gal/yr
102004020
10 to 100 MMBtu/hr residual-oil-fired
1000 gal/yr
102004030
<10 MMBtu/hr residual-oil-fired
1000 gal/yr
-------
Table 2-1. Definition of External Combustion (Boiler) Processes (Continued)
MSCC
Source Category
TACRP Unit
102005000
102005010
102005020
102005030
Distillate-oil-fired
>100 MMBtu/hr distillate-oil-fired
1 0 to 100 MMBtu/hr distillate-oil-fired
<10 MMBtu/hr distillate-oil-fired
1000 gal/yr
1000 gal/yr
1000 gal/yr
1000 gal/yr
102006000
102006010
102006020
102006030
Natural-gas -fired
>100 MMBtu/hr natural-gas-fired
10 to 100 MMBtu/hr natural-gas-fired
<10 MMBtu/hr natural-gas-fired
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
Million cu ft/yr
102007000
102007010
102007020
102007030
Process gas-fired
>100 MMBtu/hr process gas-fired
10 to 100 MMBtu/hr process-gas-fired
<10 MMBtu/hr process-gap-fired
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. 1977 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES
E>TERNAl
COMBUSTION, EOILE
p CATEGORY
PAGE 1
ANNUAL CHANGE
RATES ANC EMISSIONS PROJECTED TO
1 9 77
PUN
DATE =
NOV 16,
1977
MCOIFIEC
see
TACSF
(SCC UMTS I
EMISSIONS
NOX
(MILLIONS OF
HC
TONS
CO
/ YEAR)
PART
10100 2000
tt366<40000.
5. 091
. 080
• 22 6
4. 281
101002010
101002020
<~8600000*
313260000.
.559
2. 851
. 00 7
. 057
.02*.
.157
.8 06
3. 099
101002021
101002022
101002023
10100 202<*
164 800000.
66500000.
65700000.
16260000.
1. 020
. 829
. 910
. 200
. 025
.010
. 010
. 012
.082
.033
.033
.00 6
1.630
. 658
.658
. 161
101002030
101002040
101002050
101002060
101002070
101002080
101002090
101002100
101002110
101002120
60000000.
5170000.
2730000.
190000.
1738000.
1160000.
37^0000.
1^0000.
0.
1896000.
1. 548
.035
.019
.002
• 016
. 008
.0 26
. 001
.000
.017
. 00 9
. 003
. C01
. 000
. coo
. 001
.002
. 000
. 000
. 000
.030
.005
.003
.000
.00 1
.001
.001*
.001
.000
.001
.212
. 098
.036
.006
.02«»
. 016
. C33
.001
.000
.051
101004000
24200000.
. 631
.024
.036
.097
10100<*010
23629000.
.617
.024
.035
.095
101004011
101004012
101004013
10100401
-------
Table Z-Z-a. 19 77 EXTERNAL, COMBUSTION EMISSIONS AND CHARGE RATES (Continued)
EXTERNAL COMBUSTION, EOILER CATEGORY PAGE 2
ANNUAL CHANGE
RATES AND EMISSIONS
PROJECTED TO
1977
RUN 0ATE =
NOV 16,1977
MODIFIED
see
TACRF
(SCC LNITSI
EMISSIONS
NOX
1 PILLIONS OF TONS
HC CO
/ YEAR)
PART
101006000
2597200.
. 415
. 001
.022
. 019
10100601Q
2551500.
.408
.001
.022
.ni9
101006011
101006012
101006013
10100601<«
675000.
1050000.
750000.
76500.
. 060
.187
.134
. 027
. 000
. 001
. 000
. coo
.006
.009
.006
.00 1
.005
.008
. 006
.001
101006020
101006030
45700.
0.
. 007
0.000
.000
0. coo
.000
0.000
.0 00
0. 0 00
181007000
9 0 290.
. 000
NEG
NEG
NEG
101007010
101007020
1010070 30
90390.
NEG
NEG
.0 00
NEG
MEG
NEG
NEG
NEG
NFG
NEG
NEG
NEG
NEG
NEG
10200 2000
107 9 1 0000.
1.043
. 050
.123
1,77i*
102002010
102002020
102002030
1020020 40
102002050
102002060
102002070
102002080
102002090
102002100
102002110
102002120
102002130
1272000.
14000800.
14530000.
25700000.
2730000.
11570000.
2790000.
0.
25900000.
3040000.
1290000.
1437000.
3650000.
.015
. 127
.375
.176
. 019
. 079
.030
0. 009
. 178
.012
. 001
. 013
.019
. 000
. 002
. 002
.013
. 001
. 006
. 000
0. 000
. 013
. 005
. 002
. 000
. 005
.001
.007
.007
.026
.003
.012
.001
0.000
.026
.01 5
.006
.001
.018
.019
.271
• 066
.491
.059
. 179
.122
0.000
• kkb
.017
.015
.057
. 0 33
10200^000
18220000.
. 328
. 027
.0«*2
. 210
1 0200
-------
Table 2-2-a. 1977 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES (Continued)
EXTERNAL COMBUSTION, TOILER CATEGORY
PAGE 3
ANNUAL CHANGE
RATES ANC EMISSIONS
P^OJECTEC TO
19 77
RUN OATE =s
NOV 16,
1977
modified
see
TACRP
CSCC UNITS)
EMISSIONS
NOX
(MILLIONS OF TONS
HC CO
/ YEAR)
P APT
10200<»0 30
3330000.
• 060
. 005
.00 7
. 038
10200 500 0
6720000.
. 121
. 010
.013
.050
100005010
102005020
102005C30
3120000.
1740000.
1660000.
. 056
.0 31
.033
. 005
.003
. 003
.00 6
.003
.00 <4
. 023
.013
.Oil)
102006000
5011000.
.386
. 008
• 0
-------
Table Z-2-b. 1977 EXTERNAL COMBUSTION UNCERTAINTIES
EXTERML COMBUSTION, BGILEP CATEGORY PAGE 1
TACK 4K0 EflSSIOt^ UNCE^TAI ^IES PRCJECTEO TO 1977 RUN 0 ATE = NOV 16,1977
i
HODIFIEC
SCC
101002000
101002010
101002020
101002021
101002022
101002023
10100202*.
101002030
1010020*0
101002050
101002060
101002070
101002080
101002090
101002100
101002110
101002120
Tfl CRP
(SCC UNITS)
9195800.
9146500.
1565200.
1565200•
8667300.
86 67 200.
8209800.
8209800.
i924zao.
1924200.
1924200.
1924200.
815U0.
815410.
1831000.
1831000.
6 52310•
692310.
152710.
152110.
56 (85.
56 (85.
661690.
661690•
660140.
680140.
663S10.
683S10.
680000.
140000.
680000.
0.
682060.
662060.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO PAPT
.449
. 449
.115
.115
. 324
. 324
.215
. 215
.170
.170
. 168
. 168
.042
. 042
.239
.289
. 008
. 908
. 003
. 003
.001
.001
. 007
.0 07
.005
. 0O5
. 007
. 007
. 003
.001
• 002
.000
• 007
. 007
. 110
. 016
. 006
. CO 4
. 110
. 01^
. 019
.012
.076
. 005
. 076
.005
. 009
. 001
. 00 7
.005
. 002
.002
. 001
. 001
.000
. 000
.000
. 000
.001
. 001
. 001
. 001
. 001
.000
. 001
. 000
. 000
. 009
.077
.052
.018
.01 2
.071
.048
• 062
.041
.025
.017
.025
.01 6
.006
. 00 U
.023
.015
.00 U
.003
.002
.001
.00 0
.000
.001
.001
.001
.00 1
.003
.002
.003
.001
.003
.00 0
.001
.001
-------
Table 2-2-b. 1977 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION, EOILES CATEGORY PAGE 2
TACR AfH EHISSIOf^ UNCEfTAINTIES FRCJECTEO TO 1977 RUN 0ATE = NOV 16,1977
MOOIFIEC
SCC
101004000
101004010
101004011
101004012
101004013
101004014
101004020
101004030
10100500 0
101005010
101005020
101005030
101006000
101006010
101006011
TACRF
(SCC UNITS!
4911500.
3609100.
1+015300.
3561400.
2011*300.
2014300.
2Q08100.
2008100.
2008100.
2003100.
2000000.
839000.
2000000.
420000.
2000000.
150700.
0.
0.
0.
Q.
0.
0.
0.
0.
127590.
125150.
116 500.
116500.
57271.
57271.
NOX
EMISSIONS (MILLIONS OF TONS / YEARI
. 195
. 141
• 1 31
. 141
.0 51
. 051
.085
.0 85
• 0 85
.085
. 126
.052
.051
. 011
.051
.004
0. 000
0. 000
0.000
0. 000
9.000
0. 000
0. 000
0. 000
.0 39
.039
• 038
.0 33
.009
• Q09
0
0
HC
.011
.098
.011
. 00 8
.007
. 005
. fl05
. 004
.(105
. 004
. 002
.001
. T102
.000
. 002
. 000
000
000
0.000
0. COS
O.OQQ
fl. 000
0. OOQ
0.000
. 001
.000
. 001
. 000
.000
. 000
CO
.017
.011
.017
.011
.011
.008
.00 8
.006
.008
.006
.003
. 001
.003
.001
.003
.000
0.000
0.000
9.00 0
0.000
0.000
0.000
0.000
0.000
. 009
.006
.009
.006
.004
.003
PART
-------
Table Z~Z-b. i977 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL C0M8USTION t FCILEf? CATEGORY PAGE 3
TACR A*Q EMISSION UNCERTAINTIES PROJECTED 10 1977 RUN 0 ATE = NOV 16,1977
MODIFIED
SCC
101006012
101006013
10100601*
101006020
10100 60 30
101007000
101007010
101007020
101007030
10 2002000
102002010
102002020
102002030
1020020^0
102002050
102002060
TACfiF
EMISSIONS (PILLIONS OF TONS / YEAR)
(SCC UNITS)
NOX
HC
CO
PART
E^Oi* •
~ .326
~
.000
~ .007
~ . 000
40^»
- . 026
-
. 00 0
- . 00 <4
- .000
58591.
*¦ .020
•f
. 000
* .00 5
~ . €00
58E91.
- .020
-
.00 0
- .003
- .0 00
52075.
+ .019
*
. 000
~ .001
~ .0 00
52075.
- .019
-
. 000
- .001
- . 000
52027.
~ • oia
~
. uoo
~ .001
~ .000
(~5700.
- . 097
-
.000
- .000
- .0 00
0.
~ 0.000
~
0 . (00
+ 0.000
+ 0.000
0.
- 0.000
—
0.009
- 0.000
- 0.000
15220.
+ .000
NEG
NEG
NEG
15220.
- . 000
NEG
NEC
NEG
15220.
+ .033
NEG
NFG
NEG
15220.
- . 000
NEG
NEG
NEG
NEC
NEG
NEG
NEG
NEG
KEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
hEG
NEG
NEG
NEG
NEG
228 3*00.
~ .0 92
~
.015
~ .03?
+ .252
2263400.
- .0 92
.015
- .023
- .252
636000.
+ . oos
~
. 000
~ .001
~ . 010
636000.
- .096
.000
- .000
- . 010
700000.
~ . 027
~
.00 2
~ .00 5
~ .062
700000.
- . 327
.001
- .09 U
- .062
726000.
~ .072
4-
.002
* .005
~ . 019
726000.
- .072
. 001
- .00 u
- .019
1290000.
~ .032
¥
.019
*¦ .319
+ . 127
1290000.
- .032
.010
- .013
- .127
136000.
~ .003
*
. 001
+ .002
~ .013
136000.
- . 003
.001
- .001
- .013
575000.
«¦ . 015
~
.Q0<»
~ .009
~ .0^6
579000.
- .015
-
. 0Q4
- .006
- .0^6
-------
Table 2-2-b. 1977 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION, BOILER CATEGORY PAGE 4
TACR ANO E*ISSlOf UNCERTAINTIES PROJECTED TO 1977 RUN DATE= NOl/ 16,1977
MODIFIED
SCC
102002070
102002080
102002090
102002100
102002110
102002120
102002130
102004000
102004010
102004020
102004030
102005000
102005010
102005020
102005030
102006000
TACSF
CSCC UNITS!
140000.
140000.
0.
0.
1300000.
1300000.
152000.
152000.
64000.
64000.
72000.
72000.
leoooo.
leoooo.
705210.
705210.
320000.
320000.
550000.
550000.
304000.
304000.
198130.
198130.
35009.
35000.
64000.
84000.
176000.
176000.
198130.
198130.
EMISSIONS I MILLIONS OF TONS / YEAR)
NOX HC CO PART
. 008
.008
0. 000
0. 000
.0 33
• 0 33
. 005
.005
.004
.000
.003
.003
. 013
. 013
. 125
. 125
.0 83
.083
.086
.0 86
. 038
. 038
.046
. 046
035
035
020
020
921
021
072
112
000
000
000
ooo
010
010
002
002
C01
C01
000
000
003
003
013
00 8
00 8
006
009
t06
004
003
005
003
004
002
002
001
002
001
004
00 2
.001
.001
0.000
0.000
.019
.013
.008
.008
.003
.003
.001
.000
.009
.009
.016
.013
.010
.007
• Oil
• Oil
• 005
.003
• 006
.004
.00 4
.003
.002
.002
• 003
.002
.020
.013
-------
Table 2-2-b- 1977 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION* SOILEP. CATEGORY
TACR AND FMISSIOh UNCE fTAINTIES PRCJ^CTEO 10 1977
RUM DATE =
MCOIFIED
see
102006010
102006020
102006010
102007000
102807018
10200 7020
102007030
TACSF
-------
Table 2-3-a. 1982 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES
EXTERNAL COMBUSTION* BOILS
R CATEGORY
PAGE 1
ANNUAL CHARGE
RATES AND EMISSIONS
P^OJECTEO TO
1962
RUN DATE =
NOV 16,1977
MODIFIED
TACRF
EMISSIONS
t MILLIONS OF TONS
/ YEAR)
see
(SCC LNITSI
MOX
HC
CO
PART
101002000
520000000.
4.767
.098
.272
4. 130
101002010
50350000.
.453
.00 8
.025
. 651
101002020
374410000.
2.746
. 068
.187
3. 028
101002021
196800000.
. 982
. 030
• 0 9
1.592
101002022
79500000.
.789
.012
.040
.643
101002023
78700000.
. 781
. ni2
.039
. 636
10100202*1
19410000.
.193
. C15
.010
.157
101002030
69000000.
1.418
.fllQ
.035
. 181
101002040
6920000.
.038
.00 3
.007
. 094
101002050
4480000.
.024
. CO 2
.004
.042
101002060
190000.
. 002
. 000
.000
.00U
101002070
2063000.
. 015
. 000
.001
.024
101002 C80
2930000.
. 016
. 001
.003
.032
101002090
6990000.
.039
. 003
.007
.045
101002100
390000.
. noi
. 001
.002
. 001
101002110
0.
.000
. 00 0
.000
. 000
101002120
2261000.
.817
. 000
.081
.327
101004000
31400000.
.115
.031
.047
. 126
101004010
30129000.
. 110
. 030
• 84 5
. 121
101004011
11910000.
. 043
. 012
.018
.048
101004012
8190000.
. 030
. CO 8
.012
.033
101004013
8190000.
.030
. 008
.012
.0 33
101004014
1839000.
. 007
. 002
.003
. 007
101004020
770000.
. 003
.001
.001
. 0 03
101004030
500700.
. 002
. 001
.001
.002
101005000
0.
0. 000
0.000
0.000
0. 000
101005010
0.
0. 000
0.000
0.000
0 . 000
101005020
0.
0. 000
0. 000
0.000
0. COO
101005030
0.
0. 000
0. 000
0.000
0. 003
-------
Table 2-3-a. 1982 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES (Continued)
EXTERNAL
COMBUSTION, BOILER CATEGORY
PAGE ?
ANNUAL CHARGE
RATES ANC EHISSIONS PROJECTED TO
1982
3 UN
D ATE =
NOV 16,1977
MODIFIED
TACRF
EMISSIONS
(MILLIONS OF
TONS
/ YEAR)
see
(SCC LMTS)
NOX
HC
CO
P APT
101006000
1232200.
. 031
. 001
.010
,0 09
101006010
1211500.
.0 30
. 001
.010
. C 09
101006011
325000.
. 008
.000
.003
.002
101006012
500000.
.013
. 000
.00 4
. 004
101006013
350000.
.009
. 000
.003
. 0 03
10100 601
36500.
. 001
. 000
.000
.000
101006020
20700.
.001
. 000
.000
.000
101006030
0.
O.OQO
0. 000
0.000
0. 000
101007000
90390.
. 000
NEG
NEG
NEG
101007010
90390.
. 000
NEG
NEG
NEG
101007020
NEG
NEG
NEG
NEG
NEG
101007030
NEG
NEG
NEG
NEG
NEG
102002000
li»539000Q.
1. 124
.066
.16 3
1.684
102002010
5277000.
. 047
.001
.003
. 058
102002020
1840 0000.
. 134
.003
.009
.281
102002030
19105000.
. 393
. 003
.010
.061
102002040
33800000.
.134
.017
.034
. <-63
102002050
3480000•
. 019
. CO 2
.00 3
.049
102002060
15220000.
. 083
.008
.015
. 147
102002070
3670000.
.0 32
. 001
. 00 2
.092
102002090
0.
0.000
0. 000
0.000
0. 000
102002090
3405 0000.
. 185
.017
.034
.392
102002100
3997000.
. 313
. C06
.020
. 022
102002110
1695000.
. 001
.003
.00 8
.017
102002120
1892000.
.014
. 000
.001
. 068
102002130
U800000.
. 020
.007
.024
. 037
102004000
21425000.
.078
. 032
.050
.246
10200401Q
8595000.
. 031
. 013
.017
.099
102004020
8915000.
.033
. 013
.025
.103
-------
Table 2-3-a. 1982 EXTERNAL COMBUSTION EMISSIONS AND CHARGE RATES (Continued)
OTERJVAL COMBUSTION, POILER
CATEGORY
PAGE 3
ANNUAL CHARGE
RATES ANC EMISSIONS
PROJECTED TO 1
982
*UN
0 ATE =
NOV 16,1977
MODIFIED
SCO
TACRP
CSCC UNITS)
EMISSIONS
NOX
(MILLIONS OF
HC
TONS
CO
/ YEAP)
PART
102004030
3915000.
.01<*
.006
.00 8
.0U5
102005000
790<*E00.
.0 29
.012
.016
.0 59
102005010
102005020
102005030
3670000.
20
-------
Table 2-3 -b. 1982 EXTERNAL COMBUSTION UNCERTAINTIES
EXTERNAL C0M3USTI0N, EOILER CATEGORY
PAGE
TACR ANO EMISSION UNCERTAINTIES PROJECT?! TO 198?
RUN DATE = NOV 16,1977
to
vO
MODIFIED
SCC
101002000
101002010
101002020
101002021
101002022
101002023
10100202*4
101002030
1010020<*0
1Q1Q02G50
101002060
101002070
101002080
101002090
101002100
101002110
101002120
TACSP
(SCC UNITS)
258^0000.
25567000.
2881800.
2821800.
2A72<«000.
2U72UOOO.
2^2 ^ 0000•
242^0000.
2 98^000.
296<»0Q0.
298*4000.
29€^000.
2^22200.
2i»22200.
292<»eQ0.
292^800.
2383500.
238 3 f00.
^<=3780.
**93780.
126*00.
126 <<0 0.
23 80500.
2083000.
2380000.
2380000.
2381100.
2381100.
2380000.
3<=0000.
2380000.
0.
2380 COO.
2261000•
EMISSIONS (MILLIOhS OF TONS / YEAR)
NO X HC CO PACT
.926
. 926
. 219
. 219
. 618
. 613
. '~16
. U16
.319
.319
.316
.316
. 081
.081
. 653
. 653
.022
. 022
.012
. 012
. 001
.001
. 018
. 015
. 015
. 015
. 022
.022
. 003
. 001
. 006
. 000
. 019
.017
.132
. 019
.006
. 00*»
. 131
. 017
.023
. 015
.391
. 00 6
. 091
. CO 6
.011
. 002
.008
.005
. 003
. 003
. 002
. 002
. 000
. 000
. 000
. 000
. 002
. 001
. 003
. 00 3
. 00*t
. 001
.001+
. 000
. 000
. 000
.09 i
.062
.019
.013
.086
.05 8
.075
.351
.030
.120
.030
.02 0
.007
.00 5
• 02 €
.017
.00 6
.00 k
.003
.002
.00 0
.ooc
.001
.001
.003
.003
.006
.00 b
.012
.002
.012
.090
. 001
.001
-------
Table 2-3-b. 1982 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION, BOILER CATEGORY PAGE 2
TACR AND EMISSION UNCERTAINTIES PROJECTED TO 1982 RUN 0ATE = NOV 16,1977
EMISSIONS (MILLIONS OF TONS f YEAR)
MODIFIED
see
101004000
101004010
101004011
101004012
101004013
10100401*
101004020
101004030
101005000
101005010
101005020
1010050 30
101006000
101006010
101006011
TAC5F
-------
Table 2-3-b. 1982 EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION, ECILER CATEGORY
TACR AND EHlSSIOh UNCERTAINTIES PROJECTED TO 1982 RUN DATE =
HCOIFIEC
SCC
101006012
101006013
1Q100601<<
101006020
101006030
101007000
101007010
101007020
101007030
102092000
102002010
102002020
102002030
1020020*0
102002050
102002060
TACSF
(SCC UNITS)
185920.
1£5920#
163990•
163990.
162020.
36500.
182010.
20700.
0.
0.
15220.
15220.
15220.
15220.
KEG
NEG
NEG
NEG
14 393000.
14393000.
4050200.
4050200.
4554100.
4554100.
45 S 8200.
4558200.
8103300.
8103300.
eeoeio.
860610.
3655600.
3695600.
EMISSIONS
W)X
HC
.023
~
. 000
.005
—
. COO
.016
~
. 000
. 005
-
. 000
.006
~
. 000
. 001
—
. 000
.005
~
. 000
.001
-
.000
0. 0Q0
O.UOO
0. 003
—
o. noo
.000
NEG
.009
NEG
.000
NEG
. 000
NEG
NEG
NEG
NEG
NEG
MEG
NEG
NEG
NEG
.262
. 021
.261
.021
• 043
~
. 001
.043
. 001
• 064
t
. 002
. 064
.002
.293
~
. 002
.203
. 00 2
. 096
*
. 013
.096
.013
• 010
~
• 001
• 010
. 001
.043
+
. 006
.043
-
. 006
OF
TONS
CO
• 0 0 <4
.00 3
.003
.002
.002
.000
• 00 2
.00 0
o.ono
o.oo o
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
.045
• 03 4
.003
.002
.007
.00 5
.00 8
.00 5
.027
.019
.003
.002
.012
.008
PAGE 3
NOV 16,1977
f YEAR)
PACT
.001
.001
.001
.001
.001
. 03(1
.001
.000
1.003
I. COO
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
. 291
.<~11
.t}49
. 049
.136
.135
. 032
.032
. 216
.216
. 026
.027
.080
.088
-------
Table 2-3-b. 198Z EXTERNAL COMBUSTION UNCERTAINTIES (Continued)
EXTERNAL COMBUSTION, BOILER CATEGORY PAGE 4
TACR EMlSSIOf UNCEFTAI hTIES PROJECTED TO 1962 RUN DATE = NOV 16,1977
/ YEAR)
MODIFIED
SCC
102002070
1020020%0
102002090
102002100
102002110
102002120
102002130
102004000
102004010
102004020
102004030
102005000
102005010
102005020
102005030
102006000
TACRP
-------
Table 2-3-b. 1982 EXTERNAL COMBUSTION XJNCERTAINTTES (Continued)
EXTERNAL COMBUSTION, ECILEF; CATEGORY PAGE 5
TACK AK) EMISSION UNCERTAINTIES PROJECTEO TO 198? RUN OflTE= NOW 16,1977
MODIFIED
TACRF
EMIS
SIGNS
(MILLIONS
OF
TONS /
YE Aft)
see
CSCC IMTSI
N0X
HC
CO
PAPT
102006010
* 6276^.
* .113
~
. 003
~
.016
~
.0 01
8276<*.
- . 073
-
. 002
-
.011
-
.001
102006020
~ 198CM1.
+ . 09**
*¦
. 002
4-
.013
~
.002
1*86^0.
- .062
-
. 902
—
.009
-
.002
102006030
~ t»0«730.
+ .052
«•
. 001
~
.007
*
. 00<*
W0C73O.
- .038
—
. 001
—
.006
-
.00<«
102007000
~ 1*42990 •
4- . 009
HEG
NEG
NEG
1<*2990.
- .003
KEG
NEG
NEG
102007010
~ 125700.
+ .080
NEG
NEG
MEG
125700.
- . 000
NEG
NEG
NEG
102007020
~ 68100.
~ . 000
NEG
NEG
NEG
68100.
- . 000
NEG
NEG
NEG
102007030
~ 2 €00.
+ .008
NEG
NEG
NEG
2800.
- . 000
KEG
NEG
NEG
-------
SCC 1-01-001-01 through 1-02-999-99 (see Gefs. 2-2 and 2-3 for definition
of terms and SCC categories). It was necessary to write computer pro-
grams 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 was received. The NEDS tape data were
used as a second data source, both to accomplish 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 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 sub-
divided according to the fuels selected for study within this category,
which are represented by 58 MSCC categories. In order to accomplish
the type of linear projections into the future, with cited uncertainties, as
described in Section I, a total of 40 distinct input numbers had to be
generated for each MSCC. Thus, for this category alone, more than 2, 000
separate data entries had to be considered.
In general, initial efforts were made, from data in the
literature, 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 uncertain-
ties in current data levels. Methods of projecting data into the future
could only be derived from the literature and other unpublished data sources.
All data sources were also used to estimate uncertainties in the projection
methods and the resulting projected levels. The resulting data level
estimates and uncertainties were then used to derive the linear slopes and
the uncertainties in these slopes.
2-24
-------
Since the literature search and analyses of data from the
literature provided a major source of current data and the only source
of projection data and methods, these data and analyses are discussed in
depth in Section 2.4. 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. 5.
2. 4 DATA ANALYSIS FROM LITERATURE
Data in the literature can be divided into the source cat-
egories of utility boilers and industrial boilers. Data concerning these
two sources are sufficiently different, both in depth and type, that separ-
ate 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 conducted separately.
2. 4. 1 Fuel Usage, NQ^., HC, and CO Emissions in and
from Utility Boilers
An Edison Electric Institute (EEI) survey (Ref. 2-4) of
several 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 follows: 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
operating 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 ar-
bitrarily limited to utilities with power capability exceeding 400 MW,
This was done for reasons of manageability. The average proportions of
2-25
-------
annual usage of each fuel as reported for these stations (coal/oil,
oil/gas, coal/oil/gas) were acquired. In the analysis, data were weighted
to account for differences in fuel heating values. The proportional
statistics for adjusted fuel consumption and breakdown by firing type were
then used to develop a summary breakdown expressed 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
12
electric energy value of 1.43 x 10 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 per-
cent, 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 emission inventory by boiler firing type.
The emission projections involved establishment of
expected fuel usage figures for 1980 (Ref. 2-8). However, current drastic
changes in socioeconomic conditions may strongly affect actual overall
electric energy demand by 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.
2-26
-------
Consideration was given to recent trends showing that
Combustion Engineering, supplier of tangential furnaces, has shown in-
creasing market penetration and is currently reported (Ref. 2-14) to
be controlling about 50 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 projected fuel usage breakdown, reflecting these considerations,
is based on the assumption that one half of the new construction 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
the projections.
The new construction is expected to fulfill the EPA national
emissions requirements already legislated (Ref. 2-15). It is further
anticipated that improvements in existing units will be forthcoming.
Exploratory efforts concerning the feasibility of reduced NOx by means
°f combustion modifications have shown promise m 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 conducted in this field are reported in References
2-18 through 2-20.
For all coal-fired furnaces, it was assumed that the 1980
NOx emission factors could be reduced by 25 percent from the 1973
factors listed in Reference 2-11. NO emission factors estimated for
c°al in 1980 wefce 13. 5 lb/ton for all pulverized firing and 41 lb/ton for
cyclone furnaces. The 1973 NO emission factors for gas and oil, con-
verted to parts per million (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 NOx
emissions in both gas - and oil-fired utility boilers at least to 200 parts
2-27
-------
per million. On the assumption that this technology is currently avail-
able and will be widely implemented by 1980, NO emission factors of
3 ^ X
36 lb/10 gal of oil and 250 lb/10 cu ft of gas in all firing types were
estimated.
Although there is little we 11-documented information 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 experiencing 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
reasons, 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. Considering 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 emissions from external combustion
boilers are low and usually well below the limits of any foreseen regu-
lations. For this reason, no effort was made to project changes in HC
and CO emission factors. In all cases in this category, HC and CO
slopes were considered equal to zero.
2. 4. 2 Fuel Usage, NO^, HC, and CO Emissions in and from
Industrial Boilers
The three major pieces of information needed to calculate
the industrial boiler emissions are the installed boiler capacity, the con-
sumption of each type of fuel, and the emission factors. Within the time
constraints of this study, only a limited literature search and a survey
of potential information sources were possible. For boiler capacity
data, the only source located was Reference 2-21, in which were several
2-28
-------
tables based on information in Reference 2-22. In those tables, in-
dustrial 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 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 196Y data given in Ref. 2-22 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,
was possible 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 con-
sumption.
Next, the total fuel consumption derived for 19?3 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
0l* such an estimate, taking into account the energy supply situation; how-
ever, 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 boilers and conversion of existing units, with
a- smaller rise in oil consumption and a decrease in natural gas use. A
r°ugh guideline was the fuel breakdown given in Ref. 2-23 for 1950 when
coal was widely used in industrial boilers. A further consideration was
*
KPPH = thousands of pounds of steam per hour.
2-29
-------
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 cal-
culated using the emission factors of Ref. 2-11. Emission factors for
NO from gas-fired boilers, given in Ref. 2-11 for industrial boilers,
X ^
range from 120 to 230 lb/10 cu ft from the smallest to the largest
boilers Rather than trying to interpolate and use multiple factors, an
arithmetic average of 175 was applied to the total gas consumption.
Since NOx emissions from natural gas combustion represent only about
20 percent of the total, an error in using an average emission factor
should not significantly affect the total emissions.
In estimating probable NOx emission factors for 1980,
it was noted that there are currently no NO^ regulations for industrial
boilers other than for new units larger than 250 million Btu/hr heat in-
put but that some sort of control appears likely in the near future. Much
of the NO^ control technology developed for utility boilers should be
directly applicable, but the larger question concerns the degree to which
new regulations will be met in industrial boilers by 1980. For the 1980
projections, it was assumed that the NOx emission factors for coal
firings will be reduced by 25 percent (as in the case of utility boilers)
but that NOx emissions from gas and oil-firings will be reduced by 50
percent, rather than the 58 to 65 percent reduction which appears likely
for utility boilers A summary of the 1973 NOx emission factors and
those assumed in this study for 1980, for both utility and industrial
boilers, is as follows:
2-30
-------
Emission
Partnr
Utilities
Industrial
Fuel
Jm CI V. U U JL
Unit
Use
1973
1980
1973
1980
Coal
lb / ton
General
18
13. 5
18
13. 5
lb/ton
Cyclone
55
41
55
41
lb/ton
Stoker
-
-
15
11. 25
Oil
lb/1000 gal
Tangential
50
36
40
20
lb/1000 gal
Other
105
36
80
40
Natural
lb/million cu ft
Tangential
300
250
180
90
Gas
lb/million cu ft
Other
600
250
180
90
As in
the utility boiler category, HC and CO emissions
were considered
currently satisfactory, and the 1980 emissions factor used were unchanged
from those of Ref 2-11-
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 general pulverized coal category and the more
specific firing categories of stoker and cyclone. For each of these cat-
egories, the annual PART emissions can be calculated from the product
of five factors: (1) coal usage rates, (2) average weight percent of ash
in the coal, (3) ash factors, (4) average collector efficiencies, and (b)
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
2-31
-------
Ref. 2-25 for industrial boilers The values of percent ash, ash factors,
collector efficiencies and control application factors (2) through (5)
used to calculate 1967 to 1973 PART emissions in this analysis were as
follows:
Utility Boilers
Boiler
Ash
%
Collector
Control
Net
Type
Factora
Ash
Efficiency
Application
Control
Pulverized
lb
11. 9
0. 92
0. 97
0. 89
Stoker
13
112
0. 80
0. 87
0. 70
Cyclone
3
11. 8
0. 91
0. 79
(M
o
Industrial Boilers
Pulverized
16
10. 6
0. 85
0. 95
0. 81
Stoker
13
10. 2
0. 85
0. 62
0. 53
Cyclone
3
10. 3
0. 82
0. 91
0. 75
For the utility boiler projections 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 con-
struction was assumed to be 100 percent.
In the industrial boiler area, EPA standards of perform-
ance for new stationary sources (Ref. 2-15) require control efficiencies
of about 0. 988 (based on allowable emissions of 0. 1 lb/million Btu 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
3r
The ash factor multiplied by the percent of ash yields the uncontrolled
emission factor.
2-32
-------
boilers of smaller capacity are currently forecast, and the control
efficiencies and application (net control) therefore, were assumed to
be constant
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 efficiencies or control applications. Even on the assumption of
100 percent uncontrolled gas - and oil-fired utility and industrial boilers,
the PART emissions projected for gas - and oil-firing represent less
than 7 percent of the total from these sources PART emissions from
gas- and oil-fired utility boilers were considered uncontrolled in all
time periods. Controls for industrial boilers were treated the same
except that new construction 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. 2-15
2.4.4 Update of Charge Rate Data
Emissions from external combustion (boiler) sources,
as projected during the first year of the inventory, are quite uncertain.
Part of the reason for this uncertainty is the age of the data base (1973
and earlier) but the primary cause is the redistribution of boiler fuel
usage among coal, oil and gas fuels resulting from oil and gas shortages.
The following paragraphs describe the analysis and rationale used to
update the data base for boilers in the charge rate (fuel usage) area-
Emission factors were assumed already sufficiently accurate.
2.4.4.1 Utility Boilers
Reference 2-30 lists the annual consumption rate of
fossil fuels (coal, oil and gas) used for nationwide electric generation
through 1975. This data was used to update the data base for utility
boilers firing bituminous coal, residual oil and natural gas. Other
utility boiler fuel categories such as distillate oil and process gas con-
tribute insignificant emissions.
2-33
-------
The 1975 values for fuel usage rate were distributed
among the respective boiler categories in the same proportion as had
been observed in the initial (1975) data base. The distribution of fuel
usage among three boiler sizes as defined in the initial data base com-
pared favorably with the distribution shown for the same categories in
Ref. 2-31. The boiler sizes for which comparisons were made included:
(1) less than 10 million BTU per hour, (2) between 10 and 100 million
BTU per hour, and (3) greater than 100 million BTU per hour. More
than 95 percent of the utility boiler fuel was fired in the 3rd category
( >100 x 10^ BTU/hr), for each of the three fuel types (coal, oil and
gas).
Although the 1975 fuel usage data in Reference 2-30
was marked as "preliminary", they are considered quite accurate
(<5 percent uncertainty) because little change was observed between
preliminary values published in previous years and the revised values
published in this (1975) document. Also, good agreement was noticed
between Ref. 2-30 data and that published in other independent sources.
Therefore, the charge rate uncertainty was set at 3 percent of the
nominal value.
The slopes of the charge rates for total coal, oil and
gas were set equal to the typical annual growth rates cited in Ref. 2-30
over the last several years. These slopes, for utility boilers, are
listed below:
Years of Effective
Fuel Observation Slope, %
Coal 1970 - 1975 +3.9
Oil 1970 - 1975 +6.0
Natural
Gas 1971 - 1975 -10.7
These values for the changes in total fuel charge rates
with time were then apportioned among the various utility boiler sub-
categories in proportion to the subcategory charge rates.
2-34
-------
Uncertainties in these slopes, or projections into the
future, are, of course, still quite large. This is primarily a result of
uncertainties in the shift between fuels which might be implemented in
the near future to satisfy the energy demand.
2.4.4.2 Industrial Boilers
Reference 2-31 lists firing rates for several industrial
boiler sizes for each of the fuels of interest. Since the installed
capacity of industrial boilers is large compared to the new installation/
retirement rates, the relative distribution of usage among boiler sizes
and fuel types is expected to be about the same in 1977 as reported in
Ref. 2-31 for 1971. Appendix C of Ref. 2-32 describes the growth
rates of coal, oil and natural gas usage in industrial applications
(based on actual data until 1974 and estimated data for later years).
These growth rates are shown below:
__ Annual Growth Rates, %
Fuel 1971-1972 1972-1974 1974-1977
Coal -1.7 -5.6 +6.3
Oil +2.3 +2.0 +3.3
Natural
Gas +4.3 +2.3 +2.1
Annual charge rates for 1975 were estimated by pro-
jecting the 1971 charge rate data from Ref. 2-31 using the annual
growth rates from Ref. 2-32 (the above table). Charge rates calculated
in this manner for 1975 were then compared with those previously
derived for the same year in this study. Agreement between these two
values were excellent for coal usage but differed by 44 and 73 percent
for oil and natural gas usage, respectively. Those two estimates were
combined to develop new estimates of charge rates and uncertainties
for the three fuels for 1975. Charge rates for 1977 and subsequent,
then, were projected from the new 1975 levels using the projected
annual growth rates from Ref. 2-32.
2-35
-------
Although the individual fuel usage rates for industrial
boilers may dip or rise drastically during the next few years, the
combined firing rate of all three fuels should rise at a relatively con-
stant rate. Although the data in the above table shows that the growth
rate for coal usage in industrial boilers ranged from a 5. 6 percent
decrease in 1973-1974 to a 6. 3 percent increase in 1975-1977, the total
industrial boiler firing rate growth ranged only from +0. 6 percent to
+3. 3 percent over the same period, with an average of 2. 3 percent per
year.
2. b 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 (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 literature 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 considered desirable to
obtain a magnetic tape of data stored in the NEDS system for analysis.
The availability of these in-house data on tape allowed extensive com-
puter analysis and represents a powerful tool for emission 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. Com-
paring 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.
2-36
-------
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
13
too high by factors of as much as 1000 (a total error of more than 2x10
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 excessively small values, however, Aerospace was
unable to 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 recorded 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. 2-33).
From the 1972 compilation to the 1973 compilation (Ref. 2-11), there were
some very large changes. Those important to this study are listed below:
2-37
-------
Emission Factor Ratio,
Fuel
Plant Type
Emiss ion
1973/1972
Coal
None
-
-
Oil
Utility
CO
75. 0
Industrial
CO
20. 0
Natural Gas
Utility
NO
X
1. 538
Utility
HC
0. 025
Utility
CO
42. 5
Industrial
HC
0. 075
Industrial
CO
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.
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 emission totals calculated in this manner showed reason-
ably 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)
2-38
-------
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 emissions during gas
firing may be higher for a significant period of operation if it was pre-
ceded 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
performance. 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. 6 REFERENCES
2-1. Nationwide Emissions Summary, National Emissions Data
System, U. S. Environmental Protection Agency, Research
Triangle Park, North Carolina (January 10, 1975).
2 -2 . Guide for Compiling a Comprehensive Emission Inventory,
U. S. Environmental Protection Agency, Research Triangle
Park, North Carolina (March 1973).
2-3. Guide for Compiling a Comprehensive Emission Inventory,
Revised, APTD-1135, U. S. Environmental Protection
Agency, Research Triangle Park, North Carolina (March
1973).
2-39
-------
Unpublished Edison Electric Institute tabulation of utility-
boilers by firing type, fuels, and megawatt capacity
(May 1973).
Keystone Coal Industry Manual, McGraw Hill Book Co. ,
Inc. , New York (1973).
Semi-Annual Electric Power Survey, Nos. 53 and 54,
Edison Electric Institute, New York (1973).
"Annual Statistical Report, " Electrical World (March 15,
1973).
The 1970 National Power Survey, Federal Power Commission,
Washington, D. C. (December 1971).
"The 18th Steam Station Cost Survey, " Electrical World
(November 1, 1973).
"The 1973 Annual Plant Design Report, " Power
(November 1973).
Compilation of Air Pollutant Emission Factors. AP-42,
2nd ed. (and supplements), U. S. Environmental Protection
Agency, Research Triangle Park, North Carolina (April
1973).
Systems Study of Nitrogen Oxide Control Methods for
Stationary Sources, GR-2-NOS-69> Esso Research and
Engineering Co. (November 1969).
"Controlling NOx Emissions from Steam Generators, "
Journal of the Air Pollution Control Association,
23 (1), 37 (1973).
"New Generating Capacity, " Power Engineering, 77
(4), 40 (April 1973).
Federal Register, 36. Part II (December 1971).
"Utility Boiler Operating Modes for Reduced Nitric Oxide
Emissions, " Journal of the Air Pollution Control Associ-
ation, 21 (11) (November 1971). ———
"Operation of Scattergood Steam Plant Unit 3 Under Los
Angeles County Air Pollution Control District Rule 67 for
Nitrogen Oxides Emissions, " Inter society Energy Conver-
sion Engineering Conference Proceedings, Society of
Automotive Engineers, New York (1971).
2-40
-------
2~18- w- Bartok, et al, Systematic Field Study of NO Control
Methods for Utility Boilers. ESSO Research an
-------
2-27. Minerals Yearbook, Vols. land 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, 11 Electric World
(October 1970).
2-30. Edison Electric Institute Statistical Year Book of the
Electric Utility Industry, No. 43, Publication No.
76-51 (October 1976).
2-31. Evaluation of National Boiler Inventory, Battelle Columbus
Laboratory, Columbus, Ohio (October 1975); NTIS No.
PB -248 100.
2-32. 1976 National Energy Outlook, FEA-N-75/713, Federal
Energy Administration, Washington, D.C. (February
1976).
2-33. Compilation of Air Pollutant Emission Factors. AP-42,
U. S. Environmental Protection Agency, Research
Triangle Park, North Carolina (1972).
2-42
-------
SECTION in
STATIONARY INTERNAL COMBUSTION ENGINES
3- 1 INTRODUCTION
Stationary internal combustion (IC) 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
°r 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
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 source)
for most types of stationary engines is not much larger than point source
°nly, four engine-fuel combinations were identified where area source emis-
®ions 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
^escribed in Section 3. 3; Section 3.4 describes the assessment of the engine
Categories that make significant contributions to both area and point source
ei*Ussions.
3-1
-------
3.2 SUMMABY
The point source stationary IC engines studied along with their
modified source classification code (MSCC) numbers and MSCC charge rate
units are listed in Table 3-1. The point source charge rates and emission
rates for the two sample years are shown, respectively, in Tables 3-2-a
and 3-3-a and their uncertainties in Tables 3 -2-b and 3-3-b.
By the 1980's point source 1C engines will contribute about one-
half million tons per year of both nitrogen oxides (NO ) and hydrocarbons (HC)
and 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
x
tons of CO. The largest contributor to stationary IC engine pollution is the
conventional gasoline engine.
3. 3 POINT SOURCES
This category includes 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 3-10)
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
1000 gal/yr
201002010
Natural-gas-fueled turbine
Million cu ft/yr
201002020
Natural-gas-fueled reciprocating
Million cu ft/yr
201003010
Diesel-fueled reciprocating
1000 gal/yr
201999970
Other, not classified
Million cu ft/yr
201999980
Other (not classified)
1000 gal/yr
202000000
Internal Combustion (Industrial)
202001010
Distillate-oil-fueled turbine
1000 gal/yr
202002010
Natural gas turbine
Million cu ft/yr
202002020
Natural gas reciprocating
Million cu ft/yr
202003010
Gasoline reciprocating
1000 gal/yr
202004010
Diesel reciprocating
1000 gal/yr
202999970
Other (not classified)
Million cu ft/yr
3-3
-------
Table 3-Z-a. 1977 INTERNAL COMBUSTION EMISSIONS AND CHARGE RATES
INTERNAL
COMBUSTION
ENGINES
PAGE
ANNUAL CHANGE
RATES ANC EMISSIONS
PROJECTEC TO
19 77
RUN DATE =
NOV 16,1977
MODIFIED
see
T ACS f
(sec UMTS)
EMISSIONS (PILLIONS OF TONS
N0X HC CO
/ YEAR)
PA FT
201001000
1163100.
. 129
. 002
.010
.008
201001010
1163100*
. 129
.002
.010
.008
201002000
319*70.
. 091
.001
.000
.000
2 01002010
201002020
10894Q•
210630.
.019
. 072
. 001
0.000
.000
0.000
.000
0.000
201003000
78259.
.011
. 001
.805
.002
201003010
78259.
.011
. 001
.00 5
.002
201999000
.018
.090
.002
.001
201999979
201999<80
7590.
125600.
.011
• 006
. 012
. 078
0.000
.002
0.000
.001
202001000
7U73.
. 004
. 000
.002
.001
202001010
71473.
. 004
.000
.002
.001
202002000
914110.
. 327
. 084
.041
.00
-------
Table 3-2-b. 1977 INTERNAL COMBUSTION UNCERTAINTIES
INTERNAL COMBUSTION ENGINES PAGE 1
TACR AM) E*IS
IOh UNCERTAINTIES
PROJECTEH TO
1977
RUN
DATE =
NOV 16,
19 77
MODIFIED
TACRF
EMISSIO
NS (MILLIONS OF
TONS
/ YEAR)
see
(SCC UNITS)
NOX
HC
CO
PART
2niooiooo
33 6 *00 0•
~ . 374
+ .nos
~
.030
+
• 025
1163100.
- . 129
- . 002
-
.010
-
. 008
201001010
336*000.
~ . 374
~ . 005
~
.030
~
. 025
1163103.
- .129
- .002
-
.010
.008
201002000
418290.
~ .«73
+ . 002
~
.00 3
+
. 001
113670.
- .022
- . 001
.000
.000
201002010
417030.
* .072
~ .002
+
.003
~
.001
108940.
- .019
- . 001
.000
. ooo
201002020
32*61.
+ .011
~ 0.000
4-
0.00 0
+
0. 000
32*61.
- .011
- 0.000
0.000
0. 000
201003000
16026.
+ .003
~ . 000
~
.002
. 0C1
16026.
- .002
- . 000
.001
.001
201003010
16026.
~ .003
+ . 000
~
.00?
~
.001
16026.
- . 002
- . 000
.00 1
. 001
201999000
~ . 004
* .017
•f
.000
«•
. 001
- .004
- .017
.000
.001
20 1999 <70
2302.
~ .003
~ . 004
~
0.000
~
0. 000
2302.
- .003
- . 004
0.000
0.000
201999<80
26925.
~ .001
«• . 017
.000
•f
.001
2652 5.
- . 001
- . 017
.000
. 001
202001000
33032.
«¦ .002
~ . 000
~
.001
~
.003
33032.
- .002
- .000
.001
. 009
202001010
23032.
* . 002
~ . 000
•f
.001
.0 00
33032.
- .002
- . 000
. 00 1
.000
202002000
631 <<00.
~ .121
~ .032
.02*
~
.005
—
211690.
- . 076
- .019
-
.010
-
. 004
-------
Table 3-2-b. 1977 INTERNAL COMBUSTION UNCERTAINTIES (Continued)
INTERNAL
COMBUST ION
ENGINES
PAGE
TACR AND
EPISSIC^ UNCEPTAI MIES
PROJECTED TO
1977
PUN 0ATE=
NOV 16,
1977
H CDIFIEO
TAC«?P
EMISSIONS (MILLIONS
OF TONS
/ YEARJ
see
(SCC UNITS)
NOX
HC
CO
PAPT
202002010
+ 597C60.
~
. 09i»
. 025
~ .022
+
.0 0<*
60f6fi.
-
.010
. 002
- .002
-
. 000
202002020
~ 202750.
+
.076
. 021
~ .010
~
. 03<»
202750.
-
. 076
. 019
- .009
-
.0 0^
202005000
~ 1626.
+
.009
. 000
~ .003
+
. 0 09
1 €26.
—
.000
. 080
- ,001
-
.000
202003010
* 1626.
+
.0 00
. 000
~ .00 3
+
. 0 00
1626.
.009
. COO
- .001
• 000
202001*000
~ 26177.
~
.005
. 000
~ .00 2
~
. 000
26177.
.005
. 000
- .002
.000
20200^010
* 26177.
.005
. noo
~ .002
~
.000
26177.
.005
. 000
- .002
.000
202999000
~ <^53,
~
. 001
. 207
~ .00 0
+
.000
9U53.
.001
. 068
- .000
.000
202999^70
~ 9<453.
*
.001
.20 7
~ .300
+
.000
9^53 •
-
. 091
- . 068
- .000
-
.0 00
-------
Table 3-3-a. 1982 INTERNAL COMBUSTION EMISSIONS AND CHARGE RATES
INTERNAL
COMBUSTION r
NGINES
PAGE 1
ANNUAL CHARGE
RATES ANC EMISSIONS
PROJECTED TO
1982
RUN 0ATE =
NOV 16,1977
MODIFIED
see
TAC«F
(SCC IMTS)
EMISSIONS
NOX
MILLIONS OF TONS
HC CO
/ YEAR)
P APT
201001000
13 5 0(00.
. 149
. 002
.012
.010
201001010
1350600,
. 149
.002
.012
. 010
201002000
271240.
.077
. 000
.000
. 0 00
201002010
201002020
91680.
179660.
.016
. 061
. 000
0. 000
.000
o.ooq
. noo
0.000
201003000
86009.
.012
. 001
.006
.002
201003010
86009.
.012
. 001
.006
. 002
201999000
.020
. 107
.002
. 0 02
201999970
201999980
8421.
150600.
.013
. 007
. 014
. 093
0.000
.002
3.000
.0 C2
202001000
85273.
. 005
. noi
.002
. 0 fl
202001010
65273.
• 005
. 001
.002
.001
202002000
764<«70.
. 276
. 070
.035
. 003
202002010
202002020
39133.
72471*0.
. 096
. 270
. 002
. 069
.001
.0 33
. 000
.0 03
202003000
5090.
. 001
. 001
.00 4
.0 00
2 0 200 3010
5090.
.001
, 001
.00 <4
.000
2 02004000
39396.
.007
.001
.003
.000
202004010
39396.
.007
.001
.003
.000
202999000
36561.
.005
. 263
.002
. 000
202999970
36561.
.005
. 263
.002
. 0 00
-------
Table 3-3-b. 1982 INTERNAL COMBUSTION UNCERTAINTIES
INTERNAL
COMBUSTION E
NGTNES
PAGE
TACR AM) EMISSION UNCERTAINTIES
PR0J5CTE1 TO 198 2 RUN
0 ATE =
NOV 16,1977
MCDIFIEC
TACRP
EMISSIONS
-------
Table 3-3-b. 1982 INTERNAL COMBUSTION UNCERTAINTIES (Continued)
INTERNAL CO*8U~TION ENGINES PAGE 2
TACR A hO
EMISSICH
UNCERTAINTIES
Pf?
CJECTEO
TO 1982
RUN DATE =
NOV 16,1977
MOOIFIEC
see
TACPF
(SCC INITS)
EMI
NOX
S 51ONS (MILLIONS OF TONS
Hr CO
/ YEARI
PAPT
20200 2010
202002020
*
4-
m
6cee*o.
39733.
320210.
320210.
«-
4-
.0 96
. 006
. 119
. 119
~ . 025
- . 002
~ .031
- . 030
~ .023
- .00 1
+ .015
- .015
~ . CO*
- .000
~ .0 03
- .003
20200 3000
4-
2769.
2769.
4-
. 000
.000
~ . 000
- .000
~ .00 *
- .002
~ .000
- .009
202003010
2769.
2769.
4-
. 000
. 000
~ .000
- .000
~ .00^
- .002
* .000
- .0 CO
20200*000
t
26695.
26695.
4-
. no5
. 005
~ . 000
- .000
~ .002
- .002
~ . oco
- .000
202004010
~
26 €95.
26695.
4-
. 005
.005
~ . 000
- . 000
+ .00 2
- .002
+ . 0 CO
- .0 00
202999000
~
1S*61.
18*61.
+
. 003
.003
~ .292
- . 133
*¦ .001
- .00 1
~ .noo
- . coo
202999 <70
4-
13*61.
18*61.
4-
. 00 3
.003
~ .292
- . 133
~ .001
- .001
+ .000
- .000
-------
For electrical generation, diesel engines represent 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
3-10
-------
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
°perate 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.
•*•3.4 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
lndustrial use, the assumption was made that charge rate trends for these
turbines are equal to those for electrical power demand. For turbines used
ln the handling of petroleum products in such services as pumping and pres-
®Urization, it is also reasonable to assume that the same trends exist as for
*ke electric utility consumers.
For reciprocating engines, it was necessary to use less direct
Methods of estimating charge rate changes. Table 3-4 shows data on the
dumber of IC engines versus end use for gasoline and diesel fuels. Only
those listed in the source (Ref. 3-4) for construction, generator sets, or
Berieral industrial use were considered in this part of the study. Of the
6ngines produced (Table 3-4), many were probably for replacement of
3-11
-------
1,320 TOTAL FUEL DEMAND
THOUSANDS OF
BARRELS PER DAY
180
RESIDUAL
960
120
CRUDE
560
760
280
150
570
"~6fT JET/KEROSENE
480
DISTILLATE
350
320
300
280
150
260
NATURAL GAS
(1000 barrel equivalent)
200
170
180
190
1972)
1973
1975
CALENDAR YEAR
1977
1979
Figure 3-1. Electric utility gas turbine fuel demand
3-12
-------
Table 3-4. INTERNAL COMBUSTION ENGINE DISTRIBUTION:
NUMBER VERSUS END USE
Engine Type Number of IC Engines Distributed''
and End Usea
W
U>
1965 1966 1967 1968 1969 1970 1971 1972 1973 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 67,769 76,678 67,930 67,798 90,760 86,264 104, 142 146,270 165. 183 176,014
Sets
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 130, 185 140,021 134,665 139,577 156,329 142,266 130,216 150,823 175,071 200,054
and General
Industrial Use
Generator 13,209 12,746 5,564 6,070 8,535 10,201 8,400 9,661 13, 327 15,212
Sets
Total Diesel 143, 394 152.767 140,299 145,647 164,864 152,467 138,616 160,484 188,398 215,266
Total IC 1,383,999 t.535.598 1,400,27t 1,452,721 1,680,414 1,464,473 1.416,936 1,282,991 1,753,381 1,663,831
Engines
aRef, 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 percent of pro-
duction going into new installations. Hence, the assumption of a change of
charge rate based on 10 percent of the annual production seems conservative,
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 factors
(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 1-6-a shows the 1982 projections of annual charge rates
and emissions for point sources. The data show that about one-half million
tons per year of both NO and HC are produced by stationary IC engines. Of
this amount, about 50 percent of the NOx and 25 percent of the HC are from
electrical generating plants, with the remainder from industrial sources. In
the electrical generating category, the worst offender is the distillate-oil-
fueled turbine (201001010). With a charge rate of over 1. 35 billion gal/year,
it contributes about 150, 000 tons /year of NO^. In the industrial use class-
ification, natural gas reciprocating engines (202002020) contribute about
270, 000 tons/year of NO from about 725 billion cu ft/year of gas.
3-14
-------
3.4
TOTAL EMISSIONS FROM SELECTED STATIONARY IC
ENGINES (POINT AND AREA SOURCES)
3. 4. 1 Introduction.
As reported in Section 3. 1, four stationary IC 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 3-5 shows the total emissions for these engines in 1980.
Table 3-6 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
^~4.3.1 Turbines
In 1971, the installed horsepower for gas turbines was about
^8 million. About 29 million of that was for electrical power generation, and
remainder was for pipelines and natural gas processing. For power gen-
cation, 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,
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- 15
-------
Table 3-5. 1980 PROJECTION OF TOTAL INTERNAL
COMBUSTION ENGINE EMISSIONS51
Emissions, million
Source Category Charge Rate,
NOx HC CO gal/yr
Distillate-Fueled Turbines 0.459 0.011 0.060 6.70X 10^
Crude-Oil-Fueled 0.884 0.022 0.116 12.90 X 106
Turbines
Gasoline-Fueled 1. 345 0.924 13, 273 12.75 X 106
Reciprocating Engines
Diesel-Fueled
Reciprocating Engines
Diesel-Fueled 0.432 0.032 0.142 2. 40 X 106
Total 3. 120 0.989 13.591 34.75 X 106
aPoint source and area source emissions.
3-16
-------
Table 3-6, 1980 PROJECTION OF AREA SOURCE INTERNAL
COMBUSTION ENGINE EMISSIONS
Emissions, million
c ^ . tons/yr Charge Rate,
Source Category innn 1/
NO HC CO 1000 gal/^r
Distillate-Fueled Turbines 0.313 0.009 0.047 5. 34 X 106
Crude-Oil-Fueled 0.884 0.022 0.116 12.90 X 106
Turbines
Gasoline -
Reciprocating Engines
Diesel-Fueled
Reciprocating Engines
Total 2.955 0.985 13.566 33.26 X 106
Gasoline-Fueled 1.344 0.923 13.269 12.74 X 106
Diesel-Fueled 0.414 0.031 0.134 2.28 X 106
3-17
-------
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 3-4 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.
3-18
-------
c. Specific fuel consumption is 0. 40 lb/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 lb/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 3-4 shows the number of IC 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 lb/bhp-hr) is 12. 75-
Mllion-gal/year. Gasoline density of 6.0 lb/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 3-5. The data indicate that
about 3-million tons of i —million, tons of HC, and 13. 6-million tons of
(mainly from gasoline engines) will be emitted from these engines.
Table 3-6 is the same data minus the point source data. This shows an
estimate of the area source pollution.
3-19
-------
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 IC 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)-i,
U.S. Bureau of the Census, Washington, D. C. (1975).
3-5. V. DeBia9i, "Double Standard on Fuel Oils Would Favor
Steam over Gas Turbine Plants, " Gas Turbine World
(September 197 3).
3-20
-------
SECTION IV
CHEMICAL MANUFACTURING
4- 1 INTRODUC TIQN
The emission sources discussed in this section are classified
^der 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 (NOx), hydrocarbons (HC),
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
ej*iission equations is described in Section I, Data Handling. Chemical manu-
facturing processes studies are defined according to the National Emissions
•^ata System (NEDS) Source Classification Code (SCC) and, in Table 4-1, by
'He NEDS Modified Source Classification Code (MSCC) developed by The
-Aerospace Corporation for this study.
4,2 SUMMARY
Chemical manufacturing production rates and emissions are
^®fined for two sample years and are listed in Tables 4-2-a and 4-3-a with
the respective uncertainties in the production and emission data listed in
Tables 4-2-b and 4-3-b. Table 4-1 describes the process and production
*ate (charge rate) unit for each MSCC for which emissions were determined.
(Continued on page 4-9)
4-1
-------
Table 4- 1. DEFINITION OF CHEMICAL MANUFACTURING PROCESSES
MSCC
Source Category
Charge Rate
Unit
301002010 Purge gas in ammonia plant with methanator
301002020 Storage and loading in ammonia plant with
methanator
301003010 Regenerator exit in ammonia plant with CO
absorber
301003020 Purge gas in ammonia plant with CO absorber
301003030 Storage and loading in ammonia plant with CO
absorber
301003990 Miscellaneous processes in ammonia plant with
CO absorber
301005010 Channel process carbon black production
301005020 Thermal processes carbon black production
301005030 Gas-fired furnace process carbon black
production
301005040 Oil-fired furnace process carbon black
production
301005050 Gas- and oil-fired furnace process carbon
black production
301005991 SIC 2952 sector of miscellaneous carbon black
processes
301005992 SIC 3624 sector of miscellaneous carbon black
processes
301005993 SIC 3999 sector of miscellaneous carbon black
proces ses
301005994 SIC 2899 sector of miscellaneous carbon black
processes
301005995 All other SICs of sector of miscellaneous
carbon black processes
301999991 SIC 2818 sector of miscellaneous chemical
manufacturing
301999992 SIC 3999 sector of miscellaneous chemical
manuf a ctu r ing
301999993 All other SICs of sector of miscellaneous
chemical manufacturing
Tons/yr
t
""Standard industrial classification (SIC). The product description
corresponding to each SIC is given in Ref. 4-1.
4-2
-------
Table 4-2-a. 1977 CHEMICAL MANUFACTURING EMISSIONS AND CHARGE RATES
INDUSTRIAL PROCESS, CHEMICAL MANUFACTURING PAGE 1
ANNUAL CHANGE
RATES ANC EMISSIONS
PROJECTED TO
1977
FUN OATE =
NOV 16,1977
MODIFIED
TAC9F
EMISSIONS
(MILLIONS OF TONS
/ YEAR)
see
(SCC UNITS)
NOX
HC
CO
PART
301002000
6*96800.
kfg
.223
.003
NEG
3010020H1
5570200.
NEG
• 223
.003
NEG
301002020
926600.
MEG
0. 000
o.o o n
NEG
301003000
2598800.
NEG
. 033
.049
NEG
301003010
818200.
NEG
. 001
.049
NEG
301003020
790400.
NEG
.032
0.000
NEG
301003030
590400.
NEG
O. 000
0.000
NEG
301003«90
3=9800.
NEG
. 000
0.000
NEG
301005000
6119M10.
NEG
.324
2.292
NEG
301005010
118*00.
NEG
. 105
.475
NEG
301005020
231 680.
NEG
. 000
.00 3
NEG
301005030
33398.
NEG
.029
.088
NEG
301005040
516060.
NEG
. 108
.579
NEG
301005050
673300.
NEG
. 074
1.092
NEG
301005990
*~546600.
NEG
.009
.85?
NEG
301005*91
4005000.
NEG
0.000
0.0 0 0
NEG
301005992
425400.
NEG
• 004
.009
NEG
301005S93
24330.
NEG
. 005
• 04 5
NEG
30100599'*
44550.
NEG
.000
.0 on
NEG
301005 ?95
^9290.
NEG
0.000
0.000
NEG
301999000
I511f0000.
NEG
.516
.336
NEG
301999990
1511eoooo.
NEG
.518
.33 6
NEG
301999931
70000000.
NEG
.276
.067
NEG
301999<92
181500.
NEG
.018
.153
NEG
301999*93
81000000.
NEG
.224
.116
NEG
-------
Table 4-E-b. 1977 CHEMICAL MANUFACTURING UNCERTAINTIES
INDUSTRIAL PROCESS, CHEMICAL MANUFACTURING
PAGE
£•
•k
TACR AND
EMISSION UNCERTAINTIES
FROJECTED TO
1977
RUN
0 ATF =
MODIFIED
TAC?F
EMISSIONS MILLIONS OF
TONS
see
(SCC LMTSI
NO*
HC
CO
301002000
«¦ 239590.
NEG
~ . 029
~
• 001
239S90.
NEG
- . 029
.001
301002010
~ 236350.
NEG
~ . 029
4-
.001
236350.
NEG
- . 029
.00 1
301002020
~ 39290.
NEG
~ 0.000
~
0.000
39290.
MEG
- 0.000
0.000
301003000
~ 56<97.
NEG
~ . 004
~
.033
56997.
NEG
- . 004
.033
301003010
~ 3*» 731.
NEG
~ . 000
~
.033
34 731.
NEG
- . coo
.033
301003020
~ 33543.
NEG
«¦ . 004
~
0.000
33543.
NEG
- . 004
0.000
3 0100 3030
~ 25076.
NEG
+ 0.000
~
0.00 0
25076.
NEG
- 0.000
0.00 0
3 0100 3 990
«¦ 16982.
NEG
«¦ .noo
«¦
0.000
16 982 .
NEG
- . 000
0.00 0
301005000
~ 228300.
NEG
«¦ . 074
~
.353
228300.
NEG
- . 074
. 352
301005010
~ 82790.
NEG
«• . 073
~
.333
62 79Q.
NEG
- . 073
.333
301005020
~ 18202.
NEG
~ . 000
4-
.000
18202.
NEG
- . 000
.000
301005030
~ 2640.
NEG
«- . "03
~
.007
2640.
NEG
- . 003
.007
3010 05 040
~ 40800.
NEG
~ . 010
~
.054
40800.
NEG
- . 010
.053
301005050
~ 5 322 7.
NEG
~ . 007
~
.102
53227.
NEG
- . 006
.102
301005590
~ 201070.
NEG
~ . 001
~
.005
201070.
NEG
- . 001
.00 5
301005*91
~ 200000.
NEG
~ 0.000
~
0.000
200000.
NEG
- 0.000
-
0.00 0
PART
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
-------
Table 4-2-b. 19 77 CHEMICAL. MANUFACTURING UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, CHEMICAL MAN'UFACTU°ING
TACR AfO E^ISSIOt^ UNCEfT&IMIES PROJECTED TO 197? RUN DATE =
EMISSIONS (MILLIONS OF TONS
MCOIFIEC
see
301005992
3 0100 5 S93
301005*94
301005*95
301999000
301999 S90
3 01999991
3 01999592
301999993
TAC*F
(SCC UNITS)
20000.
20000.
1000.
1Q00.
2000.
2000.
5003.
5000.
i7<+e<»ooo.
i7«iei«ooo.
17*»6^000.
17
-------
Table 4-3-a. 1982 CHEMICAL, MANUFACTURING EMISSIONS AND CHARGE RATES
I
ANNUAL CHA^G?
MCOIFIEt
SCC
301002000
301002010
301002020
3 0100 3000
301003010
301003020
301003030
301003 *90
3010050Q0
301005010
301005020
301005030
30100 5040
301005050
301005990
301005=91
301005992
301005993
30 100 5 99*»
301005*95
INCUSTRIAL PROCESS, CHEMICAL MANUFACTURING PAGE 1
PATES ANC EMISSIONS PROJECTEC TO 1982 CUN DATE = NOV 16,1977
TACRF
(SCC UNITS)
7473800.
6408200.
1065600.
2963300.
9*-1200 .
908900.
678=00.
<~59300.
62 5 210 0.
9 7664.
268890.
37393.
577780.
753800.
4546600.
4003000.
42 5MJ0.
24330.
4 4550.
49290.
NOX
NEG
NEG
MEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
EMISSIONS (MILLIONS OF TONS / YEAR)
HC
. 256
. 256
0. 000
. 038
. 001
. 036
0. 000
. 000
.331
.086
. 000
. 032
. 121
. C83
. 009
0.000
. 004
. 005
.000
0 . 00 0
CO
.003
.00 3
0.000
.056
.056
0.000
0.000
0.00 0
2. 42 0
.392
.00 4
.098
.64 9
1.223
.055
0.000
.009
.045
.00 0
0.000
PART
NEG
MEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
301999000
301999 ?90
301999991
301999992
301999993
151180000.
151ie0000.
70000000.
181500.
81000000.
NEG
NEG
NEG
NEG
NEG
.518
.518
.276
. 018
.224
• 336
.336
.067
.153
.116
NEG
NEG
NEG
NEG
NEG
-------
Table 4-3-b. 1982 CHEMICAL MANUFACTURING UNCERTAINTIES
INDUSTRIAL PROCESS, CHEMICAL MANUFACTIFING PAGE 1
TACR AND EMISSIOh UNCERTAINTIES PROJECTED TO 1982 RUN DATE = NOV 16,197?
I
-4
MODIFIED
SCC
T ACRF
ISCC UMTS!
3 0100 200 0
~
335720.
NEG
~ . 035
+ .001
335720.
NEG
- . 035
- .001
301002010
«¦
331210.
NEG
~ #035
+ .001
331210.
NEG
- . 035
- ,00 1
3 01002030
~
54824.
MEG
~ 0. COO
~ o.ooo
££»S2*.
NEG
- 0.000
- o.ooo
301003000
~
79980.
NEG
+ .005
~ .038
75980.
NEG
- .00 5
- .938
301003010
~
<~8751.
NEG
~ . 000
v .038
301003020
48751.
NEG
- . 000
- .038
~
<~6963.
NEG
~ .005
~ 0.000
46963.
NEG
- . 005
- 0.000
301003030
f
35263.
NEG
~ 0 . GO 0
~ o.ooc
301003990
35283.
NEG
- 0. 000
- 0.000
~
23867.
NEG
-i- . 000
+ 0.000
23867.
NEG
- .00 0
- 0.00 0
301005000
*
247220.
NEG
+ . 099
+ .469
2*1€30.
NEG
- . 088
- .418
301005010
110770.
NEG
~ . 098
+ .445
301005020
97664.
NEG
- . 086
- .392
>
22236.
NEG
* . 000
~ .00 0
22236.
NEG
- .000
- .00 0
301005030
~
3497.
NEG
~ . CO 3
~ .009
301005040
3497.
NEG .
- . 003
- .009
~
54118.
NEG
~ . 012
+ .069
54118.
NEG
- . 012
- .068
3 01005050
70594.
NEG
4- .00 9
~ .130
30100 5990
73594.
NEG
- . 008
- .130
~
201070.
NEG
~ .601
+ .00 5
2C1070.
NEG
- . 001
- .00 5
301005991
~
200000.
NEG
* 0.000
+ 0.000
-
200000.
NEG
- 0.000
- 0.000
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX HC CO P ApT
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
-------
Table 4-3-b. 1982 CHEMICAL MANUFACTURING UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS» CHEMICAL HA NUFACTUPING PAGE 2
TACR AND EllSSlOh UNCERTAINTIES PROJECTEO TO 1982 PUN DATE = NOV 16,1977
MODIFIEt TACRF EMISSIONS (MILLIONS OF TONS / YE tR)
SCO CSCC UNITS) NOX HC CO PART
301005*92 ~ cOOOO. NEG ~ .000 ~ .001 NEG
20000. NEG - .000 - .001 NEG
301005<93 1000. NEG ~ .001 + .0(15 NEG
1000. NEG - . 001 - .00 5 NEG
30100599
-------
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 4-4. Industrial process emissions for chemical manu-
facturing (SCC 3-01-xxx-xx) are compared in Table 4-5 with emissions
from the petroleum industry and other members of the industrial process
group. The PART and NOx emissions from chemical manufacturing repre-
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
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 4-6 ranks the cate-
gories with the highest charge rates. Tables 4-7 and 4-8, 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 4-7 and 4-8) to those having the
highest charge rates (Table 4-6), 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 4-15)
4-9
-------
Table 4-4. NATIONWIDE POINT SOURCE EMISSIONS*1
Source
Category
Emissions, tons/yr
PART
NO
HC
CO
Fuel
Combustion
5,414,427 8,922,937 239,403
645,880
Industrial
Proces ses
8,427,012 3, 728, 717 7,033, 590 21, 132, 667
Other Point
Sou rces
1 50,847
29,725 165,847 5,455,023
Total
13,992,286 12,681, 379 7,438,840 27,233, 570
Ref. 4-3.
4-10
-------
Table 4-5. INDUSTRIAL PROCESS EMISSIONS*1
Source
Category
PART
NO
X
HC
CO
Total Industrial Process Emissions, tons/yr
Chemical
Manufacturing:
SCC 3-01-xxx-xx
232,886
(2.76%)
155, 068
(4. 16%)
2, 319, 544
(32.98%)
5,992,262
(28.36%)
Petroleum
Indus try:
SCC 3 -06-xxx-xx
1,036,281
(12. 30%)
3, 264,812
(87. 56%)
1,012, 131
(14. 39%)
4, 524,476
(21.41%)
Other Industrial
Proces sesb
7, 157,845
(84. 94%)
308,837
(8.28%)
3, 701, 915
(52. 63%)
10, 615, 929
(50. 2 3%)
Total Industrial
Proces ses
8,427,012
(100%)
3,728,717
(100%)
7, 033, 590
(100%)
21,132,667
(100%)
Total Nationwide
Point Source
Emissions, %
Chemical
Manufacturing
1.7
1. 2
31. 2
22. 0
Petroleum
Industry
7.4
25. 7
13.6
16. 6
Othe r
Industrial
Processes
51 . 2
2.4
48. 8
39. 0
Total Industrial
Proces ses
60. 2
29.4
94, 6
77.6
aRef. 4-3.
^Includes such processes as food, agriculture, primary metals, and secondary metals.
4-11
-------
Table 4-6. PRODUCERS OF GREATEST EMISSIONS
IN CHEMICAL MANUFACTURING
Rank
see
Numbe r
of Point
Sources
Source Category-
Annual
Production
Rate,
tons/yra
1
3-01-999-99
1944
Miscellaneous
chemical
manuf ac tu ring
151.29 x 106
2
3-01-026-99
189
Miscellaneous
synthetic rubber
production
13.63 x 106
3
3-01-021-99
40
Miscellaneous
sodium carbonate
produc tion
11.67 x 106
4
3-01-018-99
225
Miscellaneous
plastics production
5.30 x 106
5
3-01-005-99
74
Miscellaneous
carbon black
production
4.75 x 106
6
3-01-002-01
33
Ammonia pro-
duction with
methanator
4.62 x 106
7b
3-01-027-03
41
Ammonium nitrate
with prilling
tower
4.25 x 106
aAlso known as annual charge rate (ACR).
These categories were not among the five categories yielding the greatest
emissions in the chemical manufacturing group.
4-12
-------
Table 4-7. PRODUCERS OF GREATEST HC EMISSIONS IN
CHEMICAL MANUFACTURING
Rank by Emissions
Rank
see
Source Category
Effective
Emis sion
Factor,
lb/tona
Emission
Rate,
tons/yr
1
3-01-999-99
Miscellaneous chemical
manufacturing
6. 86
519 X 103
2
3-01-005-01
Carbon black, channel
1767.
227 x 103
3
3-01-002-01
Ammonia with methanator
69. 2
160 y IO3
4
3-01-005-04
Carbon black, furnace oil
425.
82 x 103
5
3-01-018-99
Miscellaneous plastics
production
30. 6
81 x IO3
Rank by Product
Production Rate
Emission Rate
Rank
Product
Tons/yr %
Tons/yr
%
1
Carbon black
0.634 x 106 0.4
309 X 103
29
2
Ammonia
4. 622 x 106 2.9
160 X 103
15
3
Plastics
5. 296 x 106 3.3
81 x iO3
8
4
Other
151.3 x 106 93.5
519 X 103
49
Total
161.85 x iO6 100
1069 x 103
100
aEffective emission factor is the emission rate (lb/yr) divided by the
production rate (tons/yr).
4- 13
-------
Table 4-8. PRODUCERS OF GREATEST CO EMISSIONS IN
CHEMICAL MANUFACTURING
Rank by Emissions
Rank
see
Source Category
Effective
Emission
Factor,
lb/tona
Emission
Rate,
tons/yr
1
3-01-005-01
Carbon black, channel
8031.
1032 x 103
2
3-01-005-05
Carbon black, furnace
oil and gas
3246.
797 x 103
3
3-01-005-04
Carbon black, furnace oil
2137.
403 x 103
4
3-01-999-99
Miscellaneous chemical
4.44
336 x 103
5
3-01-005-03
Carbon black, furnace gas
5000.
60 x 103
6
3-01-005-99
Carbon black, miscella-
neous processes
24.44
58 x 103
Rank by Product
Rank
Product
Production Rate
Emission Rate
Tons/yr %
Tons/yr
%
1
Carbon black
5.90 x 106 3.8
2350 x 103
87
2
Mipcellane ous
chemical
manufacturing
151.29 x 106 96.2
336 x 103
13
Total
157. 19 X 106 100
2686 x 103
100
aEffective emission factor is the emission rate (Ib/yr) divided by the
production rate {tons/yr).
4-14
-------
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 4-7 shows that cer-
tain carbon black, ammonia, and miscellaneous chemical manufacturing
^missions represent 93 percent of the HC emitted by the five largest pro-
ducers in the chemical manufacturing category. Table 4-8 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
3-01-002-xx Ammonia made with methanator
3-01 -003-xx Ammonia made with CO absorber
3-0i-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 projections 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
4-15
-------
emission data. Most of these observations were trivial, but two were
believed sufficiently significant to be reported here.
4 . . 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 4-9 far .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.
Data Source
NEDS Tape:
1971 0.28
NEDS Nationwide Emis-
sion Summary Report:
December 1973 0.22
January 1975 0.23
CO
0.33 1.42 2.92
0. 15 2. 37 6.01
0.16 2.33 5.99
Emissions, million tons/yr
PART NOx HC
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.
4-16
-------
Table 4-9. SUMMARY OF CHEMICAL MANUFACTURING
AND EMISSIONS REPORTED IN NEDSa
see
Annual ^
Emissions,
~ tons/yr
Charge Rate
PART
NO
X
HC
CO
3-01-002-01
4, 621, 676
118
3, 259
160,008
2, 777
3-01-002-02
766, 500
-
-
-
-
3-01-002-99
-
-
-
-
-
3-01-002
118
3, 259
160,008
2, 777
(-%)
(1.0%)
(tl.3%)
(0. 1%)
3-01-003-01
679, 793
40
65
772
10,995
3-01-003-02
6 51, 996
119
-
2, 510
3-01-003-03
486,877
-
-
-
_
3-01-003-99
330,000
-
-
331
-
3-01-003
159
65
3, 613
10,995
(0. 1%)
(-%)
(0.3%)
(0.4%)
3-01-005-01
257,163
22,146
_
227, 337
1, 031,710
3-01-005-02
-
-
.
3-01-005-03
24,381
3, 614
-
19, 997
63,469
3-01-005-04
376,731
901
435
82,204
402,659
3-01-005-05
491, 484
7, 168
10
54,013
797,087
3-01-005-99
4, 745, 552
8,079
68
8, 967
57,506
3-01-005
41,908
513
392, 518
2, 352,431
(15.2%)
(0.2%)
(27.7%)
<80.7%)
3-01-999-99
151,288,357
69,015
44, 054
518, 506
335,500
(25.0%)
(13.3%)
(36.5%)
(11. 5%)
3-01-008
248,813
343
55,730
144
(100 tons/yr)
(0. 1%)
(16.8%)
(-)
(-%)
3-01 -033-0 i
3, 000
(-)
5, 801
_
(gal/yr)
(-)
(0.4%)
(-)
3-01-900-99
747
4, 667
146
18,850
(million cu ft/yr)
(1.7%)
(-)
(-)
(0.6%)
Other
182,696,930
159, 870
228, 523
338, 554
194,503
3-01
(57.9%)
(68.8%)
(23.9%)
(6.7%)
Total
276,080
332, 290
1,419, 000
2, 915,200
(100%)
-------
[o-REF.4-6 A = REF. 4- 3 and 4-7
0.28 -
0. 26 -
0. 24 —
0.22 —
0.20
0.34
OXIDES OF NITROGEN
0.30
£ 0.26
LTl
2 0.22
° 0-18
14
2.6
UNBURNED HYDROCARBONS
U1
1.8
6.0
CARBON MONOXIDE
1971
1972
1973
1974
1975
CALENDAR YEAR
Figure 4-1. Emissions from chemical manufacturing
PARTICULATE MATTER
4-18
-------
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 3-01-005-020 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 thermal carbon black was not reported or it was
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 Standard Industrial Classification (SIC) 2895 is close to the
deficit. Of the nine SICs comprising 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 hydrocarbon (HC) feed stock such as natural gas. The difference in
the two techniques is centered on how the large amounts of CO are handled.
The CO results when is extracted from the HC feed stock. While the
CO emissions in the main process of ammonia production are substantially
4-19
-------
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 in 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:
'p
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.
4-20
-------
10
ex
8
6
O REF. 4-9
o
A REF. 4-6
LEAST SQUARE FIT TREND
(excluding 1964 and 1965 data)
4
o
o
0«—
1940
1975
1945
1950
1970
1955
1960
1965
CALENDAR YEAR
Figure 4-2. Synthetic ammonia production
4-21
-------
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 1982 is
estimated to be 256,000 tons ± 35,000. The majority (223, 000 tons) of these
emissions is from methanator-type production. The total estimated CO
4-22
-------
(-'missions from ammonia industries in 1982 is 59,000 tons ± 38, 000. The
NO and PART t-missions are expected to be negligible in 1 982 (as is the
ease prcsrnlly) compared to other point source industrial processes
emissions.
4.3.4 Carbon Black Industry
4.3.4. 1 Processes and Use s
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 proce ss
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
4-23
-------
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 lb of carbon
black per 1000 cu ft of gas compared to a yield of Z to 3 lb/1000 cu ft from
the channel black process. The theoretical yield is approximately 32 lb/
1000 cu ft.
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 soot particulate, 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.
4-24
-------
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 sum 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.
4-25
-------
o
REF.
4-6
O SUM OF 3-01-005 xx SCCs
O SAME AS O LESS SIC 2952 OF SCC 3-01-005-99
~ SAME AS O LESS ALL SICs OF SCC 3-01-005-99 EXCEPT SIC 2895
A SAME AS O LESS ALL OF SCC 3-01-005-99
0 SCC 3-01-005-01 ONLY
V REF4-7 DATA
SCC= SOURCE CLASSIFICATION CODE
SIC - STANDARD INDUSTRIAL CLASSIFICATION
1960
CALENDAR YEAR
1965
^ THERMAL
FURNACE
}CHANNEL
1970
Figure 4-3. Total carbon black production
4-26
-------
0.3
0.2
0
az
0.4
<
>-
0.3
UJ
a.
on
0.2
Z
O
LL-.
0.1
o
0
Z
1025
O
—i
0.020
I
z
0.015
o
—
C_>
ZD
0.010
a
o
0
OS
Q_
0.20
o
c
0.15
QQ
o
0.10
GO
os:
c
o
o'
O = REF. 4-3 A = RFF 4-6
FURNACE
(gas/oil)
FURNACE
FURNACE
O
THERMAL
0.3
0.2
0.1
0
— O
0
1
CHANNEL
1950
1955 1960 1965
CALENDAR YEAR
1970
1975
Figure 4-4. Breakdown of carbon black production
4-27
-------
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
proce ss
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:
EFj (l.o - 0.4 - Tlj) T\z
EF^ = (1.0 - 0.4 - T) ) T|
4-28
-------
whe re
EF = emission factor
Tj = decimal fraction of 32 lb 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.
4.3.4.2.2 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 NEC
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
aNot elsewhere classified (NEC).
4-29
-------
The baseline charge rate was set equal to the NEDS (1970)
value. Uncertainties were set at 5 percent of the base value for categories
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 pro-
jections of the 3-01-005-99 SCC categories.
4. 3. 4. 3 Projections of Carbon Black Activity
The estimated HC emissions in 1982 carbon black industries
are 331, 000 tons. Although the channel process is by far the dirtiest (high
emission factor), its HC emissions are down both trend-wise and process-
wise. The 1982 HC emissions from channel black production is 86,000 tons
compared to 121, 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 1982 are
2. 42-million tons . The oil-enriched natural gas-fired furnace technique
leads CO emissions with 1. 22-million tons in 1982.
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
4-30
-------
SIC 2818 and 3999, respectively, constituted approximately 50 percent of
the ITC and CO emissions. The 76 other SIC products combined represented
only 43 percent of the [JC 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
Manufactu ring
The estimated 1982 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).
4-31
-------
Compilation of Air Pollutant Emission Factors, AP-42, U.S.
Environmental Protection Agency, Research Triangle Park,
North Carolina (February 1972).
Compilation of Air Pollutant Emission Factors, 2nd ed. ,
AP-42, U. S. Environmental Protection Agency, Research
Triangle Park, North Carolina (April 1973).
"Industrial Processes, Chemical Manufacturing Category, "
NEDS Data, The Aerospace Corporation Tape Analysis, The
Aerospace Corporation, El Segundo, California (February 25
1975).
NEDS Nationwide Emissions Report as of December 10, 1973
U. S. Environmental Protection Agency, Research Triangle
Park, North Carolina (January 12, 1974).
I. Drogin, "Carbon Black, " Journal of Air Pollution Control
Association, Informative Report No. 9, 8_ (4) (April 1968).
R. Shreve, Chemical Process Industries, 3rd ed. , McGraw
Hill Book Co. , Inc. , New York (1967).
NEDS Source Classification Codes and Emission Factor
Listing (SCC Listing), U. S. Environmental Protection
Agency, Research Triangle Park, North Carolina
(July 1974).
T. Cox, Jr. , "High Quality-High Yield Carbon Black, "
Chemical Engineering Journal (June 1950).
4-32
-------
SECTION V
PETROLEUM REFINERIES
5. 1 INTRODUCTION
This section develops data for the petroleum refining industry,
in terms of several important source classification codes (SCC), for emissions
of particulate (PART) matter, nitrogen oxides (NO ), unburned hydrocarbons
(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. Data for two sample years are reported in Tables 5-2-a
and 5-3-a, respectively. The uncertainty data are listed in Tables 5-2-b
and 5-3-b.
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,
(continuted on page 5-9)
5-1
-------
Table 5-1. DEFINITION OF PETROLEUM INDUSTRY PROCESSES
MSCC
Source Category
Charge Rate Unit
306001010
Process heater (oil-fired, major
quantities)
1000 bbl burned/yr
306001020
Process heater (gas-fired, minor
quantities)
1000 cu ft burned/yr
306001030
Process heater (oil-fired, minor
quantities)
1000 gal burned/yr
306001040
Process heater (gas-fired, major
quantities)
Million cu ft burned/yr
306002010
Fluid catalytic cracking
1000 bblfresh feed/yr
306003010
Moving bed catalytic cracking
306008010
Miscellaneous leakage (pipe, valve,
flange)
1000 bbl refined/yr
306008020
Miscellaneous leakage (vessel
relief valves)
1000 bbl refined/yr
306008030
Miscellaneous leakage (pump seals)
1000 bbl refined/yr
306008040
Miscellaneous leakage (compressor
seals)
1000 bbl refined/yr
306008050
Miscellaneous leakage (other,
general)
1000 bbl refined/yr
306012010
Fluid coking
1000 bbl fresh feed/yr
5-2
-------
Table 5-Z-a. 19 77 PETROLEUM INDUSTRY EMISSIONS AND CHARGE RATES
i
INTUST-Ul. P-CTISS, ^ETPCLEliM
ANNUAL CHA^G-" 3 A T£ S AN9 fMTSGIONS P3OJ?CTrr TO P'
MODIFIED
sen
T AC^
(SCC L M T jI
NOX
EMISSIONS (
M
PPCGJCT^
7 = Lf '
'ILL 10 CF
i AT E = NPV 1
TONS / YEA
CO
D A G E 1
6,1177
')
PART
306Q01000
. <*35
. H49
.13c
. C 9 0
^o^co loin
30 eon 1020
30 6n010 30
3 0600 10<*Q
It 13?3.
?r6na coooo.
5£670C.
NEG
. 16*
. 255
. r 16
MEG
. nin
. °3 6
. noi
ME G
.0 12
. 3 2 7
.001
NEG
. Cu 9
. 0 26
. n C5
M: G
3 o 6 o n ? o o n
15 7 6 0 01.
. ^53
.1 7k
. 16 1
306002010
1576000.
.053
. 17k
1*.85 9
.161
306003001
c- 310 0.
MEG
. 00 £~
. 1 7 7
N"G
306013010
<= 31U0.
MEG
. 00*
.17"'
NEG
3 06008000
276E0000.
NEG
. 198
N c G
m r
« L o
30 600 8010
306003020
306008030
v3 060080hT
306008050
5610003.
5610000.
5610000.
52 E 000 0 .
5610000.
NEG
MEG
NEG
KEG
NEG
. 079
. 031
. 0U8
. 013
. C2 8
NtT.
NEC-
NEC
MEG
.MEG
N-G
NEG
NEG
NFG
NEG
306012000
11^00 0 .
NEG
NEG
Mf G
. ^28
3 06 012010
11^000.
MEG
NFG
NEG
.028
-------
Table 5-2-b. 19 77 PETROLEUM INDUSTRY UNCERTAINTIES
.Ncmr-I4L
p -
oncSG,
° E TP. CL r,JM FrOlUCT
s
P&GE 1
TACP E
'ISSICK UMCE=TftI MI£S
=
-?DJrQTE
1 tp 197 7 k
UN
D AT E =
NCV 16,
1 177
^ODIPIEC
T mC^F
:SSIONS ( " IL L10 N S
CF
TONS
/ YEA")
see
(SCC LNIT SI
NOX
m r
CO
PA~ T
30*001000
+
. n ?7
«¦ .006
+
. 3d Z
~
.0 05
—
. 0 27
. ro6
-
. 00 t
-
. 0 05
<0*001010
~ 6601.
~-
.01%
~ .005
~
.on?
f
.00 =
5 €0 1.
-
.0U
.1305
-
. 0 0 ^
-
. 015
3060010^0
~ 1593(^ 000 0 .
~
.022
~ . nn3
~
.00 5
~
. 002
- 159963000.
-
.022
. p n 3
-
.00 5
-
. CO?
3 06001030
~ 2 5h56.
. 007
~ . too
~
.00 0
~
.0 02
35U56.
-
.007
. ooo
-
. 03 (1
-
.0 02
3060010<*0
NEG
NEG
NEG
MEG
NEG
KEG
NEG
~.eg
ME G
NFG
306002000
~ 72971.
.00*
~ . 012
~
6.21 e
+¦
. Cll
7 2«7i.
—
. 00<*
- . 012
—
6.21 e
-
. Oil
306002010
~ 72571.
~
. 00i+
. 012
~
6.21 6
+¦
. 0 11
7?c71.
—
. 004
. Q12
—
6.?1 6
-
. Cll
3 06003090
+ 863 3.
NCG
+ . noo
~
.0 19
NEG
«633.
NEG
. noo
—
.019
NEG
3 06003010
~ 33.
NEG
~ .000
4-
.019
Nc.G
<5633.
MEG
- . noo
—
.0 19
NEG
306003000
~ 5 9 0690.
MEG
+ . 036
MEG
^ ^ c.
5^0690.
NEG
- . 036
me n
NEG
3oeoo80in
+ 21 s lb n.
MEG
~ .
MFC-
NEG
26
-------
Table 5-2-b. 1977 PETROLEUM INDUSTRY UNCERTAINTIES (Continued)
i\DUSTrI4l :,cTfCLr,Jw PRO IDC T3 oar,- 2
rarf. a NO EUSSIOf^ IJNCEPT-I M":ES PROJECTED TP 137" *U\ DATE* NOV 16 ~ 1 977
'"OOIFI-O TAC-P E^ISriONS f^ILLIONS CF TONS / YE 0~ )
sen {^cc LMTS) NO X h ? O PAcy
^oeoi?oon * 5?o 5. meg nfg neg *¦ .n?
5 205. MEG KEG MEG - .032
30 6012010 320 5. MEG '.'EG NEG «• .CO?
5 205. MEG '.'EG NEG - . C02
-------
Table 5-3-a. 1982 PETROLEUM INDUSTRY EMISSIONS AND CHARGE RATES
INCUST
7 IA L ^0CrSS, nE IF CLr
LJM PP.OJUCTS
PAGE 1
ANNUAL CHANGE
rA TES ANC EM
IS 21ONS PROJECTED TO
19-^2 * UN
D AT E =
NOV 16,1977
MODIFIED
see
TACRF
(SCC IN IT S)
£MI SEICN5
NOV
MILLIONS OF
H'
TONS
CO
/ >E A9)
PA-T
3 06omooo
. 253
. 061
.03?
.077
306001010
306001020
306001030
3 060 0 10^0
9 313
3 <*60 (1 0000 0 .
5ee?oo.
N EG
. n<*i
. 206
. 036
N EG
. no7
. U52
. 001
NFG
. 00 0
.03 0
.10 1
NFC-
. C 3 9
. 0 35
.0 03
NEG
3 06002000
176 6 00 0.
. 059
.18 3
* « 6 2 c
. 1 C?
306002010
1766000.
. 059
. 183
3.326
.in?
306003000
S^COO.
NEG
. 002
.100
NEG
306003010
5*460 0 .
N EG
. no2
.10 0
NEG
30 6008000
31 2 SO 00 0 .
NEG
. 226
NEG
NcG
306008010
306003020
306008 C30
3 0 60080^0
30 €008050
6510000.
6510000.
6510000.
5250000.
6510000.
NEG
NEG
NEG
NEG
NEG
. 092
. 035
. 055
. 113
. 032
NEG
NEG
NEG
NEG
NEC-
NEG
N^G
NEG
NEG
NEG
306012000
12^000.
NEG
NEG
NEC-
. 0 *0
306012010
1 2<»00 0.
NEG
NEG
NFG
. 0 30
-------
Table 5-3-b. 1982 PETROLEUM INDUSTRY UNCERTAINTIES
iNCusr
cIAL p-
Q~ESS, JE
TF CL rU
*¦' P^COUCTS
PAGE 1
T ACP AND E
113 310 N UNCESTAI
NT ICS C?CJ ECTE 1
TC 1 98
?
UM
o ate =
o
<
<•
1 977
^ 901F IEC
T AC"» f
EM IS
EI ON S
(MILLIONS
CE
ton s
f YE A=?)
see
< CCC UMIT 3 >
NO X
HC
CO
Dft C]-
316001000
4-
. n 3*
4-
. r0 7
4
.007
4-
. 0 03
—
. o *<~
—
. ij 0 9
-
.00 7
-
. 00
-------
Table 5-3-b. 1982 PETROLEUM INDUSTRY UNCERTAINTIES (Continued)
INDUSTRIAL
p^OCEES,
3ETrOLEUM PPOHUCTS
PAGE 2
T ACP A ^ F
MISSION UNCE-T AI KTIES
°30J ECTE
"l TC 1 9 ft 2 PUN
D Alt =
NOV 16,1977
MODIFIED
T ACS F
EM
IS EI ON^ f.vILLI0h3 OF
TOMS
/ YEA*)
see
(SCC UMTS!
*JQX
HC
CO
DAFT
?oeni2oao
~
16658.
NEG
NEG
NEG
* .0 05
-
16658.
MEG
KEG
NF C
- . 0 D5
3 96 01?01Q
16658.
MEG
KEG
NF G
~ .0 05
-
16656.
NEG
NEG
M f G
- .005
-------
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
the basis of an 8 percent coke formation and a feed gravity of 300 lb/bbl, we
ha ve
5C + 402 = 2CO + 3COz
8-lb coke x 56 - lb CO x 300 lb x 10£0 bbl _ 22 400_lb CO/SCC
100- lb fresh feed 60-lb coke bbl SCC
Slightly different assumptions can be made to show even more severe emission
factors, which merely makes the uncertainty range greater.
-------
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 5-4. 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 the 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-
9
alized on 350 days results in 5.25 X 10 bbl. Although this appears to be an
5-10
-------
Table 5-4. 1973 DISTRIBUTION OF PETROLEUM PRODUCTS
Product
Percent of Refinery Yield
Gas oline
Distillate Fuel Oil
Residual Fuel Oil
Jet Fuel (Kerosene)
Kerosene
Jet Fuel (Naphtha)
Lubricants
Other
45.61
22.46
7.74
5.41
1.73
1.44
1.50
14. 11
5-11
-------
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
9 9
6.0x10 to 6.3x10 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 106 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).
5-12
-------
In forecasting, 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 the
near future 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
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 equip-
ment. At the same time, improved firing techniques will enable reductions
in NO emission factors,
x
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
9
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
9
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.
5-13
-------
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 lb) 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 degree 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. Information
concerning refinery abandonments, replacements, enlargement, and modern-
ization 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
5-14
-------
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 to forecast 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^ bbl/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
9 6
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
5-15
-------
6
is obtained from a daily feed capacity of 14.2 X 10 bbl. At 300 lb/bbl,
we obtain
43,410 ton/day x = 2 Q%
14.216 x 10 bbl/day x 300 lb/bbl x
2000 lb
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
Q
to affect 0.67 x 10 bbl/year of fresh feed charge rates out of a total of
9 9
1. 77 X 10 bbl/year by 1982. In other words, of the current 1.58 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 review 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.
5-16
-------
5. 7 PETROLEUM REFINERY PRACTICES
5. 7. 1 Raekground
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-
H ydroprocessing
h.
Alkylation
i.
Isomerization
5-17
-------
Topping
The basic operation in all refineries is atmospheric pressure
distillation. This operation, known as topping, 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 propane-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 cracking 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
5-18
-------
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 maybe accom-
P1 ished 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
5-19
-------
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 multi pie 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, isomerization;
pentane to isopentanes, Cc isomerization). Now, more modern plants
such as Butamer, Penex, and Hysomer process reactants in the presence of
highly active and selective fixed-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, hydrotreating, and hydro-
refining are used to describe a multitude of production systems. The most
5-2 0
-------
usual applications are for desulfurization (also called hydrosuifurization) 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 ultrasweetening. 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 hydroproce ssing
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.
Alkylate finds extensive use in aviation gasoline.
Other Pr ocesses
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 NC>x except, perhaps, from the stand-
point of requiring boiler-produced steam or direct-fired thermal energy.
These include the following:
a. Light oil treating
b. Lube oil processing
5-21
-------
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, D.C. (July 1974).
5-2. Energy Statistics, Department of Transportation,
Washington, D.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. Dupree, Jr. and J. A. West, United States Energy
Through the Year 2000, U. S. Department of the Interior,
Washington, D.C. (December 1972).
5-6. W. B. Bryant, "Trends in the Oil Industry, " Chemical
Engineering Progress, 70 (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).
5-22
-------
A. L. Aim, "Energy and the Environment: Choices for
the Future, " Chemical Engineering Progress, 70 (12)
(December 1974).
"News Features. . . Oil Price Drop? , " Chemical Engineering,
34 (February 3, 1974).
W. W. Reynolds and H. S. Klein, "Petrochemical and
Energy in Perspective," Chemical Engineering Progress,
21, (3) (March 1975).
"Fuel and Steam Required in Average U.S. Refinery,"
The Oil and Gas Journal (April 21, 1958).
"Industrial Processes, Petroleum Industry Category, "
NEDS Data, The Aerospace Corporation Tape Analysis,
The Aerospace Corporation, El Segundo, California
(February 25, 1975).
L. R. Aalund, "Refining Capacity Registers Largest
'Nickel and Dime1 Jump in History, " The Oil and Gas
Journal (April 1974).
"Air Programs; Standards of Performance for New
Stationary Sources Additions and Miscellaneous
Amendments, " Federal Register, 39 (47), Part II
(8 March 1974).
Journal of the Air Pollution Control Association, 24 (4),
362-364 (April 1974).
A. L. Conn, "Developments in Refining Processes for
Fuels, " Chemical Engineering Progress, 69 (12)
(December 1973).
"Striking Advances Show Up in Modern FCC Design, "
The Oil and Gas Journal (October 30, 1972).
"NPRA Q&C - 3, Answers for Process Questions of
FCC Units, " The Oil and Gas Journal (March 11, 1974).
Background Information for Proposed New Source Per-
formance Standards, Vol. 1, Main Text, U.S. Environ-
mental Protection Agency, Washington, D.C. (June 1973).
Background Information for New Source Performance
Standards, Environmental Protection Agency, Vol. 3,
Promulgated Standards^ U.S. Environmental Protection
Agency, Washington, D.C. (February 1974).
5-23
-------
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. Weinberg 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).
5-24
-------
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 1977 was
3. 84-million tons/year and is estimated to drop by 40 percent to 2.3-
million tons/year in 1982.
The largest contributor to these totals is the paint and surface
coating application industries. The most dramatic reduction in estimated
emissions for the years of interest 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 for the two selected years from evaporation and total annual
charge rates (TACRP) is shown in Tables 6-2-a and 6-3-a and their uncertain-
ties in Tables 6-2-b and 6-3-b.
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
40 1001010
Perchlorethylene dry cleaning
Clothes, tons/yr
401001020
Stoddard dry cleaning
Clothes, tons/yr
40 1002010
Stoddard degreasing solvent
Solvent, tons/yr
401002020
Trichleroethane degreasing solvent
Solvent, tons/yr
40 10020 30
Pe rchloroethylene degreasing
solvent
Solvent, tons/yr
40 1002050
Trichlor oethylene degreasing
solvent
Solvent, tons/yr
40 1002990
Miscellaneous degreasing solvent
Solvent, tons/yr
402001011
Sheet, strip, and coil paint
Paint, tons/yr
402001012
Auto and truck paint
Paint, tons/yr
402001013
Major appliances paint
Paint, tons/yr
402001014
Industrial machinery paint
Paint, tons/yr
402001015
Wooden furniture paint
Paint, tons/yr
402001016
Metal furniture paint
Paint, tons/yr
402001017
Small appliances paint
Paint, tons/yr
402001018
Farm machinery paint
Paint, tons/yr
402001019
Commercial machinery paint
Paint, tons/yr
402002011
Coating for coated paper
Coating, tons/yr
402002012
Coating for folding cartons
Coating, tons/yr
402002013
Coating for kraft paper
Coating, tons/yr
402002014
Coating for milk cartons
Coating, tons/yr
402002015
Coating for paper bags
Coating, tons/yr
402002016
Coating for paper boxes
Coating, tons/yr
402002017
Coating for paper tubes and cans
Coating, tons/yr
402002018
Coating for printing paper
Coating, tons/yr
402002019
Coating for waxed paper
Coating, tons/yr
6-3
-------
Table 6-1. DEFINITION OF HC EVAPORATION (Continued)
MSCC
Source Category
Charge Rate Unit
40200 3011
Varnish and shellac on sheet,
strip, and coil
Coating, tons/yr
40200 3013
Varnish and shellac on major
appliances
Coating, tons/yr
402003014
Varnish and shellac on industrial
machinery
Coating, tons/yr
402003017
Varnish and shellac on small
appliances
Coating, tons/yr
402003019
Varnish and shellac on commercial
machinery
Coating, tons/yr
402004011
Lacquer on sheet, strip, and
coil
Coating, tons/yr
402004012
Lacquer on autos and trucks
Coating, tons/yr
402004015
Lacquer on wooden furniture
Coating, tons/yr
402004017
Lacquer on small appliances
Coating, tons/yr
40200 5011
Enamel on sheet, strip, and coil
Coating, tons/yr
40200 5012
Enamel on autos and trucks
Coating, tons/yr
40200 5013
Enamel on major appliances
Coating, tons/yr
402005016
Enamel on metal furniture
Coating, tons/yr
402005017
Enamel on small appliances
Coating, tons/yr
402006011
Primer on sheet, strip, and coil
Coating, tons/yr
402006012
Primer on autos and trucks
Coating, tons/yr
402006014
Primer on industrial machinery
Coating, tons/yr
402006016
Primer on metal furniture
Coating, tons/yr
402006017
Primer on small appliances
Coating, tons/yr
402006019
Primer on commercial furniture
Coating, tons/yr
402007011
Dye for fabric
Solution, tons/yr
402007012
Permanent crispness solution
for fabric
Solution, tons/yr
402007013
Sizing solution for fabric
Solution, tons/yr
6-4
-------
Table 6-1. DEFINITION OF HC EVAPORATION (Continued)
MSCC
Source Category
Charge Rate Unit
402007014
Waterproof solution for fabric
Solution, tons/yr
402007015
Wrinkle resistance solution
for fabric
Solution, tons/yr
402008011
Oven coating for sheet, strip,
and coil
Coating, tons/yr
402008012
Oven coating for autos and trucks
Coating, tons/yr
402999990
Miscellaneous surface coating
activity
Coating, tons/yr
40 300101 1
Fixed-roof tank gasoline breathing
loss
Storage capacity,
1000 gal
40 3001021
Fixed-roof tank crude breathing
loss
Storage capacity,
1000 gal
40 3001031
Fixed-roof tank gasoline working
loss
Throughput,
1000 gal/yr
40 3001041
Fixed-roof tank crude working loss
Throughput,
1000 gal/yr
40 30010 51
Fixed-roof tank JP-4 breathing loss
loss
Storage capacity,
1000 gal
40 3001061
Fixed-roof tank kerosene breathing
loss
Storage capacity,
1000 gal
40 3001071
Fixed-roof tank distillate breathing
loss
Storage capacity,
1000 gal
40 300 1 50 1
Fixed-roof tank JP-4 working loss
Throughput,
1000 gal/yr
40 3001511
Fixed-roof tank kerosene working
los s
Throughput,
1000 gal/yr
40 3001521
Fixed-roof tank distillate working
loss
Throughput,
1000 gal/yr
40 3002011
Floating-roof gasoline tank
standing loss
Storage capacity,
1000 gal
403002021
Floating-roof gasoline tank
working loss
Throughput,
1000 gal/yr
40 30020 31
Floating-roof crude tank
standing loss
Storage capacity,
1000 gal
6-5
-------
Table 6-1. DEFINITION OF HC EVAPORATION (Continued)
MSCC
Source Category
Charge Rate Unit
40 3002041
Floating-roof crude tank working
los s
Throughput,
1000 gal/yr
40 3002051
Floating-roof JP-4 tank standing
loss
Throughput,
1000 gal/yr
403002061
Floating-roof kerosene standing
los s
Storage capacity,
1000 gal
40 3002071
Floating-roof distillate standing
loss
Storage capacity,
1000 gal
40 300 3020
Variable vapor-space gasoline
working loss
Throughput,
1000 gal/yr
403999990
Miscellaneous petroleum product
storage loss
Stored, 1000 gal
406001011
Load gasoline on tank cars,
splash
Transferred,
1000 gal/yr
406001012
Load gasoline on tank trucks,
splash
Transferred,
1000 gal/yr
406001021
Load crude on tank cars, splash
Transferred,
406001022
Load crude on trucks, splash
Transferred,
40 6001261
Load gasoline on tank cars,
submerge
Transferred,
1000 gal/yr
406001262
Load gasoline on tank trucks,
subme rge
Transferred,
1000 gal/yr
406001271
Load crude on tank cars,
submerge
T ransferred,
1000 gal/yr
406002010
Load gasoline onto marine vessels
T ransferred,
406002260
Unload gasoline from marine
ves sels
Transferred,
1000 gal/yr
406002270
Unload crude from marine vessels
Transferred,
1000 gal/yr
6-6
-------
Table 6-2-a. 1977 HC EVAPORATION EMISSIONS AND CHARGE RATES
ANNUAL CHANGE RATES
HYOR0C
ANC EMISSIONS
EVCPGRATICN
PROJECTED TO 1977
CUK DAT F
HCOIFIF C
see
*~0 1001000
1*01001010
<~<11001020
*~01002000
<*01002010
401002020
<~0100203(1
<~01002050
4 0100 299 0
401999000
401999 «90
402001000
402001010
402001011
402001012
402001013
40200101L
402001015
40200101 (
40200101 1
402001018
402001019
TACSF
(SCC UMTS*
42080.
31650.
10430.
114480.
880.
3070 .
8 €13.
4470.
97ti50.
118650.
119650.
470730.
470730.
340000.
87000.
10240.
7200.
10990.
8135.
2325.
3270.
1466.
NOX
NEG
MEG
NEG
NEG
NPG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
EMISSIONS
(MILLIONS OF TONS
HC CO
.003 NEG
.00 2 NEG
. 002 NFG
.103 NFG
.001 NFG
.0 03 NEG
. 007 NEG
.004 NEG
.08 8 NEG
.0 23 NEG
.023 NEG
.215 NEG
.215 NEG
.171 NEG
. 029 NEG
.003 NEG
. 00 2 NFG
.004 NEG
. 003 NFG
.001 NEG
.001 NEG
.000 NEG
PAGF 1
NOV 16,1977
/ YEAS)
PART
NFG
NE3
NEG
NEG
N~G
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
402002000
402002010
<*0 20 02011
402002012
9437*00.
9437*00.
122 f50 .
19650.
NEG
NEG
NEG
NEG
411
411
056
004
NE G
NEG
NFG
NFG
NEG
NEG
NEG
NFG
-------
Table 6-2-a. 1977 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYQ'.OCa'bON ZVAPORATICN
DAGF
ANNUAL CHARG- RATES flNC EMISSIONS °R0JECTFD TO 19~7
?UN D ATE = NOV 16»1977
MCDIFIED
see
40200
40200
40200
40200
40200
40200
40200
2013
201 U
201 5
201 f
201 i
2018
2019
TAC5P
(SCC LNITSt
134200.
26050.
86 6500 0.
£9350.
5620.
71900.
303 10 0 .
NO V
EMISSIONS ("ILLIONS OF TONS / YEAR)
NEG
NEG
NEG
NEG
NEG
NEG
NEG
wc
058
C2 3
182
013
001
041
030
CO
NEC-
NEG
NEG
NEG
NEG
NEG
NFG
PART
NEG
NEG
NEG
NEG
NEG
NtG
NFG
0
1
CD
402003000
402003010
40200 3011
402003013
402003014
402003017
402003019
299730.
299730.
290000.
8900.
481.
^48.
98.
NEG
NEG
NEG
NEG
NEG
NEG
NEG
. 178
.178
. 172
. 00 5
. 000
. noo
. 00 0
NEG
NE G
NEG
NEG
NEG
NE G
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
49200400 0
402004010
402004011
402004012
402004015
402004017
€0186.
80186.
3280 0•
43200.
4130.
56.
NEG
NEG
NEG
NEG
NEG
NEG
. 053
. 053
. 022
. 029
. 003
. 000
NEG
NEG
NEG
NEG
NEG
NEG
NEG
N rG
NEG
NEG
NEG
NFG
402005000
402005010
402005011
402005012
402005013
40200501 €
315150.
315150.
130EOO.
172800.
1135 0.
239.
NEG
NEG
NEG
NEG
NEG
NEG
.163
. 163
. 067
. 089
. 007
. 000
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NFG
-------
Table 6-2-a. 1977 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
:l/ AP03 AT ICN
ANNUAL CHANGE 3ATES AND EMISSIONS PP.OiECTEC TO 1<=77
r^W 0 AT t
PA GE T
NOV 16,1977
HOOIFIEO
SCC
<~02005017
TACRP
(SCC UMTS!
256.
NOX
NEG
EMISSIONS (MILLI0NS OF TONS / YEAR)
H
. noo
CO
NF G
PAFT
NEG
*~12006000
<~02006010
*•02096011
<*0200601 2
<~0 200601 <«
<~0200601 6
<•0200601 7
<~02006019
959730.
9-9 730.
923000.
21600.
<<60.
<»2<*3.
33 3.
9^.
NCG
NEG
MEG
NEG
NEG
NEG
NEG
NEG
. <«61
. *»61
.-<~8
. 010
. noo
. 002
. 000
. ooa
NE G
NFC
NEG
NE C-
NEG
NEG
NEG
NE C
N l G
MEG
NEG
NEG
NEG
NEG
NEG
NEG
<~02007000
<~02007010
'•02007011
*~02007012
*~0200701 3
<~0200701 U
<~0200701 E
15C7EOO.
1597500.
337500.
272.
1066000.
10765.
163000.
NEG
NEG
NEG
NEG
NEG
NEG
NEG
. 231
. ?31
. 219
. noo
. mi
. ooo
. noi
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NtG
*~02008000
*~02008010
<*02008011
<~02008012
18070!).
180700.
72700.
108000.
NEG
NEG
NEG
NEG
. H99
. 099
. nuo
. 059
NE G
NE G
NEG
NtG
NEG
NEG
NEG
NtG
<~02999000
<~02999*90
1 539<*0 0 .
1539^00.
NEG
NEG
. 192
. 192
NEG
NE G
.011
. Oil
-------
Table 6-2-a. 1977 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HY0R3Cfl°.B0M E V AP0=?AT ICN PAGE 4
ANNUAL CHARGE SATES ANC EMISSIONS PROJECT C TO 1977 RUN D AT E = NOV 15,1977
MCOIFIEC
see
TAC3P
(SCC UNITS)
EMISSIONS
NOX
(VILIIO N S
HC
OF TONS
CO
/ Y E A 3)
PACT
40 3001000
\'EG
1 . 007
NEG
NFG
403001010
12800000.
NEG
. 666
NFC
NEG
403001011
12800000•
MEG
• 666
NEG
MEG
*~03001020
lltOOOO.
NEG
. 033
NEG
NEG
40 30 01021
1120000.
KEG
. n33
NEG
NEG
403001030
32000000.
NEG
. 166
NEG
NEG
403001031
32000000.
NEG
. 166
NEG
NEG
403001040
13ft0Q000.
NEG
. H62
NEG
MEG
4 03 0010 41
138 00000.
NEG
. 062
NE G
NEG
403001050
1 c*»000.
NEG
. 002
NEG
NEG
403001051
124000.
NEG
. 002
NEG
NEG
403001060
5 OOQOO.
NEG
. 004
NEG
NEG
403001061
5 COOOO.
NEG
. no4
NEG
NEG
403001070
6914100.
NEG
. 050
NE G
NEG
<•03001071
6914100.
NEG
. 050
NE G
NEG
403001500
49170000.
NEG
. 025
NEC
NEG
40 3001501
1570000.
NEG
. 002
NE G
NEG
403001510
20800000.
NEG
. 010
NEG
NEG
403001511
208 00000.
NEG
. 010
NEG
NEG
-------
Table 6-2-a. 1977 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
ANNUAL CFA 3G
MODIFIED
see
4030m e?o
*03001£21
40 300200 0
<~03002010
*~03002011
403002020
403002021
4030020^0
403002031
403002040
403002041
403002050
403002051
403002060
403002061
403002070
<~03002071
HYDR OC A9 D ON EVAPORATICN
PATES ANC EM ISSlOrt S Pn0JECTEC TO 19 77
PflGF 5
fx UN D AT E = NCV 16,1977
TAC3F
(SCC LNITS)
266 C00O 0.
26600000.
6920000.
6920000.
1900000.
19 C 0001.
11140000.
111*0000.
55000000.
5500000 0.
89700.
89700.
52000.
52000.
154000.
154000.
EMISSIONS (MILLIONS OF TONS / YEAR)
NOX
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
HC
. HI3
. 013
. 194
. 046
. 046
.003
.00 3
. 059
~ 059
. 086
.086
.noo
. 000
. 00 0
.000
• 000
. 000
CO
NEG
NEG
NEG
NF G
NEG
NEG
NEG
NEG
NEG
NEC-
NF G
NEG
NEG
NE G
MEG
NEC-
NEG
PAFT
NEG
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
NFG
NEG
NEG
NEG
40 3003009
19 3 6 0000
NEG
.081
NEG
NEG
-------
Table 6-2-a. 1977 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYO^OCA^ION EVAPORAT
TIN
V
o
m
ANNUAL SHA3GE
RATES ANt EHIS
SIONS PROJECTED TO l^"'?
SUN GATE =
NOV 16,1977
MODIFIED
see
T ACS F
(SCC UNITS)
EMISSIONS
MOX
(MILLIONS OF TONS
HC CO
/ YEA")
PART
<*030113020
183f 0000.
NEG
. 181
N^G
NEG
403999000
15000000.
NEG
. 069
NEG
NEG
403999 «90
15 0 00000 .
NEG
. 069
NEG
NEG
<~06001000
321^000.
NEG
. 210
NEG
NEG
406001010
19971000.
NEG
. 124
NFG
NEG
<~0600 1011
4060 01012
71000.
19900000.
NEG
NEG
. 000
. 123
NEG
NEG
NEG
NEG
<~06001020
24eeoon,
NEG
. 013
NEG
NEG
<*06001021
<~06001022
56003.
2430000.
NEG
NEG
. 000
. 013
NEG
NE C
NtO
NFG
406001260
46577000.
NEG
. 057
NE G
NEG
<~06001261
<~06001262
77000.
46500000.
NEG
NEG
. ooo
. 057
NEG
NEG
NEG
NEG
4060012 "'O
13160000.
NEG
. 016
NEG
NEG
<~06001271
<~06001272
36 0000.
12800000.
NEG
NEG
. 000
. 015
NEG
NEG
NEG
NEG
<~0600200 0
117 600000.
NEG
. 147
NEG
NEG
<~06002010
406002020
<~06002260
406002270
18300000.
llOOQOOO.
18300000.
70000000.
NEG
NEG
NEG
NEG
.016
. 008
. 012
. 112
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
-------
Table 6-2-b. 1977 HC EVAPORATION UNCERTAINTIES
HrtHOCARPON
EV APCRAT ICN
°fi GE 1
t acp fl rn e
MISSION UNCESTAINT
IES dROJFCTE
1 TO 19 7 7
-UN 0 AT E =
NOV 16,
1977
CD I FIE Q
T AC
-------
Table 6-2-b. 19 77 HC EVAPORATION UNCERTAINTIES (Continued)
HYDR0CAR30N "VOFORATICN
TACR ANO EMISSION UNCE ST AIMIES PROJ ECT E "1 TC 197*
°flGE ?
=UN DATE= NOV 16,1977
MODIFIED
see
4 0 2001013
40200 101 ti
40200101 E
40200101f
<*02001017
402001019
402001019
4 0200 200 0
*0?002010
402002011
40200201?
402002013
402002014
40200201 E
40200 2016
402002017
40200 2018
T ACS F
CSCC INITS)
ie74.
1 £74.
1 £37.
1637.
27 52.
2 752.
1670.
1670.
241.
241.
60 8.
608.
198.
193.
3922000.
3893700.
3922000.
3893700.
54 70 fi.
54708.
8775.
9775,
5 9 696.
59896.
11 €21.
11621.
3889700.
3869700.
475110.
69350.
2515.
2515.
32145.
32145.
NO*
EMISSIONS (MILLIONS OF TONS / YEA»)
NEG
MEG
NEG
NIG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
f>'EG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
HC
. 00 2
. 002
. C02
. 002
. 00 3
. no 3
. nn2
. CO 2
. 001
. noi
. om
. 001
. ooo
. coo
. 217
. 189
. 217
. 189
. 026
. 026
. 002
. 002
. 127
. 027
. Cll
. Oil
. 192
. 182
.090
. 013
. 001
. 001
. 019
. n 19
CO
NE G
NEG
NF C
NEG
NEG
NEG
NE C-
NE G
NF G
NEG
NEG
NE G
NEG
NE G
•NE r,
NE G
NEG
NEG
NEG
NF G
NEG
NEG
NEG
NEG
NE C-
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
DftOJ
NEG
N c.
NEG
NF.G
NF G
NEG
NF G
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NF G
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
-------
Table 6-2-b. 1977 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON ~VAP ORATION
TACR AHn EMISSION UNCtFT AI MIES F=?CJ£CTEO TO 1977
PAGE 3
UN ~ AT T = NOV 16,1977
MOOIFIEC
SCC
402002019
402003000
<4 02003010
40200 3011
40200 3013
402003014
4Q2003011
402003019
40 20040 0 0
40 2004010
402004011
402004012
402004015
402004017
T ACRF
CSCC UMTS)
135190.
135190.
31^25.
31425.
31425.
21^25.
21384.
3138<*.
1591.
1591.
109.
109.
36.
36.
88.
88.
13532.
13532.
13532.
13532.
3584.
3584.
1300 3.
13008.
1034.
1034.
5.
5.
MO X
EMISSIONS (MILLIONS CF TONS / V£AR)
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
HC
. 314
. 014
. C27
. >127
.027
. 027
• 027
. 027
. 001
. C01
. 000
. 000
. 000
. 000
.000
. 000
. Oil
. Oil
.011
. Oil
. 005
. 005
. nio
. 010
. 001
. 001
• ooo
. 000
CO
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NE G
NEG
NEG
NEG
NE G
NEG
NE G
NFG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
NF G
NEG
NEG
NEG
NEG
NEG
PAFT
NEG
NEG
NEG
NtG
NEG
NEG
NEG
NEG
NEG
NFG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
-------
Table 6-2-b. 1977 HC EVAPORATION UNCERTAINTIES (Continued)
HYCHCCA-'.BQN rVfFORATTCN
DA GE
TACR A hO EMISSION UNCEPT AIMIES PR0JECTE1 TO 197"
MODIFIED
SCC
402005000
402005010
402005011
<+02005012
402005013
•~02005016
402005017
402006000
402006010
402006011
402006012
40200601
402006016
402006011
402006019
-UN 0 AT r = NOV 16.191
TACRF
(SCC LNIT3I
63=97.
53<07.
53907.
53907.
14346.
14346.
51923.
51923.
2051.
2051.
49.
49.
26.
26.
102430.
1021.30.
102*30.
102430.
102 220.
102220.
6552.
6552.
105.
105.
{74.
874.
36.
36.
12.
12.
NOX
EMISSIONS TRILLIONS CF TONS / YEA?)
MEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
HC
.031
. 031
. 031
. 031
. 011
. Oil
. 029
. C29
. 002
. 002
. 000
. 000
. 000
. 000
. 113
. 113
.113
. 113
. 113
. 113
. 00 4
. 004
.000
. 000
. 301
. 001
. 00 0
. 00 0
. 000
. 000
CO
NFC
NFG
NEG
NEG
NEG
NE C-
NEG
NEG
NEG
NEG
NEG
NEG
NEG
N£ G
NEG
NE C-
NEG
NEG
NEG
NEG
NEG
NE G
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
PART
NEG
NEG
NEG
NEG
NcG
NEG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
MEG
NEG
N^G
NEG
NEG
NEG
NEG
NEG
NEG
NLG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
-------
Table 6-2-b. 1977 HC EVAPORATION UNCERTAINTIES (Continued)
0
1
HYH 5
CCA°P0N
- V AFC° AT
I CN
TACR bhO
EMISSION UNCERTAINTIES
FROJECTE
0 TO 197
T
RUN D ATE =
MODIFIED
T AC3F
EM
ISSICNS
(MLLIONS CF TONS
see
CSCC UMTS)
N0X
HC
CO
2*0200700(1
~ 106670.
NEG
~
.120
NEG
106673.
NEG
-
. 12?
NEG
'~0200 7010
~ 106670.
NEG
~
. 120
NEC-
106670.
NEG
-
. 122
NEG
402007011
~ 32039.
NEG
~
. 120
NEG
32039.
NEG
-
. 122
NEG
402007012
~ 26.
NEG
~
. 00 0
NEG
26.
NEG
-
. 000
N£ C
402007013
~ 100130.
NEG
~
. 001
NEG
100130.
NEG
—
. 002
NEG
40200701
~ 1001.
NEG
+
. 001
NEG
1001.
NEG
-
. 000
NEG
402007015
~ 18021.
NEG
~
. 00 0
NEG
18021.
NEG
*
. 000
NEG
402008000
«¦ 33707.
NEG
~
. 021
NEG
33707.
NEG
-
. 021
NEG
<~02008010
~ 33707.
NEG
~
. 021
NEG
33707.
NEG
—
. 021
NEG
402008011
* 7 ?32.
NEG
. 007
NEG
7C. 32.
NEG
—
. CO 7
NEC-
402008012
~ 32760.
NEG
•f
. 020
NEG
32760.
NEG
. 020
NEG
402999000
~ 287690.
NEG
~
. 044
NEG
2€ 7690.
NEG
—
. 044
NEG
402999990
*¦ 267690.
NEG
~
. 044
NFG
287690.
NEG
—
. 044
NEG
403001000
NEG
~
.<~25
NEG
NEG
-
. 321
NE C-
NOV
/ YE
P A G F
16, 19^
A k)
P A = T
N E G
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NfG
. 002
. 002
.00?
.002
NEG
NEG
-------
Table 6-2-b. 1977 HC EVAPORATION UNCERTAINTIES (Continued)
H YOR
0CARF0N rV flF OkAT
I CM
PAGE 6
TACR ANT E
MISSION UNCERTAINTIES
P^CJECTET 10 1977
RUN
~ ATE =
NOV
16*
1977
MCDIFIEC
see
T ACRF
CSCC UMTS)
EMISSIONS
NOX
(*IL LIOKS OF
HC
TONS
CO
/ YEAS)
P APT
~ Q 300 1010
~ 3969900.
3969900.
NEG ~
NEG
. 257
.265
N E G
NFC
NEG
NEG
403001011
~ 3 96 = COO.
39E99O0.
NEG ~
NEG
.257
. 265
NEG
NEG
NF G
NEG
<~03001020
~ 1216600.
1120000.
NEG *¦
NEG
. P36
. 033
NEG
NF G
MEG
NEG
4 0 3001021
~ 1216(00.
1120000.
NEG ~
NEG
. 036
. 033
NEG
NEG
NEG
NEG
4D3001030
+ 60299000.
320CG001.
NEG +
NFG
. 313
. 166
NF G
NEG
NEG
NEG
403001031
~ 6029=000.
32000000.
NEG ~
NEG
.313
. 166
NEG
NE C-
NEG
NEG
403001040
~ 27 1 500 0 .
13800000.
NEG +
NEG
. 122
. 062
NE G
NEG
NEG
NEG
<*0 300 1041
~ 27145000.
13800000.
NEG ~
NEG
. 122
. 062
NEG
NEG
NEG
NEG
40 3001050
~ 94339.
94339.
NEG ~
NEG
.001
. 001
NEG
NEG
NEG
NEG
4T3001051
~ 94339.
94339.
NEG ~
NEG
.noi
.001
NEG
NEG
NEG
NEG
403001060
~ 335U0.
335410.
N?G ~
NEG
.002
. 00 2
NEG
NEG
NF G
NEG
403001061
~ 335410.
335410.
NEG ~
NEG
.002
. 002
NEG
NEG
NEG
NEG
403001070
~ 73 0 620.
730820.
NEG ~
NEG
. 007
. 009
NEG
NEG
NFG
NEG
-------
Table 6-2-b. 1977 HC EVAPORATION UNCERTAINTIES (Continued)
HY0RQCAR50N ^VJPORATICN
TACfi ANO EMISSION UNCERTAINTIES PROJECTED Tf! 1977
* UN OAT E =
MODIFIED
SCC
'~02001071
<~03001 fOO
<~03001511
*+9300 1510
'~03001511
<*03 00 1520
<~03001521
*~03002000
<~03002010
<~03002011
<~03002020
<~03002021
T AC 3 F
(SCC UMTS)
730320.
730820.
1<*1 75000.
l
-------
Table 6-2-b. 1977 HC EVAPORATION UNCERTAINTIES (Continued)
HYOROCARRON E VAPOR 5TITN
TACP AhC EMISSION UNC E FT AI MIES PROJECTED TC 1977
RUN 0 AT E =
0
1
ts»
©
MODIFIED
see
4*03002030
<~03002031
403002040
403002041
^0300 2050
4 0300 20 51
403002060
403002061
403002070
4 03 00 20 71
403003000
403003020
TAC5P
(SCC IMTS>
3162300.
3162300.
3162200.
3162300.
10 IS 8000.
10 193000.
10198000.
101? 800 0 .
5
-------
Table b-2-b. 1977 HC EVAPORATION UNCERTAINTIES (Continued)
0
1
CSJ
HYDROCARBON E
VAFOPAT ICN
PAGE 9
TACR AM E
MISSION UNCERTAINTIES
F9CJECTEH
TO 1977
9UN DAT E =
NOV 16,1977
^OniFIED
T A C 'P
EMI
SSIONS (MILLIONS OF TONS
/ YE £9)
see
CSCC LMTS1
•sox
HC
CO
PftPT
^ 0 399909 0
~ 101E8000.
NEG
~ . 047
NEG
NFG
10199000.
NEG
- . 058
NFG
NEG
4 0 3999 <90
~ 10198000.
NEG
~ . 047
NEG
NEG
10198003.
NEG
- . C58
NE G
NEG
40 €00 1000
*¦ 87 73 700.
NEG
*¦ . 093
NE C
NEG
8773000.
NEG
- .085
NEG
NEG
<*06001010
+ 6 0 0430 0•
NEG
+ . 038
NEG
NEG
6003800.
NEG
- . cei
NE G
NFG
<~06001011
~ 107700.
NEG
* . 001
NEG
NEG
71000.
MEG
- . 000
NEG
NEG
U06001012
~ 6003300.
NEG
«¦ . 038
NEG
NEG
6003300.
NEG
- . 061
NEG
NEG
toeooio?o
~ 524440.
NEG
~ . 003
NEG
NEG
524440.
NEG
- .006
NEG
NEG
4 06001021
~ 115 i*k.
NEG
~ .noo
NEG
NEG
1154<».
NEG
- . 000
NEG
NEG
1*0 6001022
* 5 24210.
NEG
~ . tO 3
NE G
NEG
524310.
NEG
- .006
NEG
NEG
40 6001260
~ 63£3°00.
NEG
~ . 08<*
NEG
NEG
6353400.
NEG
- . 057
NEG
NEG
406001261
~ 107700.
NEG
«• . 000
NEG
NEG
77000.
NEG
- . 00 0
NEG
NEG
<~0 6001262
~ 6353000.
NEG
~ . 08U
NE G
NEG
6353000.
NEG
- .0 57
NEG
NEG
406001270
~ 527990.
NEG
~ . 012
NFG
NFG
527<=90.
NEG
- .012
NFG
NEG
406001271
~ 62241.
NEG
~ . 000
NFG
NEG
62241.
NEG
- . 000
NEG
NEG
-------
Table 6-2-b. 1977 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON IVSPCATICN PAGE 10
TftCR ft
ISSIOf UNC£?TAIMieS
FRCJECTEO
TO 1977
RUN GATE =
NOV 1^,1977
MODI FIFO
TAC5P
EMIS
SIONS
(MILLIONS OF TONS
/ YE6S)
SCO
(SGC UMTSJ
NO*
CO
pa?T
^6011272
* 52i(3HJ.
NEG
+
. 012
NEG
N^ G
52^310.
MEG
*
. 012
NEG
NEG
^06002000
~ 19^65000.
NEG
*
. 037
NF G
NEG
19^6 500 0 •
NEG
—
. C39
NEG
NEG
<~06002010
~ 12032000.
NEG
¦V
. 019
NEG
NEG
12032000.
NEG
-
.013
NF G
NEG
^06002020
* 5597300.
NEG
~
. 038
NEG
NEG
5597300,
NEG
-
. 005
NEG
NEG
<~06002260
* 12032000.
NEG
~
. Ql<*
NEG
NEG
12032009.
NEG
—
. CI 2
NEG
NF G
4 0 £00 2 270
~ 7615800.
NEG
~
.027
NEG
NEG
7615800.
NEG
-
. 03
-------
Table 6-3-a. 1982 HC EVAPORATION EMISSIONS AND CHARGE RATES
HYDROCARBON EVAPORATION
PAGE 1
ANNUAL CHANGE
RATES ANC EMIS
SI ON S PR0JECTEC TO
19*2
RUN
0 AT E =
NOV 16,1977
MOOIFIEC
see
TACRP
(SGC UNITSI
EMISSIONS
NOX
(MILLIONS 0~
H (
TONS
CO
/ YEAR)
PART
<~01001000
43230.
NEG
. 001
NE G
NEG
401001010
401001C20
** 280 0 •
430.
NEG
NEG
. 001
. 000
NEG
NEG
NEG
NEG
401002000
114600.
NEG
. 094
NEG
NEG
401002010
4 01002020
*~01002030
401002050
401002990
0.
17 0.
15613.
17 0.
97<,50.
0. 000
NEG
NEG
NEG
NEG
0.000
.001
. 005
.001
. 088
0.000
NEG
NE G
NEG
NEG
0. 000
NEG
NEG
NEG
NEG
*~01999000
133700.
NEG
. Oil
NE G
NEG
401999<90
133700.
MEG
. Oil
NEG
NEG
<~02001000
634340.
NEG
. 118
NEG
NEG
402001010
634340.
NEG
. 118
NEG
NEG
402001011
<~02 00 1012
4 02001013
4 02001014
402001015
402001016
402001017
402001018
402001019
490000.
102000.
7680.
5930.
12420.
7<70.
2860.
3860.
1623.
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
.110
. 00 6
. 000
. 000
. GO 1
. OOO
. (0 0
. 00 0
. 000
NEG
NE G
NEG
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
402002000
5944200.
NEG
. 259
NEG
NEG
402002010
5944 20 0 .
NEG
. 259
NEG
NEG
402002011
402002012
77300.
124*0 0 •
NEG
NEG
. 036
.H02
NEG
NEG
NEG
NrG
-------
Table 6-3-a. 1982 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HYDROCARBON "VAPOP.ATICN oftGF 2
ANNUAL CHANGE
RATES ANC EMISSIONS
PROJECTED TO
19 82
SUN DATE =
NOV 16,1977
MODIFIED
T ACRF
EMISSIONS
(MILLIONS CF TONS
/ YEAR)
see
(SCC INITS)
NOX
HC
CO
PAFT
*~02002013
6<*600.
NrG
. 037
NEG
NrG
*~0200 20 1 *»
16*40 0 .
NEG
. 015
NEG
NEG
*~02002015
5 *~ 7 000 0 •
NEG
. 115
NE G
NEG
*~ 0200 201 €
<~3700.
NEG
.008
NEG
NEG
<~ 0 200 201 i
35*»0.
NEG
. 001
NEG
NCG
**0200201
<~5300 •
NEG
. 026
NEG
NEG
U02002019
191000.
NEG
. ni9
NE G
N CG
<~0200 3000
*~27530.
NEG
. 113
NEG
NEG
4*02003010
*~27530.
NEG
. 113
NEG
NEG
*~ 0 2 00 3011
<~2000 0.
NEG
.111
NEG
MP G
*~0200 3013
6 600.
NEG
.002
NEG
NEG
*~ 0200 301 *«
396.
NEG
. 000
NE G
NEG
<~0200301 7
<~29.
NEG
. 000
NEG
NEG
<~02003019
108.
NEG
. 00 0
NEG
NEG
*~0200*4000
102*4*40 .
NEG
. 030
NEG
NEG
<~0200*4010
1 0 2*4*40 .
NEG
. 030
NEG
NEG
*40200*4011
*~7300.
NEG
. 01*4
NE G
NEG
<~0200*4012
50*400.
NEG
.015
NEG
NEG
*40200*401 5
<4670.
NEG
. COl
NEG
NEG
*~0 2001*01 7
69.
NEG
. 00 0
NEG
NEG
*~02005000
399150•
NEG
. 092
NEG
NEG
*~02005010
399150.
NEG
. 092
NEG
NEG
*~02005011
163500.
NEG
. 043
NEG
NEG
<~02005012
201600.
NEG
. 046
NEG
NEG
*~02005013
8500.
NEG
. 002
NEG
NEG
*~0200501 6
23*4.
NEG
. 000
NEG
NEG
-------
Table 6-3-a. 1982 HC EVAPORATION EMISSIONS AND CHARGE RATES
(Continued)
HYDROCARBON EVAPORATION
ANNUAL CHA^G" SATES ANC EMISSIONS PROJECTED TO 1982
MODIFIES
SCC
*~02005017
TACRF
(SCC UNITS)
31 5.
NOX
NEG
EMISSIONS (MILLIONS OF TONS
HC CO
PAGr 3
?UN 0ATF = NOV 16,1977
~ YEAR)
. noo
MEG
P Af; T
NEG
o~-
t
cj
m
k02006000
<•02006010
<~02006011
<~02006012
if 0200601 <*
<~ 0 200601 £
40200601 »
<>02006019
<~ 0 200 700 0
<~02007010
<*0200 7011
*~02007012
<~02007013
•~0200701*
1*0200701 5
137f?:-00.
1370300.
13n3000.
25200.
379.
<*157.
<~10.
10
-------
Table 6-3-a. 1982 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
hyo^oca^on "VAPORATICN
PAGE 4
ANNUAL CHANGE
^ATES ANC EMISSIONS
PROJECTED TO
1982
-UN 0ATF =
NOV 16,
1977
MCDIFIEC
see
TACRF
(SCC UNITS)
EMISSIONS
NO X
MILLIONS CF TONS
HH CO
/ YE SRI
P ApT
403001000
NEG
. 082
NEG
NEG
<-03001010
0.
0. 000
o. aoo
n.oo o
0.000
'~03001011
0.
0. ooo
o. "oo
0 . 00 0
0.000
<*030010?0
0.
i. ono
0. 000
0.00 0
0.000
403001021
0.
3. 000
o. noo
fl .00 0
0.000
4 030010 30
0.
n. ooo
0. 000
0.000
0. 0 on
<~03001031
0.
0. 0 00
0. 000
0.000
0.000
<~03001040
0.
0. 000
0. 000
0.000
0 . 000
403001041
0.
0. 000
0. 000
0.00 0
0.000
403001050
124000.
NEG
. 002
NEG
NEG
<~0300 10 51
124000.
NEG
. 002
NFG
NEG
403001060
500000.
NEG
. 004
NE G
NEG
<~03001061
500000.
NEG
. nou
NE G
NEG
4 0 3001070
6937 60 0.
NEG
. 050
NEG
NFG
4Q300 1071
6937600.
NEG
. 050
NEG
NFG
403001500
52770000.
NEG
. 027
NEG
NEG
403001501
1570000.
NEG
. 002
NEG
NEG
403001 510
20800000.
NEG
. 010
NEG
NEG
40 3001511
20800000.
NEG
. 010
NE G
NEG
-------
Table 6-3-a. 1982 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
HY D R DC AD TON ~ V AFOR A T I CN
ANNUAL CHA'Gi *?A TES A N C EMISSIONS ^.OJECTEH TO 1 9 H2
PAGE 5
'UN DATE = MOV 16,1977
o
¦
—J
MODIFIED
SCO
40300152 0
<~0300 1521
<~0 300 200 0
<~03002010
4 0 3 002011
4 0300 2020
4 0300 2021
<~03002030
403002031
403002040
403002041
403002050
403002051
403002060
403002061
403002070
403002071
T ACRF
(SCC LNITS)
30*00000.
3QJ*00000 •
192QOOO.
1920000.
0.
0.
130^0000.
13040000.
86000000.
36000000.
89700.
89700.
52000.
52000.
15^000.
154000.
NOX
NEG
MEG
MEG
NEG
NEG
0. 000
0. 000
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
EMISSIONS (MILLIONS CF TO^S / YE A")
HP,
. 014
. 014
. ?17
.013
. 013
0 . 000
O. 000
. f!69
. 069
. 135
. 135
. 000
. 000
. 000
. ono
. 000
. 000
CO
HE G
NEG
NEG
NEG
NEG
0.000
0.000
NEG
NE C-
NFG
NEG
NEG
NEG
NEG
NEG
NE G
NEG
3 ART
NEG
NtG
NEG
NEG
NEG
o. ooo
o. ooo
NFG
NEG
NtG
NEG
NEG
NtG
NEG
NFG
NFG
NEG
403003000
35860000.
MEG
. 157
NEG
-------
Table 6-3-a. 1982 HC EVAPORATION EMISSIONS AND CHARGE RATES (Continued)
ANNUAL CHANGE TES A NC
HYDxOCAP 90M EVAPORATION
MISSIONS °?CJ£CTE0 TO 19*2
^ UN
MODIFIED
SCC
4 0300 3020
*4 9 3999 0 0 Q
40399999H
4 06 001000
<+06001010
406001011
406001012
4060010 20
406001021
406001022
406001260
4 06001261
406001262
406001270
406001271
406001272
TACftf
(SCC LNITS)
35860000.
15000000.
15000000.
8 361600 0.
4900000.
0.
4900000.
2011000.
11000.
20 0000 0 .
61500000.
0.
61500000.
1520500Q.
405000.
14800000.
NO X
NEG
NEG
NEG
NEG
NEG
0. 000
NEG
NEG
NEG
NEG
NEG
0. 000
NEG
NEG
NEG
NEG
EMISSIONS (MILLIONS OF
HC
PAGE i
DATE = NOV 16,1977
/ YEA3>
. 157
. 069
. 06 9
. 057
. 030
0 . 000
.0 30
. Oil
. noo
. tn
. 013
0. 000
. 013
. 003
. 000
. no3
TONS
CO
NEG
NEG
NEG
NEG
NEC
0.000
NEG
NEC-
NEC
NEG
NEG
0.000
NEG
NEG
NEG
NE G
PAST
NEG
NEG
NEG
NEG
NEG
0. 0 00
NEG
NEG
NEG
NEG
NEG
0. 000
NEG
NEG
NEG
NEG
406002000
406002010
406002020
406002260
406002270
112600000.
3300000.
6000000.
3300000.
100000000.
NEG
NEG
NEG
NEG
NEG
. 239
.001
. 002
. 000
. 235
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES
0
1
ro
vO
4YD<0CARQQN r
VflPGR AT
ICN
TACP AND E
MISSION UNCE FT AI NTIES PPOJECTE )
TG 198
2
RUN DATE =
MODIFIED
TACRF EMISSIONS
(MILLIONS Or TONS
see
(SCC UNITS) NOX
HC
CO
401001000
~ 35C91. NEG
~
. 00 6
NE C-
22C99. NEG
. 000
NEG
401001010
* 2209 5. NEG
~
. 00 4
NEG
*~01001020
22095. NEG
•
. noo
NF G
«• 28284. NEG
~
. 1304
NEG
43 0. NEG
-
. noo
NEG
<~01002000
* 110720. NEG
*
. 10 2
NE G
97660. NEG
-
. 088
NE C-
4 01002010
* 0. ~ o.ono
~ 0
. 000
~ o.ooe
*~01002020
0. 0,000
- 0
. 00 0
- 0.00 0
* 230 4. NEG
~
. 00 2
NF G
4 010020 30
E70. NEG
—
. C01
NE G
~ 6307. NEG
¥
. 010
NEG
t* 01002050
6307. NEG
. 003
NEG
~ 3667. NEG
~
. 00 3
NEG
970. NEG
—
. 001
NEG
<~01002990
~ 110450. NEG
~
. 101
NEG
97450. NEG
. C88
NEG
<~01999000
~ 3<« £75. NEG
~
. 018
NE G
34 €75. NEG
-
.011
NEG
401999990
*¦ 34C75. NEG
«¦
. 018
NEG
3C, €75. NEG
. Oil
NEG
<~02001000
~ 8<»*14. NEG
~
. 174
NEG
8<«814. NEG
-
. 084
NEG
<~02001010
* 8<»ei4. NEG
~
. 174
NE G
8<»81
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVAPORATION PAGE 2
TACR ANH EMISSION
UNCERTAINTIES
PRCJFCTE1
TO 1 38 2
RUN DATE =
NOV 16,1977
MCOIFIED
TACQF
EMI
SCIONS (MILLIONS OF TONS
/ YEAR1
SCC (SCC UNITS)
NOX
HC
CO
PART
<~02001013 «•
2S96.
NEG
~ . 004
NEG
NEG
2<=96.
NEG
. 000
NEG
NEG
402001014 *¦
2926.
NEG
~ . 003
NE C
NEG
2?2b.
NEG
- . COO
NEG
NEG
U02001015 ~
5248.
NEG
«- . 006
NEG
NEG
5243.
NEG
. 000
NEG
NEG
402001014 *
3016.
NEG
~ .004
NEG
NEG
3016.
NEG
- . 000
NEG
NEG
402001017 ~
368.
NEG
*¦ . 001
NEG
NEG
368.
NEG
- . ooo
NEG
NEG
<~02001018 ~
1108.
NEG
~ .00 2
NEG
NEG
1106.
NEG
- . OOO
NEG
NEG
<+02001019 ~
327.
NEG
~ .001
NEG
NEG
327.
NEG
- .000
NEG
NEG
<~02002000 ~
7563000.
NEG
~ . 277
NEG
NEG
54 7<4 90 0 .
NEG
. 131
NEG
MEG
<~02002010 ~
7563000.
NEG
~ . 277
NEG
NEG
5474900.
NEG
- . 131
NEG
NEG
402002011 »
105380.
NEG
~ . 049
NEG
NEG
77300.
NEG
- . 036
NEG
NEG
<~02002012 ~
16916.
NEG
~ . 003
NEG
NEG
12<«00.
NEG
- .002
NEG
NEC-
<~02002013 *
115480.
NEG
«¦ . 05!»
NEG
NEG
84600.
NEG
- . 037
NEG
NEG
<~0200 201*4 ~
22291.
NEG
~ . 020
NEG
NEG
16^00.
NEG
- . 015
NEG
NEG
<~02002015 ~
7496700.
NEG
~ . 192
NEG
NEG
5470000.
NEG
- .115
NEG
NEG
<~02002016 *¦
950050.
NEG
~ . 181
NEG
NEG
43700.
NEG
- . 008
NEG
NEG
<~02002017 +
4 £36.
NEG
~ . 001
NEG
NEG
3540.
NEG
- . 001
NEG
NEG
<~02002018 ~
61U2.
NEG
~ .036
NEG
NEG
-
<~5300.
NEG
- . 026
NEG
NEG
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVJPCRATinh PAGE 3
TACF AND E^ISSIO^ UNCEFT AI f»,T 1ES FRCJECTEO TO 131*?. RUN D AT E = NOV 16,1977
MODIFIED TAC5P EMISSIONS (MILLIONS OF TONS / YEAR)
SCC (SCH UNITS) NOX HC CO PA F T
<~0200201° ~ 260410. NEG +¦ .026 NEC NFG
191000. NEG - .019 NEG NEG
40 2003000 ~ 56373. NEG ~ .165 NFG NFG
56378. NEG - .085 NEG NEG
<~02003010 ~ 5 637 fi. NEG ~ .165 NEG N-G
56378. NEG - .065 NEG NEG
*~02003011 + 56220. NEG ~ .165 NEG NEG
56320. NEG - .085 NEG NCG
as 402003013 ~ 2549. NEG «¦ . 003 NEG NEG
i - 2549. NEG - .001 NEG NrG
w 402003014 *¦ 195. NEG ~ . 000 NEG NEG
~ - 195. NEG - .COO NEG NEG
<~02003017 ~ 55. NEG ~ . 000 NEG NEG
55. NEG - .000 NEG NEG
*~02003019 ~ 89. NEG ~ . 000 NEG NEG
89. NEG - .000 NEG NEG
<~0 2004000 ~ 26144. NEG * . 033 NEG NEG
26144. NEG - .017 NEG NEG
402004010 ~ 26144. NEG ~ .033 NEG NtG
26144. NEG - .017 NEG NEG
402004011 ~ 6456. NEG + .022 NEG NEG
6456. NEG - .011 NEG NEG
402004012 ~ 25257. NEG ~ .024 NE& NEG
25257. NEG - .013 NEG NEG
402004015 ~ 1<73. NEG ~ .002 NEG NEG
1973. NEG - .001 NEG NEG
402004017 ~ 8. NEG *¦ .000 NEG NEG
8. NEG - .000 NEG NEG
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON "VAPORATICN
TAC& ftfD EMISSION UNC ErT AlNT IE S FROJECTE') TO 1982
PAGE 4
RUN DAT F = NOV 16,1977
MODIFIED
see
402005000
<~02005010
402005011
402005012
*~0200 5013
402005016
<~0200501 7
<+02006000
4 02006010
<~02006011
<~02006012
<~02006014
<~0200601 €
<~0200601 7
<~02006019
TACRF
(SCC UNITS)
10 4 26 0 .
1G4260.
1 O<«260.
104260.
25756.
25756.
100980.
100980.
3310.
3210.
88.
83.
<~0.
40.
183970.
183970.
183970.
18 3970.
183520.
183520.
12/27.
12727.
187.
187.
1580.
1580.
54.
5 4.
21.
21.
NO X
EMISSIONS (MILLIONS OF TONS / YEAR)
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
h r.
. 098
. 053
. 198
. H53
. 065
. 0 33
. 07 3
. 041
. 00 4
. 002
. 00 0
. 00 0
. 000
. 000
• 453
. 21 8
.453
. 218
. <-5 3
.218
. 009
. 005
. 00 0
. 00 0
. C01
. 001
. COO
. 000
. noo
.000
CO
NEG
NEG
NE C
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
MEG
NEG
NEG
NE G
NEG
NEG
NEG
NE G
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NE G
NEG
PAST
NEG
NEG
NEG
NEG
NFG
NFG
NFG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NFG
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HYQROC/UeON "VePORATICN PAGF 5
TACP A NO FMISS
UNCERTAINTIES
PROJECTED
TO 1982
RUM OATE-
NOV 16,1977
MODIFIED
T AC^P
£M IS
SI CNS
MILLION'S OF TONS
/ Y E A < )
see
(SCC UNITS)
NOX
HC
CO
PA FT
<~02007030 #¦
107080.
NEG
~
. 125
NEG
NcG
107080.
NEG
—
. 186
NEG
NEG
<~02007010 ~
107080.
NCG
~
.125
NE G
NEG
107080.
NEG
-
. 186
NEG
NEG
'~0200*7011 ~
32159.
NEG
¥
. 125
NEC-
NiG
32159.
NEG
-
. 186
NEG
NEG
<*02007012 ~
26.
NEG
*¦
. noo
NEG
NEG
26.
NEG
-
. noo
NEG
NEG
U02007013 ~
100 E20.
NEG
4-
. 001
NEG
NEG
100 520.
NEG
-
. C07
NEG
NEG
<~0 200 70 I <» ~
1005.
MEG
~
. 001
NE G
NEG
1005.
NEG
-
. 000
NEG
NE G
<*02007015 *
leoea.
NEG
*¦
.000
NEG
NFG
1808^.
NEG
•
. 001
NEG
NCG
402008000 *
65220.
NEG
«-
. P62
NEG
NEG
65220.
NEG
-
.034
NEG
NEG
<~02008010 ~
65220.
NEG
~
.062
NEG
NEG
65220.
NEG
-
. ri3u
NEG
NEG
<*02008011 ~
1<»272.
NEG
. 038
NEG
NEG
1<»272.
NEG
—
. 020
NEG
NEG
<~ 0 2008012 ~
63639.
NEG
~
. 0<*9
NEG
NEG
63639.
NEG
•
. 028
NEG
NEG
<~02999000 ~
<~70300.
NEG
~
. 112
NEG
~ .003
<~70300.
NEG
—
. 112
NEG
- . 003
<*02999990 ~
<~70300.
NEG
~
. 112
NEG
+ .003
•
<~70300.
NEG
—
. 112
NEG
- . 003
<*03001000
NEG
*
. 017
NEG
NEG
NEG
-
. 035
NEG
NEG
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HYORGCAP PON EVAPORATION
TACR AN 3 E MI SS 10 U NCE FT A INTIES
MCDIPIEO TAC*F
SCC
4 03001010
403001011
*~0 30 01020
4 0 3001021
403001030
<~03001031
403001040
403001041
<~03001050
<*03001051
<~03001060
<~03001061
<~03001070
FRCJfCTEn TO 196 2 fcUN HAT E =
EMISSIONS (MILLIONS OF TONS
PAGE i
NOV 16»197 7
/ YEA")
(SCC LNITS 1
NOX
HC
CO
PAPT
0.
~
0. 000
f
0 . 00 0
0 . 00 0
~
0 . 000
G.
—
0. 000
—
0.000
—
0.00 0
-
0. 000
0 .
~
0. 000
~
0. noo
+
o. oo n
~
0.000
0.
—
0. 000
—
0 . 000
-
0.00 0
-
0.000
0.
*
0. 000
~
0 . (10 0
~
0. 00 0
+
0. COO
0 .
•
0. 000
—
0.000
—
0. 000
-
0. 0 00
0.
~
0. 000
¦f
0. 000
~
0.000
*
0.000
0.
—
0. 000
—
0 . 000
—
0.00 0
-
0. 000
0.
+
0. 000
~
0 . 00 0
•f
0. 00 0
~
0.000
9.
—
0. 000
—
0 . 00 0
—
0.00 0
-
0.000
0 .
~
Q.O 00
~
o. noo
~
0.00 0
~
0. 000
0.
0. 000
—
0. 00 0
—
o.oon
-
a. ooo
0.
«¦
0. 000
~
0 . 000
+
0. 00 0
~
0. 000
0.
—
0. 000
-
0. 000
-
0.000
-
0.000
0.
~
0. 000
~
0 . 000
~
0.000
~
0. 0 00
0.
—
0. 000
—
o. noo
—
0.000
-
0.000
128060.
NEG
*
. 002
NEG
NEG
124000.
NEG
. 002
NEG
NEG
128060.
NEG
~
. no2
NEG
NEG
124000.
NEG
—
. 002
NEG
NEG
500000.
NEG
~
. 0G4
NEG
NEG
500000.
N^G
—
. 004
NEG
NEG
500000.
NEG
~
. <104
NEG
NEG
500000.
NEG
—
. 00 4
NEG
NEG
896440 .
NEG
~
. 008
NEG
NEG
896440.
NEG
-
. 032
NEG
NEG
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HY'HOCA^BON EVCPORATICN
TftCR AMI EMlSSIOf' UNCERTAINTIES °RCJECTE1 TO 1982
RUN 0ATE = NOV
PAGE 7
16,1977
i
u>
Ul
MODIFIED
SCC
U030010^1
<~03001 !00
<+0 2001501
4 03001510
<~03001511
40300 1520
<~03001521
4 03002000
4 0 3002010
49300 2011
403002020
4 0300 20 21
TACRF
(SCC UNITSI
896*40.
8 <=€440.
28339000.
26323000.
176 0000.
1570000.
20000000.
20000000.
20000000.
20 0 0 000 0.
20000000.
20QC00O0.
20000000.
20000000.
7982900.
1920000.
7962900.
1920000.
0.
0.
0.
0.
no y
EMISSIONS (PILLIONS OF TONS / YEAR)
HC
CO
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
*¦ 0.000
- 0.000
~ 0.000
- 0.000
00 8
032
014
014
002
C02
010
nio
010
010
010
010
010
010
. 149
. 140
. 053
. ni3
. 053
. 013
0 . 000
0. 000
O .000
0.000
NEG
NEG
Nr C
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
~ 0.000
- 0.000
~ 0.000
- 0.000
PAST
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
NEG
NEG
NEG
MEG
NEG
NEG
NEG
NEG
NEG
~ 0.000
- 0.003
~ 0,000
- 0.000
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HY DROC A3, BON EVAPORATION PAGE 8
TftCR ft NO E^ISSIOf* UNCERTAINTIES PROJECTED TC H82 kUN DATE = NOV 16,1977
*1ODIFI~0 TACSP EMISSIONS (MILLIONS OF TONS / YEAR)
SCC (SCC UNITSJ NOX HC CO PA FT
4 0 300203H ~ 8062200. NEG ~ . 043 NF G NEG
8062300. NEG - .058 NEG NEG
403002031 f 8062300. NEG f .0^3 NEG NEG
8062300. NEG - .(158 NEG NEG
403002040 4- 20100000. NEG ~ .133 NEG NEG
20100000. NEG - .126 NEG NEG
4 0300 20** 1 ~ 20100000. NEG ~ .133 NEG NEG
20100000. NEG - .126 NEG NEG
40300 2050 ~ cci,08. NEG «• . 000 NEG NEG
89700. NEG - .000 NEG NEG
4 0 300 2051 ~ <=gi08. NEG ~ . 000 NEG NEG
89700. NEG - . COO NEG NEG
403002060 ~ 45276. NEG ~ .000 NEG NEG
45276. NEG - .000 NEG NEG
403002061 ~ *45276. NEG «¦ . 000 NEG NEG
45276. NEG - .000 NEG NEG
403002070 * 135830. NEG ~ .000 NEG NEG
135830. NEG - .000 NEG NEG
403002071 ~ 135830. NEG ~ .000 NEG NEG
135830. NEG - . tOO NEG NFG
403003000 ~ 90
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HYDROCARBON EVAPORATION
PAGE 9
TflCR A NO EMISSION UNCERTAINTIES PROJECTED TO 198? ?
UN
D AT F =
NOV 16,
197 7
MODIFIED
see
TAC3F
-------
Table 6-3-b. 1982 HC EVAPORATION UNCERTAINTIES (Continued)
HYO
ROCARBON "V0PORAT
I CN
PAGE 10
TACR AND i
EMISSION UNCERTAINTIES
PROJ ECTE1 TO 198
2
RUN
DATE =
NOV 16,197 7
MODI FIE C
TAC3F
EMIS SlONS
(MILLIONS 0F
TONS
/ YEAR)
see
(SCC UNITS)
NOX
HC
CO
PAPT
40600127?
«¦
910820.
MEG f
.026
NEG
NEG
•
910820.
NEG
. 003
NEG
NEG
40 6002000
~
*~1372000.
NEG ~
. 114
NEG
NEG
-
13068000.
NEG
.123
NEG
NEG
4 06002010
27 01*4000.
NEG +
. 012
NEG
NEG
3300000.
NEG
. (101
NEG
MEG
406002020
~
11795000.
NEG ~
. COfi
NEG
NEG
-
6000000.
NEG
. 002
NEG
NEG
4 06002260
~
27014000.
NEG +
. CO 5
NEG
NEG
-
3300000.
NEG
. 000
NEG
NEG
4Q6002270
~
10630000.
NEG +
. 113
NEG
NEG
-
10630000.
NEG
. 123
NEG
NEG
-------
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, (2) 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-
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 Petroleum Institute (API) coordinated efforts as
early as 195 2 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. 7 3 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
6-41
-------
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
Gasoline Pumped,
1000 gal/yr
HC Emissions,
million tons/yr
Activity
1976
1981
1976
1981
A406004011
5, 69E7
5. 69E7
0. 138
0. 023
Vapor displacement
during fill
A40600401Z
3. 56E7
3. 56E7
0. 094
0. 016
Vapor displacement
during fill
A40600401 3
9. 14E6
9. 14E6
0. 040
0. 040
Vapor displacement
during fill
Total Sales
1. 016E8
1.016E8
0. 2 72
0. 079
A406004020
1. 016E8
1. 016E8
0. 006
0. 005
Spillage
Total
0. 278
0. 084
A406003010
5. 772E7
-0-
0. 332
-0-
Filling underground
storage
A406003020
3. 902E6
1. 040E7
0. 014
0. 038
Filling underground
storage
A406003030
1.532E7
4. 080E7
0. 006
0. 016
Filling underground
storage
A406003040
2. 401E7
5. 040E7
-0-
-0-
Filling underground
storage
Total Storage
1. 016E8
1.016E8
0. 352
0. 054
Total Service
Station Activity
0. 630
0. 138
6-43
-------
6.4. i Surface Coating
Except for motor vehicles, the 19?2 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 lb 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 1 5 °F
True Vapor Pressure 5.8 psia
Density 6.2 lb/gal
6-44
-------
Paint Factor 1.14
Tank Depth 48 ft
Tank Diameter 11 0 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 HC 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 1977 from marketing and transporta-
tion of petroleum products are principally from operations involving the
splash loading of gasoline on tank trucks (0, 12-million tons/year of HC and
the unloading of crude from marine vessels (0, 11-million tons/year of HC).
Emissions from these sources are expected to be reduced to 0. 03-million
tons/year and increased to 0.2-million tons/year of HC vapors, respectively,
in 1982. Both activities will have lower emission factors in 1982, 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 9th 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 1982.
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:
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:
(6-1)
whe re:
or
(6-2)
D
1 . 73
D
0. 27
(6 - 2a)
D
1.73
4V
TrdD
0. 27
6-48
-------
Q = 7.48 x 10"3V
(6-3)
E = Ly X 42 (gal/bbl) x P
(6-4)
and the following assumption was made:
H
= 0. 5 d
(6-5)
average
whe re
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 (lb/year)
p = liquid density at average bulk temperature (lb/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:
where the product of terms in the brackets represents the emission factor
in (lb/yr )/l 000-gal capacity:
Q
(6-6)
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)
Kt = turnover factor (dimensionless)
F - working loss (bbl/year)
The following definitions apply:
V = Q*(ifH)
E = F X 42 x p (6-10)
where
E = working loss (lb/year)
Q = annual throughput (1000 gal/year)
p = density of liquid at average bulk temperature (lb/gal)
Substituting Eqs. (6-9) and (6-10) into the API equation,
Eq. (6-8), for working losses yields:
E = [lOOO CpP kJq (6-11)
where the product of terms in the brackets represents the emission factor in
(lb/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:
where
L = K.K K K D1' 5 /. . pT' (6-12)
y t s c p \14.7 - PI
L = standing loss (bbl/year)
= tank-type factor
K = seal factor
s
K = fluid factor
c
K = paint factor
P
D = tank diameter (ft) , j.
(for D> 150, replace D " with 12.25D)
w = average wind velocity (mph)
The following definitions apply:
d'-5 = ^= (6.13)
¦ndy/D
V " TT55 Q (6-14)
E = 42 X p X L (6-15)
K y
where
Y = volumetric capacity (cu ft)
Q = volumetric capacity (1000/gal)
d = equivalent cylindrical depth of the tank (ft)
p = liquid density (lb/gal) at average bulk temperature
6-51
-------
Substituting Eqs. (6-13) through (6-15) into the API equation,
Eq. (6-12), yields:
7149 p K,K K K
r t s c p
wP
\0. 7
JD d
14.7 - py
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 (lb/gal)
Q = petroleum product withdrawn (1000 gal/year)
E = emissions (lb/year)
6.5.5 Working Losses from Variable Vapor-Space
Tank Systems
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 fixed-roof 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 (lb/yr)
C = factor dependent on liquid stored
p = density of liquid at average bulk temperature (lb/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.
emissions in terms of D (average tank diameter) and Q, the capacity of the
tank with an average diameter D:
From Section 6.5. 1, the API equations yield the following
E - n x 42 pC
1. 73
1. 73
Factoring D ' and substituting the following
(6-19)
Q = 7.481 X10"3 V
(6-20)
or rearranging
D
1. 73
4Q
(6-21)
7.481 x 10"3 dD°*27TT
6-54
-------
and letting
H = 0.5 d (6-22)
and
0.49
0. 27
5020.3 F pc
n P [iA X TJ (6-23)
then, it is found that
/ 1 73 1 73
E = n x EF x Q [0.9 +1.1
E = 2. 01 x n X EF
(6-24)
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:
E = n xEF x
tt(0.9D2) d . tt(1. ID2) d~|
4 4 J
= n x EF (0.92 + 1. I2)
= n x EF x Q (0.92 + 1. I2)
= n x EF xQ X 2.02
(6-25)
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:
E = 2lcT * n X 0. 9 Q H q Tq X n 1. 1 Q
(0. 9d) (1.Id) V
= EFXQXn(o.9°-51 + l.l°-51) (6"26>
= 1. 99 7 x EF x nx Q
The EPA equations then yield the following:
E = EF X Q x 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 0.966, 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(l4.7P- p) D1"73 H°-51 AT0'5 Fp (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. , "Compute r 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, AP-42, 2nd
ed. (and supplements), U. S. Environmental Protection Agency,
Research Triangle Park, North Carolina (April 197 3).
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-74-1 2, U.S. Department of
Transportation, Washington, D. C. (August 1974).
6-58
-------
Table 6-5. VAPOR PRESSURE EFFECTS ON FIXED-ROOF
BREATHING LOSSES
Vapor
Pressure
P.a
1
(P/l4. 7 - pP'68
Ratio of Emissions Ej/Eg
(Case of Interest -f Baseline Case)
PB= 1
PB= 2
PB = 4
PB = 6
0. 5
0.103
0.609
1. 0
0.169
1. 000
0. 593
1. 5
0. 228
1. 349
0. 800
2. 0
0.285
1.686
o
o
o
0. 557
3. 0
0.396
00
<*¦>
0. 773
0.510
4. 0
0.512
1. 796
o
o
o
0. 659
6. 0
0.777
1. 504
o
o
o
¦«" 1
8. 0
1.128
2. 203
1.452
aTerms subscripted with "i" correspond to case of interest;
terms subscripted with "B" correspond to baseline case.
-------
D. a
1
6
8
10
11
12
14
20
30
40
60
80
110
140
170
210
250
e 6-6. DIAMETER EFFECTS ON FIXED-ROOF BREATHING LOSSES
c
D1'73
CXD1-73
Ratio of Emissions E^/Eg
(Case of Interest -f- Baseline Case!
a
db= 10
db= 3°
db = 60
Db= 110
Db= 170
0. 30
22. 19
6.66
0. 248
0.40
36. 50
14.60
0. 544
0. 50
53. 70
26.85
1.000
0. 075
0. 55
63. 33
34.83
1. 297
0. 097
0.60
73. 62
44. 17
1.645
0. 123
o
o
96. 12
67. 28
2. 5 06
0. 187
0.88
178.15
156.77
5.839
0.436
1. 00
359.27
359.27
1. 000
0. 301
1. 00
590. 97
590.97
1. 645
0.496
1. 00
1191.80
1191.80
1. 000
0. 350
1.00
1960.40
1960.40
1. 645
0. 576
1.00
3401. 02
3401.02
2.854
1. 000
0.471
1.00
5161.80
5162.00
1. 518
0. 715
1 . 00
7222.32
7222.00
2. 123
1 . 000
1.00
10409. 73
10410.00
1.441
1. 00
14074.60
14075.00
1.949
subscripted with "i" correspond to case of interest;
subscripted with "B" correspond to baseline cases.
-------
Table 6-7. ULLAGE DEPTH EFFECTS ON FIXED-ROOF BREATHING LOSSES
Ullage
Depth
H. a
1
H°" 51
Ratio of Emissions E-/Eg
(Case of Interest -J- Baseline Case)
hb-5
hb - io
hb = z°
hb= 25
2
1.424
0. 627
3
1. 751
0. 771
5
2. 272
1. 000
0. 702
7
2. 698
1. 188
0.834
10
3. 236
1.424
1.000
0. 707
15
3.979
1. 230
0.863
0. 771
20
4. 608
1 .424
1. 000
0. 892
25
5. 164
1. 121
1. 000
30
5. 667
1. 230
1. 097
35
6. 130
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
Tempe rature
Excursion
AT.a
1
Ratio of Emissions E^/Eg
(Case of Interest ^ Baseline Case)
atb = 5
ATb = 9
ATb = 15
ATb = 22
ATd - 30
n>
2
1.414
0. 632
5
2. 236
o
o
o
0. 745
9
3.000
1. 34 2
o
o
o
0. 775
15
3.873
1. 732
1. 291
o
o
o
0. 826
22
4. 690
1 .563
1. 211
o
o
o
0. 856
30
5.477
1.414
1.168
1. 000
40
6.325
1. 349
1. 155
50
1. 291
ct
Terms subscripted with "i" correspond to case of interest;
terms subscripted with "B" correspond to baseline cases.
-------
BASELINE PRESSURE
1 psi
LU
6 psi
U~l
-------
BASELINE DIAM
30 ft
10 ft
6C ft
170 ft
110 ft
LjJ
2
—J
LU
IS)
<
GO
UJ
LU
<0.9
o
0.8
¦z.
o
UJ
Li_
o
o
/ AP-42 BASELINE DIAM
GASOLINE
CRUDE
c
^ 0.4
300
40
60
80 100
6
8 10
20
200
TANK DIAMETER, ft
Figure 6-2. Effects of tank diameter on fixed-roof breathing losses
-------
BASELINE DEPTH
10 ft
CO
CO
20 ft
25 ft
c_>
0.9
JP-4
KEROSENE
CRUDE
DISTILLATE
£ 0.8
o
2 0.6
AP-42 ULLAGE DEPTH
= 50% OF TANK HEIGHT
GASOLINE
C£
ULLAGE DEPTH, ft
Figure 6-3. Effects of ullage depth on fixed-roof breathing losses
-------
BASELINE TEMPERATURE EXCURSION
o
CO
l/l
o
o
CO
O
AP-42 BASELINE
0.6
DAILY TEMPERATURE EXCURSION. F
Figure 6-4. Effects of daily temperature excursion on fixed-roof breathing losses
-------
SECTION VII
PRIMARY METALS
7. 1 INTRODUCTION
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-
X
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 1977 were 10.4 million tons compared to about 37.6 million tons from
all stationary point sources. These are principally from blast furnaces
(5. 6 million tons) and basic oxygen furnaces (3. 6 million tons) for
7-1
-------
pig iron and steel production. In 1982, the CO from primary metals is
expected to be reduced to 5. 7 million tons through the implementation of
improved control techniques.
The PART emissions from the primary metals industry in
1977 were nearly 1.4-million tons. The estimated nationwide total PART
emissions in 1975 from stationary point sources were 13. 5-million tons.
The estimated 1982 PART emission rate from primary metals
is 0. 65-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 for the two
years of interest is shown in Tables 7-2-a and 7-3-a, and their uncertainties
in Tables 7-2-b and 7-3-b.
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 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 lb 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
Source Category
Charge Rate Unit
30 3001000
Aluminum electrode reduction
Aluminum, tons/yr
30 3001010
Prebake cells
Aluminum, tons/yr
30 3001020
Horizontal stud soderberg
Aluminum, tons/yr
30 30010 30
Vertical stud soderberg
Aluminum, tons/yr
30 3001040
Materials handling
Aluminum, tons/yr
30 3001050
Anode bake furnace
Aluminum, tons /yr
30 300 1990
Other, not classified
Aluminum, tons/yr
30 3002000
Aluminum ore calcined
Aluminum, tons/yr
30 30020 10
General
Aluminum, tons/yr
30300 3000
Coke metallurgical byproduct
Coal, tons/yr
30 300 3010
General
Coal, tons/yr
303003020
Oven charging
Coal, tons/yr
30 300 30 30
Oven pushing
Coal, tons/yr
30 300 3040
Quenching
Coal, tons/yr
30300 30 50
Unloading
Coal, tons/yr
30 300 3990
Other, not classified
Coal, tons/yr
303004000
Coke beehive
Coal, tons/yr
30 3004010
General
Coal, tons/yr
30 300 5000
Copper smelter
a
30300 5020
Roasting
Copper, tons/yr
30 300 50 30
Smelting
Copper, tons/yr
30 300 5040
Conve rting
Copper, tons/yr
30 300 5050
Refining
Copper, tons/yr
303005060
Ore crushing,
material handling, and
miscellaneous activity
Copper, tons/yr
303005990
Other, not classified
7-3
Ore, tons/yr
-------
Table 7-1. DEFINITION OF PRIMARY METALS PROCESSES (Continued)
MSCC
Source Category-
Charge Rate Unit
303006000
Ferroalloy production, open
furnace
Produced, tons/yr
303006010
50% ferrosilicon
Produced, tons/yr
303006020
7 5% ferrosilicon
Produced, tons/yr
3030060 30
90% ferrosilicon
Produced, tons/yr
303006040
Silicon metal
Produced, tons/yr
30 30060 50
Silicomanganese
Produced, tons/yr
30 3006990
Other, not classified
Produced, tons/yr
30 3007000
Ferroalloy production, semi-
covered furnace
Produced, tons/yr
30 3007010
Ferromanganese
Produced, tons/yr
30 3007020
Ge neral
Produced, tons/yr
30 3008000
Iron production
a
30 3008010
Blast furnace charge
Produced, tons/yr
30 3008020
Blastfurnace, agglomerates charge Produced, tons/yr
30 30080 30
Sintering general
Produced, tons/yr
30 3008040
Ore-crush, handle
Ore, tons/yr
30 30080 50
Scarfing
Processed, tons/yr
30 3008060
Sand handling operation
Sand-baked, tons/yr
303008990
Other, not classified
Produced, tons/yr
30 3009000
Steel production
Produced, tons/yr
30 3009010
Openhearth noxlance
Produced, tons/yr
30 3009020
Openhearth noxlance
Produced, tons/yr
30 30090 30
Basic oxygen furnace (general)
Produced, tons/yr
303009040
Electric arc with lance
Produced, tons/yr
7-4
-------
Table 7-1. DEFINITION OF PRIMARY METALS PROCESSES (Continued)
MSCC
Source Category
Charge Rate Unit
30 30090 50
Electric arc, no lance
Produced, tons/yr
30 3009990
Other, not classified
Produced, tons/yr
30 3010000
Lead smelters
a
30 30100 10
Sinte ring
Ore, tons/yr
303010020
Blast furnace
Ore, tons/yr
30 3010990
Other, not classified
Ore, tons/yr
30 301 1000
Molybdenum
a
30 301 10 10
Mining, general
Mined, 100 tons/yr
30 301 1020
Milling, general
Product, tons/yr
30 301 1990
Process, other
Processed, tons/yr
30 3012000
Titanium processes
a
30 30120 10
Chlorination stat
Product, tons/yr
30 3030000
Zinc smelting
Processed, tons/yr
30 3030010
General
Processed, tons/yr
30 30 30040
Horizontal retorts
Processed, tons/yr
303999000
Miscellaneous metallurgical
operations
Processed, tons/yr
303999990
Not elsewhere classified
Produced, tons/yr
This represents a collection of processes whose charge rate units are
different from one another.
7-5
-------
Table
7-2-a. 1977 PRIMARY METALS EMISSIONS AND CHARGE RATES
INDUSTRIAL
PROCESS, FF.IMAPV METALS
PAGE
ANNUAL CHANGE
3ATES ANC EMISSIONS
P^OJECTEC TO
1 9 77 RUN
DATE = NOV 16,
1977
MCOIFIED
TACRF
EMISSIONS
(PILLIONS OF
TONS t YEAR)
see
(SCC UMTS >
N0X
HC
CO
P APT
303000010
19840000.
NEG
NEG
NEG
.005
30 300 1000
22338000.
neg
NFG
MEG
.103
303001010
2503000.
NEG
NEG
NEG
. 029
303001020
1132000.
NEG
NEG
NEG
.027
303001030
998000.
NEG
NEG
MEG
.0 11
3 03001040
3460000.
NEG
NEG
NEG
.005
303001050
14<40000.
0.000
0 . 000
0.00 0
. 0 00
303001990
12780000.
NEG
NEG
MEG
. 030
303002000
9046000.
NEG
NEG
NEG
.037
303002010
90^6000.
NEG
NEG
NEG
. 0 17
303003000
458400000.
.002
. 184
.056
. 07*
303003010
81900000.
. 000
.061
.025
.003
303003020
81900000.
.001
. 102
.325
. 031
303003030
880 00000.
NEG
. 009
.00 3
. 016
3 0 30 0 30 <*0
88000000.
NEG
NEG
MEG
. 010
303003050
81900000.
NEG
MEG
MEG
.0 16
3 0300 3990
36700000.
NEG
. 011
.00 4
.00?
30 3004000
1390000.
NEG
.006
.00 1
. 1??
3 03004010
1390000.
NEG
.006
.00 1
. 12?
303005000
NEG
NEG
MEG
. 340
303005020
125000.
NEG
NEG
NEG
. 0 00
303005030
1654000.
NEG
NEG
NEG
.013
30 30050^0
1654000.
NEG
NEG
NEG
.015
303005050
1654000.
NEG
NEG
MEG
. 0 04
303005060
30 00 0000 0.
NEG
NEG
NEG
. 300
303005990
1654000.
NEG
NEG
MFG
. 0 02
30 3006000
4292500.
NEG
NEG
MEG
. 132
-------
Table 7-2-a. 1977 PRIMARY METALS EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS, PRIMARY METALS
i
ANNUAL CHARGE
MODIFIED
TACRF
see
(SCC UNITS)
303006010
77240.
303006020
395000.
303006030
312220.
30 30060 40
702000.
303006050
9600 0.
303006990
2710000.
303007000
2520000.
303007010
1000000.
303007020
1520000.
303008000
303008010
80000000.
303008020
80000000.
303008030
51000000.
303008040
105400000.
303008050
117000000.
303008060
<*<*00000.
303008 <90
117000000.
303009000
1 <*<*63 000 0 •
303009010
6500000.
303009020
7700000.
303009030
64000000.
3 0 300 9 040
22100000.
303009050
6633000.
30 3009590
37700000.
303010000
6760000.
303010010
790000.
303010020
790000.
303010 <90
5200000.
303011000
PROJECTED to
1977
'UN 0ATE =
EMISSIONS
(PILLIONS OF TONS
NOX
HC
CO
NFG
NEG
NFG
NEG
NEG
NEG
NEG
NEG
NFG
NEG
^G
NEG
NEG
NEG
NEG
NEG
NEG
NE G
NEG
NEG
NEG
NEG
NEG
NE C-
NEG
KEG
NFG
NEG
NEG
6.51 e
NEG
NEG
5.60 0
NEG
fEG
0.000
NEG
NEG
.91 8
NEG
NFG
NE G
NEG
NEG
NEG
NEG
r^EG
NEG
NEG
NEG
NE G
.010
. 008
3.835
NEG
NEG
0 .00 0
NEG
NEG
0.00 0
NEG
NFG
3.55 2
NEG
NEG
.19?
NEG
NEG
.060
. 010
. 008
.02 <¦
. 000
. 000
NE G
NEG
NEG
NFG
NEG
NEG
NFG
. 000
. no a
NEG
NEG
NFG
NEG
NOV
PAGE ?
16 j197 7
/ YEAR)
PAPT
.003
. n?a
.029
. 073
.00 3
. o a*
.002
. 0 00
. C02
.<+1 3
. 0^8
. 017
.086
. 067
.010
. 003
.137
. 073
. 0 1 *4
.0 08
. 016
. 0 12
.003
. 020
.007
.003
.003
. 001
.0 12
-------
Table 7-2-a.
1977 PRIMARY METALS EMISSIONS AND CHARGE
RATES
(Continued)
INDUSTRIAL
PROCESS, PRIHAPY METALS
D AGE
ANNUAL CHA 3Gr
9ATES ANC EMISSIONS
a»OJECTE0 TO 1977 PUN
OATE =
NOV 16,1977
M OQIFIE E
see
TACRF
(SCC LNITS)
EMISSIONS (PILLIONS OF TONS
NOX HC CO
/ YEAR)
PA FT
303011010
303011020
3 0 301199 0
11^000000.
57500000.
171000000.
NEG NFG
NEG NEG
NEG NEG
NEG
NEG
NEG
• 0 06
. 003
.0 03
303012000
esooo.
NEG NEG
.00 2
NEG
303012010
65000.
NEG MEG
.00 2
NEG
303030000
155^000 .
NEG NEG
NEG
.0 05
303030010
3030300U0
6H»000.
9^0000.
NEG NEG
NEG NEG
NEG
NEG
.003
.002
303999000
32000000.
.001 .001
.00 2
.0^8
303999 «90
32000000.
.001 .001
.00 2
. 0*3
-------
Table 7-2-b. 1977 PRIMARY METALS UNCERTAINTIES
INDUSTRIAL PROCESS, FFIMARY METALS
TACP AND EMISSION UNCERTAINTIES PPCJECTEQ 10 197' PUN DAT E =
-vl
I
vO
MODIFIED
TACRF
EM
IS SIGNS
(MILLIONS
OF
TONS
see
-------
Table 7-2-b. 1977 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, PRIMARY METALS P AGF ?
TACF A KO EMISSION UNCEFTAINTIES PROJECTED TO 1977 RUN D ATE = NOV 16,1977
MODIFIED
T AC3F
EMISSIONS
(MILLIONS
OF
TONS
/ YEAR)
see
(SCC I NITS)
NO X
HC
CO
PACT
303003 99 0
~
10770000.
NEG
~
. 004
*¦
.00 1
~ .001
—
10770000.
NEG
-
. 004
-
.001
- .001
303004000
~
135720.
NEG
f
. 001
~
. oon
*¦ . 036
—
135720.
NEG
-
. 001
-
.00 0
- . 029
30300*4010
~
135720.
NEG
~
. 001
4
.00 0
«• .036
—
135720.
NEG
-
. 001
-
.000
- .029
30 3005000
NEG
NEG
NEG
~ .C5 3
NEG
NEG
NEG
- . 056
303005020
453980.
NEG
NEG
NEG
~ .0 01
—
125000.
NEG
NEG
NEG
- .000
303005030
~
170000.
NEG
NEG
NFG
~ . 012
-
170000.
NEG
fEG
NEG
- .0 19
303005040
~
170000.
NEG
NEG
NEG
.012
—
170000.
NEG
NEG
NEG
- .0 15
303005050
~
170000.
NEG
NEG
NEG
~ .002
—
170000.
NEG
NEG
NEG
- .0 03
303005060
~
40361000.
NEG
NEG
NEG
~ .050
-
40361000.
NEG
NEG
NEG
- . 050
303005990
~
170000.
NEG
NEG
NEG
~ .002
170000.
NEG
NEG
NEG
- .0 02
303006000
~
1056600.
NEG
NEG
NEG
~ .119
—
1055800.
NEG
NEG
NE G
- .081
303006010
~
16230.
NEG
NEG
NEG
~ . 0 02
-
16230.
NEG
NEG
NEG
- .002
303006020
~
84152.
NEG
NEG
NEG
~ .0 13
-
84 152 .
NEG
NEG
NEG
- .020
303006030
~
9595.
NEG
NEG
NEG
~ .017
—
9595.
NEG
NEG
NE G
- .028
303006040
~
314010.
NEG
NEG
NEG
+ . 051
—
314010.
NEG
NEG
NEG
- .073
303006050
~
10 4400.
NEG
NEG
NEG
~ .0 04
-
96000.
NEG
NEG
NEG
- .0 03
-------
Table 7-2-b. 1977 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, PRIMARY METALS PAGE .1
TACR AND E
MISSlOf> UNCEfcTAI MIES
w " — — j
PR0JF3TEQ
TO 1977 £?UN
D ATE =
NOV 16,1977
MCOIFIEC
TAC=?F
EMISSIONS
(MILLIONS
OF
TONS
/ YEA")
see
(SCC LKITSI
MO X
HC
CO
PART
303006990
~ 999€80.
NEG
NEG
NE C
~ .10 5
999680.
NEG
NEG
NEG
~ . 0 0*+
303007000
~ 6M890.
NEG
NEG
NEG
~ .002
6 <+1890•
NEG
NEG
NEG
- .002
303007010
* 215U1Q.
NEG
NEG
NEG
~ .003
21541Q.
NEG
NEG
NEG
- . 000
303007020
~ 60i«670.
NEG
NEG
NEG
~ .002
6 0 It 6 78 •
NEG
NEG
NEG
- .00?
303008000
NEG
NEG
~
1.151
+ . 2k7
NEG
NEG
-
1.151
- . 222
303008010
~ 9329*00.
NEG
NEG
~
1.10 7
+ .025
9329500.
NEG
NEG
—
1.10 7
.TK9
303009020
~ 9329500.
NEG
NEG
~
0.00 0
~ .009
9329500.
NEG
NEG
—
0.000
- . 017
303008030
~ 13000000.
NEG
NEG
+
.315
+ .083
13000000.
NEG
NEG
—
.315
.086
3030080<*0
~ **7539000 •
NEG
NEG
NEG
~ .0 7 8
*»75 3900 0 •
NEG
NEG
NEG
- .067
303008050
~ 21190000.
NEG
NEG
NEG
+ . 021
21190000.
NEG
NEG
NEG
- .010
303008060
~ 763220.
NEG
!>EG
NEG
~ .0 01
763220.
NEG
NEG
NEG
- .001
303008*90
~ 21190000.
NEG
fEG
NEG
+ . 216
21190000.
NEG
NEG
NEG
- . 187
303009000
~ 11+310000 .
*¦ .002
~
. 002
~
1.09 5
~ . 031
1^310000.
- . 010
. COS
—
1.08 €
- . 033
303009010
~ 5055900.
NEG
NEG
~
0.000
~ .0 17
5055900.
NEG
NEG
-
0.000
- . 0 1*»
3 03 009 020
~ 60(2800.
NEG
NEG
~
O.Ofl 0
~ . 0 10
6062800.
NEG
NEG
—
0.000
.0 08
303009030
~ 7^^3 10 0 .
NEG
NEG
~
1.08 i
~ .0 09
7^3100.
NEG
KEG
-
l.OSt.
- .016
-------
Table 7-2-b. 1977 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, PPIMARY METALS PAGE <+
TACR A NO EMISSION UNCERTAINTIES PR CJ E5TED TO 1 977 RUN D ATE = NOV 16,1977
MODIFIE C
T AC3P
EMIS 51 0NS
(MILLIONS
OF
TONS f YEAP)
see
(SCC UNITS)
NOX
HC
CO
PAPT
3 9 300 90U0
f 50^2^00.
NEG
NEG
+
.051 +
. Oil
5092200.
MEG
NEG
—
.065
. 0 12
303009050
«¦ 6 8 Q 07 0.
NEG
NEG
4-
.00 9 *
.003
6 £ 0070.
NEG
NEG
-
.015
.003
3 0 3009 <90
~ 7772300.
+
.002
+
. 002
~
.006 ~
. 019
7 772 20 Q •
—
.010
. 008
—
.0 ?u
.020
30 301000 0
1116'.0 0.
.000
~
. 000
NEG ~
. 003
1116 E0 0.
-
. 000
. 00 0
NEG
.0 05
303010010
~ 122070.
NEG
NEG
NEG ~
. 0 02
122070.
NEG
NEG
NE G
.003
30 3010020
~ 122070.
NEG
NEG
NEG ~
.003
122070.
NEG
NEG
NEG
. 003
303010990
~ 1103100.
+
.000
~
. 000
NEG +
. 0 00
1103100.
-
.000
—
. 000
NEG
.0 00
303011000
NEG
NEG
NEG ~
.003
NEG
NEG
NEG
. G0<»
303011010
+ 17205000.
NEG
NEG
NEG «¦
. 0 02
17205000.
NEG
NEG
NEG
.002
303011020
* 8602300.
NEG
NEG
NE C ~
. 0 02
8602300.
NEG
NEG
NEG
. 003
30 3011*90
* 25807000.
NEG
NEG
NEG +
.0 CI
25807000.
NEG
NEG
NEG
. 001
303012000
~ lieei.
NEG
NEG
+
.002
NEG
11661.
NEG
NEG
—
.00 1
NEG
303012010
«• 11661.
NEG
NFG
+
.00 2
NEG
11661.
NEG
NEG
.001
NEG
303030000
~ 2191^0.
NEG
NEG
NEG «¦
.002
2191*»0.
NEG
NEG
NFG
. 002
303030010
~ 108170.
NEG
NEG
NFG ~
. 001
108 170.
NEG
NEG
NEG
.001
-------
Table 7-2-b. 1977 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL
P°0CESS«
FF
IMAP
y me
TALS
PA
GE
TACR a no
EMISSION UNC £PT A IKTIES
P9CJECTE0
TG
197
7
RUN
DATE-
NOV 16,1
97 7
HCOIFIEO
TAC*F
EH I
SSI
ONS
I WIL
LIONS Oc
TONS
/ YEAR)
see
(SCC UNITS)
Ma x
HC
CO
P
APT
30 sosoouo
~
150590.
NEG
NEG
NEG
~
. oai
•
190 E9 0.
NEG
FEG
NE C-
—
. 0 01
SO 3999000
»
5000000.
+ .091
~
. 000
~
.00 0
«-
.0 09
-
5000000.
- . 001
-
. 001
-
.00 1
-
.009
30 3999990
~
5000000.
+ .000
~
. 000
*
.000
~
. 009
-
5000000.
- . 001
-
. 001
-
.00 1
-
.0 09
i
*-*-
LO
-------
Table 7-3-a. 1982 PRIMARY METALS EMISSIONS AND CHANGE RATES
INDUSTRIAL PROCESS, PRIMARY METALS
ANNUAL CHARGE *ATES AND EMISSIONS PROJECTED TO 1 9 S2 RUN
D AGE 1
D ATE = NOV 16,1977
MODIFIED
see
3n3000010
30300101)0
303001010
303001020
303001030
3 0 3001040
303001050
30 3001 c.90
303002000
303002010
303003000
303003010
303003020
303003030
303003040
303003050
303003990
303004000
303004010
303005000
303005020
3030n5 C30
30 3005040
303005050
303005060
3030Q5S90
303006030
T ACS F
ISCC UNITS)
20740000.
23618000,
2593003.
1172000.
1033000.
3630000.
1510000.
13680000.
9456000.
9456000.
458 4 C 000 0.
81900000.
819DOOOO.
88000000.
86000000.
81900000.
36700000.
1390000.
1390000.
0.
1654000.
16 5^00 0.
1654000.
300 000000.
1654000.
4 0 65 000.
NOV
NEG
N^G
NEG
NEG
NEG
NEG
0. 000
N£G
NEG
NEG
.002
.000
. 001
NEG
NEG
NEG
NEG
NEG
NEG
NEG
0. 009
NEG
NEG
NEG
NEG
NEG
NEG
EMISSIONS
(MILLIONS CF
HC
NFG
NEG
NEG
NEG
NEG
fEG
0.000
NEG
NEG
NEG
. 164
. 061
. 10 2
. 009
NEG
NEG
. Oil
. 006
. 006
NEG
o. noo
NEG
NEG
NEG
NEG
NEG
NEG
TONS / YEA"?*
CO PA^T
NEG .001
NEG .02?
NEG .011
NEG .010
NEG , 0 Oh
NEG .000
0.000 .000
NEG .000
NEG .009
NEG .009
.056 ,024
.02* .000
.025 .001
.003 .005
NEG .000
NEG .016
.004 .001
.001 .042
.001 .0^2
NEG .312
0.000 0.001
NEG .009
NEG ,002
NEG .001
NEC- .30 0
NFG .000
NEG .02?
-------
Table 7-3-a. 1982 PRIMARY METALS EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL P'OCESS, FFIMApv VITALS PAGE 2
ANNUAL CHANGE RATES ANC EMISSIONS OROJECTEC TO 1982 -UN DAT E = NO V 16,1977
MCDIFIE C
T AC t» P
EM!SCIONS
(MILLION-
OF TONS /
YEAR)
see
(SCC UNITS)
NOX
H C
CO
PA P T
303006010
-------
Table 7-3-a. 1982 PRIMARY METALS EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL
P "OCESS v PFlMflPy METALS
PAGE
ANNUAL CHARGE
SATES ANC EMISSION
S PROJECT t TO
19 82 9UN
DATE =
NOV 16,1977
MODIFIED
see
TACSP
-------
Table 7-3-b. 1982 PRIMARY METALS UNCERTAINTIES
TflCR AND E *1 S3
MCOIFIEO
SCC
INDUSTRIAL PROCESS, FRIM4PV METALS c>AGF 1
ION UNCERTAINTIES PROJECTED TO 1982 RUN DATE= NOV 16,1977
T AC3F
(SCC UNITS)
NO*
EMISSIONS (PILLIONS OF TONS / YEAR)
HC
CO
303000010
«• *295200.
NEG
NFG
NEG
*~2 9520 0.
NEG
NEG
NEG
303001000
~ 9010200.
NEG
NEG
NEG
^307309.
NEG
NEG
NEG
303001010
*¦ 228710.
NEG
NEG
NEG
223710.
NEG
NEG
NEG
303001020
«• 80 00200.
NEG
KEG
NEG
1172000.
NEG
NEG
NEG
303001030
~ 9<«175.
NEG
NEG
NEG
9^175.
NEG
NEG
NEG
3030010>*0
~ 5980.
NEG
NEG
NEG
^5980.
NEG
NEG
NEG
30 3001050
~ 1 9 5 C 8 0 .
~
0. 000
+
0. *00
+
0. 00 0
195880.
-
0. 000
-
0. noo
—
C.000
303001990
* ^108600.
NEG
NEG
NEG
Ifl08600.
NEG
NEG
NEG
303002000
~ 799700.
NEG
NEG
NEG
799700.
NEG
NEG
NEG
303002010
~ 799700.
NEG
NEG
NE G
799700.
NEG
NEG
NEG
303003000
«- 778^6000.
~-
. 001
~
. 0^8
*¦
.0 1 U
778^6000.
—
.001
—
.120
—
.03 5
303003010
«¦ 31822000 .
~
• 003
+
. "25
+
.010
31822000.
-
. 000
—
. 061
—
.025
303003020
31822000.
+
.000
4-
. n<«i
+
.010
31822000.
-
. 001
-
. 102
-
.025
303003030
«• 36098000.
NEG
+
. no4
~
.001
36098000.
NEG
m
. no9
—
.003
30 30030U0
* 36098000.
NEG
NEG
NEG
36093000.
NEG
NEG
NEG
303003050
~ 31822000.
NEG
NEG
NEG
31822000.
NEG
NEG
NEG
PA cj
-------
Table 7-3-b. 1982 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, PRIMARY PETALS PAGE ?
TACR AND EMISSION UNCEfiTAIf-TIES PRCJE^TEI TO 1982 PUN D AT E = NOV 16,1977
MCDIFIEC
TACRP
EMISSIONS
( PILLIONS
OF
TONS /
YEAR)
see
(SCC LNITS)
NO X
HC
CO
PACT
303003990
~
20396000.
NEG
+
. 007
~
.00?
+ .0 01
—
20396000•
MEG
—
. 309
—
.103
- . C01
30 300 WO 0 0
f
iee i8o.
NEG
+
. 001
+
.00 0
+ .0^2
-
16 6 480.
NEG
—
. OOW
—
.000
- . 0W2
30 30 04*01(1
*¦
166W80.
NEG
+
. 001
~
.0 0 0
~ • 0 W 2
-
leeteo.
NEG
—
. now
—
.000
- . 0<+2
303005000
NEG
NEG
NEG
*¦ . 03W
NEG
KEG
NEG
• 06-+
303005020
*
0.
~ 0.000
~ 0
. 000
~
C.00 c
+ 0.000
-
0.
- 0.000
- 0
. 00 0
—
0.000
- 0.coo
303005030
~
407920.
NEG
NEG
NEG
+ .007
-
W07920.
NEG
fEG
NEG
- .009
3030050W0
f
W07<20.
NEG
NEG
NE G
~ .000
-
WO 7920.
NEG
NEG
NEG
- .002
303005050
~
W07920.
NEG
NEG
NEG
«¦ .0 01
-
W 0 7 920 .
NEG
NEG
NEG
- .001
303005060
~
780 00000.
NEG
NEG
NEG
~ . 08W
-
78000000.
NEG
NEG
NEG
- . 08W
303005 <90
~
W 0 7 920 .
NEG
NEG
NEG
~ .0 00
-
W07920.
NEG
NEG
NEG
- . 000
303006000
~
1737000.
NEG
NEG
NEG
+ .020
—
17 0 W 50 0 •
NEG
NEG
NEG
- .013
303006010
29 11 e.
NEG
NEG
NEG
~ .0 00
—
29 il6.
NEG
NEG
NEG
- .001
303006020
15W080.
NEG
NEG
NEG
.now
-
15W080.
NEG
NEG
NEG
- . oow
303006030
«¦
15862.
NEG
NEG
NEG
+ .0 05
•
15862.
NEG
NEG
NEG
- . 005
3 0 30 060 W0
~
53W880.
NEG
NEG
NEG
~ .016
-
W 6200 0.
NEG
NEG
NFG
- .011
303006050
«•
2022W0.
NEG
NEG
NEG
~ . 0 CI
-
39000.
NEG
NEG
NEG
- . 000
-------
Table 7-3-b. 1982 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL
PROCESS, PFIMAFY METALS
PAGE
TACP E
"ISSION UNCERTAINTIES
PRCJECTE3 TC 198 2 R
UN
n AT E =
NOV 16,1977
MODIFIED
TACSF
EMISSIONS
(MILLIONS
OF
TONS
/ YEA?)
see
(SCC UNITS!
NOX
H C
CO
PAFT
303006 *90
~ 1632600.
NEG
NEG
NEG
~ .010
16 32 £0 0 .
NEG
NEG
NEG
- . 000
303007000
+ 1032700.
NEG
NEG
NEG
~ . oni
1032700.
NEG
NEG
MEG
- . 001
303007010
~
-------
Table 7-3-b. 1982 PRIMARY METALS UNCERTAINTIES {Continued)
INDUSTRIAL PROCESS, PFIM/VRY METALS PAGE -
TACR ANT EMISSION UNCERTAINTIES PR0JECTE1 TO 1982 RUN 0 ATE = NOV 16,1977
MODIFIED
TAC=? F
EMISSIONS
{MILLIONS
OF
TONS /
YE A")
see
(SCC UNITS)
NOX
HC
CO
PART
30 3009040
«• 10933000.
NEG
NEG
+
. 10 2
~ .0 01
10933000.
NEG
NEG
—
.20 4
- . 0 0?
303009050
~ 788160.
NEG
NEG
+
.010
~ . noo
768160.
KEG
NEG
-
• 0 4 L
- .0 00
303009 <90
«• 12993000.
~
. 004
~
. no3
~
.00 o
f . 0 00
12993000.
•
. 010
-
. 00 8
—
• 0 2 4
- . 001
303010000
+ 1769700.
¥
. 000
~
. 000
NEG
~ . 0 03
1769700.
—
.000
—
. 000
NE C-
- . 003
303010010
«• 211900.
NEG
MEG
NEG
~ .000
211900.
NEG
NEG
NEG
- .00 1
30 3010020
~ 211900.
NEG
NEG
NEG
+ . 0 03
211900.
NEG
NEG
NE G
- . 0 G3
303010990
~ 1 7 44 10 0 .
~
. 0 00
~
. 000
NEG
~ . 0 00
1744100.
•
.000
—
. 000
NEG
- . 0 0!)
302011000
NEG
NEG
ns:g
+ . G03
NEG
NEG
NEG
- . 0 03
303011010
«• 26000000.
NEG
NEG
NEG
~ .003
26000000.
NEG
NEG
NE G
- .003
303011020
13000000.
NEG
NEG
NEG
«• .0 01
13000000.
NEG
NEG
NEG
- .001
30 3011 *90
«• 39000000.
NEG
NEG
NEG
+ .002
39000000.
NEG
NEG
NE G
- .002
303012000
~ 20880.
NEG
NEG
~
.003
NEG
20880.
NEG
NEG
—
.00 0
NEG
303012010
~ 2 08 8 0 .
NEG
NEG
+
.00 3
NEG
20880.
NEG
NEG
—
.00 0
NEG
303030000
~ 372780.
NEG
NEG
NE G
~ .a oi
372780.
NEG
NEG
NEG
- .001
303030010
~ ie=74o.
NEG
NEG
NFG
~ . 0 00
189740.
NEG
NEG
NE G
- . 0 00
-------
Table 7-3-b. 1982 PRIMARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL. PROCESS, PF
IMARY METALS
OA
GE 5
TftCR A^
EMISSION UNCE FTAIMIES PROJECTED 10
198? ^UN
DATE =
NOV 16,1
977
MODIFIED
TACRF £?irS?I
CNS
(MILLIONS
OF
TONS
/
see
tSCC UNITS) NOX
HC
CO
P
APT
3030300^0
*
320980. NEG
N'EG
N£ G
f
. 0 01
320880. NEG
NEG
NEG
-
. C01
30 5999000
~
85^000. ~ .000
+
. aoo
+
. aa o
~
. OlH
85<^ooo. - .002
-
. CC1
—
.00 ?
-
.01<*
303999 *90
~
85<*i»a00. ~ .030
*
. 000
~
.00 0
~
.014
-
85^000. - .002
-
. 001
-
.00 c
-
. 01<*
-o
i
t-j
-------
Although nearly 90 percent of the CO formed does get collected
and burned, approximately 150 lb 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 atmo-
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 percent 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.Z 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 lb/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 lb/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 lb 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 produce 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 low tem-
peratures 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 nm; 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
-------
7.4.1 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 17 50 lb 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 lb/ton of steel produced. Although this can be reduced to near
zero (3 or 5 lb/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 lb/ton of steel). The effective emission factor, however, is expected
to decrease linearly to near zero by 1985.
7-25
-------
The 1977 CO emissions from the BOF are 3. 6 million tons.
In 1982, these will be reduced to 1.3 million tons. The associated large un-
certainties are 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 operation
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 uncertainty
exists for the uncontrolled emission factor. Fifteen percent uncertainty
was used in these analyses.
7. 5 REFERENCES
7-1. "Computer Analysis of NEDS Point Source Emission Data,"
Contractor Magnetic Tape No. 74362, The Aerospace Corpor-
ation, 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
-------
Particulate Pollutant System Study, VI, Mass Emissions,
PB-203 522, Midwest Research Institute, U. S. Environ-
mental Protection Agency, Durham, North Carolina
(May 1971).
Compilation of Air Pollutant Emission Factors, AP-42, 2nd
ed. (and supplements), U. S. Environmental Protection
Agency, Research Triangle Park, North Carolina (April
1973).
Survey of Current Business, U. S. Department of Commerce,
Washington, D. C. (February 1976).
7-27
-------
SECTION VIII
SECONDARY METALS
8. 1 INTRQDUC TION
The metallurgical industries are classified as part of the in-
dustrial processes category of the National Emissions Data System (NEDS).
The primary metals industry (described in Section VII) uses ore for its pro-
duction, while the secondary metals industry uses scrap metal.
This section describes the rationale and results of the analysis
performed to determine the atmospheric emissions from the secondary metals
industry. The NEDS Source Classification Code (SCC) number which repre-
sents the secondary metals industry is 3-04-xxx-xx.
Table 8-1 describes the secondary metallurgical processes
studied and gives the corresponding Modified SCC (MSCC) numbers and the
units of the annual charge (or usage) rate. The list of industries studied was
formed from those secondary metal processes which had one or more of the
four pollutants of interest with an emission rate of 500 or more tons per year.
The four pollutants of interest in the study are oxides of nitrogen (NO ), un-
burned hydrocarbons (HC), carbon monoxide (CO), and particulate matter
(PART). Except for a few isolated cases, the only significant quantities of
emission from the secondary metals industry are CO and PART.
A detailed list of emissions and charge rate data for the two
years of interest is shown in Tables 8-2-a and 8-3-a and the associated un-
certainties in Tables 8-2-b and 8-3-b.
(Continued on page 8-18)
8-1
-------
Table 8-1. DEFINITION OF SECONDARY METAL PROCESSES
MSCC
Source Category-
Charge Rate Unit
304001000
Aluminum Operation
Tons produced
304001010
Sweating furnace
Tons produced
304001020
Smelter -crucible
Tons produced
304001030
Smelter -reverberation
furnace
Tons produced
304001040
Chlorination station
Tons produced
304001100
Foil rolling
Tons produced
304001200
Can manufacture
Tons produced
304001500
Aluminum operation -
roll, draw, extrude
Tons produced
304001990
Miscellaneous activity
Tons produced
304002000
Brass/Bronze Melt
304002020
Crucible furnace
Tons charge
304002030
Cupola furnace
Tons charge
304002040
Electric induction furnace
Tons charge
304002050
Reverberatory furnace
Tons charge
304002060
Rotary furnace
Tons charge
304002990
Miscellaneous activity
Tons produced
-------
Table 8-1. DEFINITION OF SECONDARY METAL PROCESSES (Continued)
MSCC
Source Category-
Charge Rate Unit
304003000
Gray Iron
304003010
Cupola
Tons of charge
304003030
Electric induction furnace
Tons of charge
304003050
Annealing operation
Tons of charge
304003300
Miscellaneous casting fabrication
Tons processed
304003400
Grinding and cleaning
Tons processed
304003500
Sand handling - general
Tons handled
304003990
Miscellaneous activity
Tons of charge
304004000
Lead Smelting
304004020
Reverberatory furnace
Tons metal charged
304004030
Blast (cupola) furnace
Tons metal charged
304004990
Miscellaneous activity
Tons processed
304006000 Magnesium
304006990 Miscellaneous activity
Tons processed
-------
Table 8-1. DEFINITION OF SECONDARY METAL PROCESSES (Continued)
MSCC
Source Category-
Charge Rate Unit
304007000
304007010
304007020
304007030
304007040
304007990
Steel Foundry
Electric arc furnace
Open hearth furnace
Open hearth oxygen lance
Heat treat furnace
Miscellaneous activity
Tons processed
Tons processed
Tons processed
Tons processed
Tons processed
304008000
304008050
304008060
Zinc
Galvanizing kettles
Calcining kiln
Tons produced
Tons produced
304009000
304009990
Malleable Iron
Miscellaneous activity
Tons charge
304010000
304010990
Nickel
Miscellaneous activity
Tons processed
-------
Table 8-1. DEFINITION OF SECONDARY METAL PROCESSES (Continued)
MSCC Source Category Charge Rate Unit
304020000 Furnace Electrodes Tons processed
304020040 Bake furnaces Tons processed
304050000 Miscellaneous casting and fabrication
304050010 Not classified elsewhere Tons produced
304999000
304999990
Miscellaneous secondary metal
Not classified elsewhere
Tons produced
-------
Table 8-2-a. 1977 SECONDARY METALS EMISSIONS AND CHARGE RATES
ANNUAL CHA 3G?
MCOIFIEC
SCC
INDUS TkI AL D R CO E S S i S EC ON CA 9 Y *ETALS PAGE 1
'A TES AND EMISSIONS PROJECTED TO 1977 -UN DAT £ = NOV 16,1977
T AC3P
(SCC UNITS)
304001000
3812*00.
. 001
. 003
NEG
304001310
70231.
NEG
NEG
NEG
3 040 010 2 0
136260.
NEG
NEG
NEG
30*001030
11*5000.
. 009
NPG
ME C
304001040
333930.
NEG
NEG
NEG
3014001100
125280.
NEG
. 001
NEG
30400120 0
38414.
NEG
. 001
NEG
30*001500
122500.
NEG
. 101
NE C-
304001990
1835 70 0.
.001
. 001
NEG
304002000
451900.
.000
. noo
NEG
30400 2020
40000 .
NEG
NEG
NEG
30*002030
3*900.
NEG
NEG
NEG
30400 2040
1*2000.
NEG
NEG
NE G
304002050
79400.
NEG
NEG
NEG
304002060
6600.
NEG
NEG
NE G
304002«90
149000.
. 000
. 000
NEG
304003000
62197000.
.000
. 002
.792
304003010
12114000.
.000
NEG
.787
304003030
15 2 6*00.
NEG
. ono
0.00 0
304003050
1119000.
NEG
NEG
.001
304003300
6350200.
NEG
NEG
NEG
304003400
9334000.
NEG
. 000
.00 1
304003500
22232000,
NEG
NEG
.30 2
3 040 0 3 590
7522000.
NEG
. 002
NEG
304004000
66 * 790 •
NEG
. 000
NE C
304004020
445000.
NEG
NEG
NEG
304004030
146000.
NEG
NEG
NEG
30 4004^90
65790.
NEG
. 000
NFG
304006000
19380.
NEG
KEG
.000
EMISSIONS (MILLIONS CF TONS t YE A°)
NOX HC CO PAPT
. 0 06
. 1 rD
. 0 CO
. n n i
. 002
N~G
NEG
NEG
. rci
. GDI
.000
.000
.000
. 0 CI
. 0 00
.00 0
.034
. C26
. 0 CO
MEG
.002
. 0 02
.001
. 0 0*
. 000
. 0 00
.000
N EG
NE 3
-------
Table 8-2-a. 1977 SECONDARY METALS EMISSIONS AND CHARGE RATES (Continued)
UDUSTftlAL
PROCESS.
SFCONCARY HTTALS
PAG" 2
ANNUAL CHA;4 7 5 000 0.
. 01*
. 000
0. 0 03
.018
.012
NEG
bEG
NEG
NEG
.004
.0 14
NEG
NEG
NFG
NEG
.025
.012
. 0^9
. oni
.016
304008000
57 0 <-0 0.
NEG
. rD4
NEG
.002
3 040 0 80 50
3 04008060
479009.
?2<.00.
NEG
NEG
. 004
NEG
NEG
NEG
.000
. 002
304009000
1090000.
NEG
KEG
. 00 8
.0 00
304009990
1090000.
NEG
NEG
.00 8
. OPO
304010000
14700.
NEG
NEG
.001
NEG
3 04010990
14700.
NEG
NEG
.001
NFG
301*020000
275850.
NEG
NEG
NEG
. o no
304020040
275C50.
NEG
NEG
NEG
.000
304050000
1448400.
NEG
. 001
NEG
. 001
30405 0 010
1448400.
NEG
.001
NFG
. G01
304999000
11080000.
. 002
.002
NEG
. 010
304999990
noeoooo.
.002
. 002
NEG
.0 10
-------
Table 8-2-b. 1977 SECONDARY METALS UNCERTAINTIES
INDUSTRIAL PROCESS, S EC ON OA c Y METALS
PA GE
oo
00
TACR ANO
EMISSION UNCEFT A INTIES
F9CJFCTEH TO 19 77
9UN GATE =
NOV 16,1977
MOOIFIEC
TACSF
EMISSIONS
(MILLIONS OF TONS
/ YEAR)
see
(SCC UNITS)
NO*
H€
CO
PAf? T
30i»001000
~ 116*90.
+
. ono +
. 000
NFG
~ .001
116990.
—
.000
. 00 1
NEG
- . 0 PI
304001010
~ 3583.
NEG
KEG
NEG
«- .0 00
3583.
NEG
NEG
NEG
- .000
30U001020
«• 6t88.
NEG
NEG
NEG
+ .003
£ f 8 8.
NEG
NEG
NEG
- .coo
304001010
~ 61032.
~
. 0 00
NEG
NEG
+ .000
61032.
-
. 000
NEG
NEG
- . 001
3040010*»0
* 16621.
NEG
NFG
NEC
~ .0 00
16621.
NEG
NEG
NEG
- . COT
304001100
~ 6f80.
NEG ~
. OOO
NFG
NEG
6 £8 0 •
NEG
. 000
NEG
NEG
304001200
~ 1=53.
NEG ~
. 000
NEG
NEG
1953.
NEG
. 000
NEG
NEG
304001*00
«¦ 6103.
NEG ~
.000
NEG
NEG
6103.
MEG
. ooo
NE C-
NFG
304001<90
~ 97652.
+
. 000 +
. 000
NEG
~ .011
S7652.
—
.000
. 000
NEG
- .001
304002000
~ 24625.
.000 ~
. €00
NEG
~ . 001
24 62 5.
•
.000
. 00 0
NEG
- . 0 01
304002020
~ 4304.
NEG
NEG
NEG
~ . 0 00
4 304.
NEG
NEG
NEG
- .000
304002030
~ 3773.
NEG
NEG
NEG
~ .000
3 773.
NEG
NEG
NEG
.0 00
304002040
+ 15264.
NEG
»>EG
NEG
~ .003
15264.
NEG
NEG
NEG
- .001
3040Q2050
+ 8575.
NEG
NEG
NEG
.000
8575.
NEG
NEG
NFG
- .0 01
304002060
+ 722.
NEG
KEG
NEG
~ .0 00
722.
NEG
NEG
NEG
- .0 00
30400 2?90
~ 16326.
~
. 000 ~
. 00 0
NEG
~ .000
16326.
-
. 000
. 000
NF G
- . 000
304003000
«• 3073600.
~
. 000 +
. 00 0
~ .131
~ .019
3073600.
-
. 000
.001
- .131
- .021
-------
Table 8-2-b. 1977 SECONDARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, SECONDARY METALS PAGE 2
TftCP ANC MISSION UNCE FTfll M1ES F3CJFCTE3 TO 1977 SUN DATE = NOV 16,1977
MODIFIED
T AC 3P
E-IIS
51 ON S
(MILLIONS
OF
TONS / YEAP)
see
(SCC tMTSI
NOX
HC
CO
PAPT
304003010
~ 1261900.
f
.000
NEG
~
.131 ~
.019
12 6190 0.
—
. 000
NEG
—
.131
.0 21
304003030
«• 159430.
NEG
+
. 000
~
0.000 ~
. n oo
159430.
NEG
-
. ^00
—
9 .0 n n
. 0 OT
3 01+0 9 3050
~ 116430.
MEG
NEG
~
.002
NcG
116430.
NEG
NEG
—
.0 00
NEG
30400 3300
~ 865<70.
NEG
NEG
NFG 4
. C 01
304003400
865970.
NEG
NEG
NEG
. 0 02
~ 963540.
NEG
~
. 00 0
~
.001 ~
.001
304003500
963540.
NEG
—
. POO
-
.001
. Q f}2
~ 2351900.
NEG
KEG
~
. 00 t +
. 001
30400 3<90
2351900.
NEG
KFG
-
.001
.001
~ 779270.
NEG
~
. 000
NEG ~
.002
778270.
NEG
-
.001
NEG
.003
304004000
~ 27123.
NEG
~
. 000
NEG +
. OOO
27123.
NEG
-
.000
NFG
.000
304004020
~ 25455.
NEG
NEG
NEG «¦
. 0 CO
304004030
25455.
NEG
NEG
NEG
.000
~ 8485.
NEG
NEG
NE G +
. 0 GO
304004 <90
8485.
NEG
NFG
NEG
.000
~ 3=62.
NEG
¦f .
. ooo
NEG
NFG
3962.
NEG
-
. 00 0
NEG
NFG
3040060Q 0
~ 1979.
NEG
NEG
+
.000
NEG
1979.
NEG
KEG
—
.oo n
NTG
304006590
~ 1^79.
NEG
KEG
+
.80 0
NEG
1979.
NEG
NEG
—
.000
NEG
301*007000
~ 6209800.
~
. 003
~
.001
~
.0 11 «-
. 046
6209800.
—
. 009
—
. 002
-
.00
. 051
304007010
+ 3000000.
~
. 000
NEG
~
.011 ~
. 016
3000000.
—
.002
KEG
—
.00 4
. 025
304007020
~ 1269200.
¦f
. 009
NEG
NEG ~
.008
1268200.
—
.000
NEG
NFG
.012
-------
Table 8-2-b. 1977 SECONDARY METALS UNCERTAINTIES (Continued)
UDUSTRIAL
PR CCESS j
S ECCNDA
metals
PAGF 1
TAC* A NO E
MISSION UNCERTAINTIES
P»CJCCTE1
TC 1-37 7
CUN
D ATE =
NOV la,
197 7
MODIFIED
T ACQ F
E"IT
S !TONS
tMILLIONS OF
TONS
/ YEAPI
see
(SCC UMTS)
^OX
HC
CO
PAcy
30U0070 30
2 0 1*10 0.
+
o- o a n
NFG
NCG
+
. 03 9
2014100.
-
0. 000
NEG
NEG
—
. Ct»0
3Qt»on70^n
~ 1181900.
. 002
MEG
NEG
.001
1181900.
-
. 0-35
^ G
NFG
. 0 01
30<*007<90
+ 47i*3400.
+
. onz
. 001
NEG
~
. 016
4743400.
-
. 037
-
. 002
NEG
.016
30<*Q0800n
*¦ E3268.
MEG
~
. 001
NEG
f
.0(31
63268.
NEG
-
. 001
NEG
.002
30^008050
~ 60063.
NEG
>
. 001
NEG
+
.003
60063.
NEG
-
. 001
NEG
. 000
301+008060
~ l«e82.
NEG
NEG
NEG
~
.031
19882.
NEG
NEG
NEG
. 0 02
304009000
*¦ 171 €0 0 •
NEG
NEG
+
.005
+
.000
171600.
NEG
KEG
—
.00 5
. 000
30l»009<90
~ 171600.
NEG
NEG
+
.005
¥
.000
171 €0 0.
NEG
NEG
—
.00 5
-
.0 00
301+010009
* 410 4.
NEG
NEG
*
.001
NEG
410 4.
NEG
NEG
—
.001
NEG
304010990
+ 4104.
NEG
NEG
~
.001
NEG
4104.
NEG
NEG
—
.0 0 1
MEG
30<»020000
~ 59095.
NEG
NEG
NE G
+
~ 0 CO
59095.
NEG
NEG
NEG
-
. 000
304020040
* 59095.
NEG
NEG
NEG
~
. 0 00
59095.
NEG
NEG
NE G
-
. 000
304050000
~ 345400.
NEG
~
. 000
NEG
4-
.001
31(5*00.
NEG
-
. 001
NEG
-
. 0 01
304050010
~ 345400.
NEG
~
. 000
NEG
~
.001
34540 0.
NEG
-
. 001
NEG
-
.001
-------
Table 8-2-b. 1977 SECONDARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL FRCT.ESS, SECONDARY METALS PAGE U
TftCR AND EMISSION UNCERTftlMIES pR CJ EC TEH TO 1977 PUN D AT E = NOV 16,1977
MCDIFIEC
SCC
3 3<*99900 0
30<» <399=90
T AC^P
EMISSIONS MILLIONS OF TONS / YE A3)
(SCC IMTSJ
NOX
H r
CO
«-
2250000.
+ .001
f
. 00 0
MEG
+¦
-
225 0000.
- . 001
•
. oni
NE C
•
*
2250000.
~ . on
. 00 0
NEG
+
-
2250000.
- . 901
-
. 001
NEG
-
p Ap r
. 005
. 003
. 0 05
.0 03
-------
Table 8-3-a. 1982 SECONDARY METALS EMISSIONS AND CHARGE RATES
INDUSTRIAL PRCCESS, S FCCU0Ac V METALS PAGE 1
ANNUAL CHA^G^
3ATES A K [ £ HIS:
ilONS PROJECT EC TO
1982
kUN DATE =
NOV 16,1977
MODIFIEO
T AC'F
EMISSIONS
(fILLlO
NS OF TONS
/ YEAR*
sen
CSCC IMTS)
NOX
HC
CO
PA'T
30^001000
*+2?2Z00.
. no2
. 003
NEG
« 0 05
204001010
77131.
NEG
NEG
NEG
. COO
30400102t!
1 51 58 0.
NEG
NEG
NEG
.0 00
3 04001030
127(300 0.
.001)
NEG
NEG
. 000
304001040
370e30.
NEG
NEG
NEG
. 001
304001100
143580.
NEG
. 001
NEG
NEG
304001200
42394.
NEG
. 001
NEG
NEG
3 0 4001500
135000.
NEG
. 001
NEG
NEG
304001990
20 347 0 0.
.001
. 001
NEG
.004
3 04002000
451900.
. 000
. 000
NEG
. 000
304002020
40000.
NEG
NEG
NEG
. ooa
3 0400 20 30
3<»coo.
NEG
NEG
NEG
. COO
304002040
142000.
NEG
NEG
NEG
.000
304002050
7 9 40 0.
NEG
KEG
NEG
.000
304002060
eeoo.
NEG
KEG
NFG
. 003
304002990
149000.
.0 00
. 000
NFG
.000
304003000
67542000.
.000
. 002
.365
.017
304003010
13164000.
.009
NEG
. 362
. 013
304003030
16 5640 0.
NEG
. 000
0.000
. 0 00
30400 3050
1218000.
NEG
NFG
. 00 0
NEG
304003300
9065200.
NEG
NEG
NEG
. oni
304003 *00
10134000.
NEG
. 000
.00 0
. 0 Cl
304003500
24122000.
NEG
NEG
.003
. oon
304003 *90
8172000.
NEG
. 002
NEG
. 0 01
304004000
7 09 *40 .
NEG
. 000
NE G
. 0 Cl
304004020
479000.
NEG
NEG
NEG
. 0 00
304004030
156000.
NEG
NEG
NEG
. 0 09
304004990
74440.
NEG
. 000
NEG
NEG
304006000
21830.
NEG
KEG
.00 0
NCG
-------
Table 8-3-a.
1982 SECONDARY METALS EMISSIONS AND CHARGE
RATES
(Continued)
I MDUSTt.
IAL PRCCESS, S EC ON DA
-V METALS
PAGE 2
ANNUAL SHA^S
T RATES AS C EM IS
SIGN J ".CJECT^C TO 19-2 -"UN
DATE =
NOV 16,1977
MCDIFI5TH
see
T AC^F
(SCC UMTS)
EMI S SIGNS
MOX
( V 3 9
3o<*no7oio
30400 70 20
3 0 40 0 7 0 30
30U007CUO
30^007990
415 60000.
210 20000.
294a 0000 .
17 2 E 000 0 .
69000000.
.0 04
. 003
0.000
.0 08
.012
NEG
MEG
KEG
NEG
. 004
.010
NF G
NE G
NEG
NEG
.00 1
. 0 03
. 026
. 0 GO
. 005
304009000
573*00.
NEG
. 004
NEG
.030
304008050
304008060
478000.
92«»110.
NEG
NEG
. 004
NEG
NEG
NE G
.coo
. 000
304009000
1090000.
NEG
r.'EG
.on?
. 000
304009*90
10900 00.
NEG
NEG
.00 3
. 000
304010000
16*50.
NEG
NEG
.00 0
NEG
304010 *90
18S50.
NEG
NEG
.00 0
NEG
304020000
312350.
NEG
NEG
NEG
.003
304020040
312350.
NEG
NEG
NEG
. 0 00
30^05 0000
1628<<00.
NEG
. 001
NEG
.000
304050010
1626^00.
NEG
. 001
NEG
.000
304999000
12580000.
. 002
.002
NEG
.011
304999<90
12560000.
.002
. 002
NEG
.0 11
-------
Table 8-3-b. 1982 SECONDARY METALS UNCERTAINTIES
INDUSTRIAL
P^CCFSSt S EC ON OA
~Y METALS
PAGE 1
TAC* AND E
"ISSIOh UNCEFTAIMIES
P'CJE^TET TC 1982 -
UN 0ATE =
NOV 16,
1977
M CD I FIE D
TAC5F
EMISSIONS
< ILL 10 NS
CF TONS
/ YEAR!
see
CSCC UNITS)
NOX
»C
CO
P APT
30U001000
~ 321100.
~
.000 ~
. CO 0
NEC-
~
. 003
321100.
—
.oat
. 001
NEG
-
. 0 01
3040010m
~ 944 8.
NEG
NEG
NEG
+
. a oq
9448.
NEG
KEG
NE C
-
.0 CO
304001020
~ 19561,
NEG
KEG
NEG
~
.003
19961*
NEG
MEG
NEG
-
. n qo
304001030
«• 167630.
~
. ooa
NEG
NEG
~
.0 00
167630.
-
.000
NEG
NE G
-
. n co
304001040
~ *3286.
NEG
NEG
NEG
~
.001
<~3266.
NEG
KEG
NEG
-
.001
304001100
* 19958.
NEG *
. 000
NEG
NEG
1 2 95 8»
NEG
. 001
NEC
NEG
304001200
~ 536h •
NEG ~
. 000
NEG
NEG
5364.
NEG
. C01
NE G
NEG
304001500
~ 16763.
NEG *
. 000
NEG
NEG
16763.
MEG
. 031
NEG
NEG
304001990
~ 268210.
+
. 000 ~
. 00 0
NEG
+
. 003
268210.
—
.001
. 000
NEG
. 0 01
304002000
~ 79617.
«-
. 000 ~
.000
NEG
+
.000
79617.
—
. 008
. noo
NE C
.0 CO
304002020
~ 13708.
NEG
NEG
NEG
.000
13J08.
NEG
NFG
NEG
.0 00
301*002030
~ 12419.
NEG
NFG
NEG
¥
.000
12419.
NEG
KEG
NEG
. 000
304002040
~ 49729.
NEG
NEG
NEG
f
. 0 OQ
49729.
NEG
NEG
NEG
. 000
304002050
*¦ 27969.
NEG
NEG
NEG
+
. 000
27969.
NEG
NEG
NEG
. 000
304002060
+ 2304.
NEG
NEG
NEG
~
. 0 00
2304.
NEG
NEG
NE G
. 000
304002990
~ 52308.
~
. 0 00 ~
, 000
NEG
+¦
. 0 00
52308.
—
.009
. 000
NEG
. 0 00
30400 3000
~ 11808000.
~
,000 *
. 901
~ .340
+•
. Oil
1180 3000•
-
. 000
. 00 2
- . 340
-
.013
-------
Table 8-3-b. 1982 SECONDARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL
ACCESS,
S EC ON OA
~Y METALS
PAGE 2
TACR A NO E*I
SSION UNCEfrTAISTIES
P
3 C J E C T E O
TO 198?
RUN
O AT E =
NOV 16,
197?
MOOIFIEO
TAC^ F
eh:
S SIGNS
(hIllIONS CF
TONS
/ YEAC)
see
(SCC UMTS)
NOX
HC
CO
PftPT
30400 3010
~ *650200.
+
. 000
KEG
+
.340
f
. 0 10
^ssoeoo.
-
. 003
NEG
-
.3 4 0
.0 13
30400 30 30
~ 6 0 3290.
NEG
. 00 Q
~
0.00 0
. 0 CO
6 C 0 290.
NEG
-
. noo
-
o.ooc
. COO
304003050
* +360 *
NEG
NEG
+
. 003
NEG
- 446 26 0 .
NEG
NEG
-
.0 0 0
NEG
30400 3300
~ 3300(00.
NEG
NEG
MEG
+
. C01
3300600.
NEG
NEG
NEG
. 0 01
30400 3400
~ 3687800.
NEG
~
. 000
+
.003
~
. 001
3 6 6 7 800.
NEG
—
. 000
—
.00 0
.0 01
304003 !00
~ 9053800.
NEG
NEG
¦f
.001
~
.000
9053800.
NEG
KEG
-
.on ?
.000
3 0400 3 ?go
~ 2976300.
NEG
+
. (01
NEG
f
. 001
2976300.
NEG
—
. 001
NFG
. 0 01
304004000
~ 5 k 591.
NEG
«•
. 000
NEG
~
. 000
54591.
NEG
—
. 00 0
NEG
. 000
304004020
~ 51264.
NEG
NEG
NEG
+
. coo
51264.
NEG
NEG
NEG
. oon
304004030
~ 17088.
NEG
NEG
NEG
~
. 0 00
17088.
NEG
NEG
NEG
-
.000
304004<90
~ 7762.
NEG
~
.OOtJ
NEG
NEG
7762.
NEG
—
. 00 0
NEG
NEG
304006000
~ 5096.
NEG
NEG
«¦
.00 1
NEG
5096.
NEG
NEG
-
. AO o
NEG
304006990
~ 5096.
NEG
NEG
+
.001
NEG
5096.
NEG
NEG
•
.000
NEG
304007000
~ 10779000.
+
. 0Q4
~
. 001
.020
~
. 0? S
10779000.
-
.014
—
. ro4
—
.00 1
-
.0 27
304007010
~ 536 6 €0 0.
~
. 001
NEG
•f
.020
~
.0 00
304007020
5366600.
-
• 004
NEG
m
.00 1
-
. oo^;
~ 2307900.
+
.000
NEG
NEG
~
. 0 02
2307500.
-
.009
NEG
NEG
-
. 0 03
-------
Table 8-3-b. 1982 SECONDARY METALS UNCERTAINTIES (Continued)
INDUSTRIAL PRCCrSS, SECO^OA'Y METALS PAGE 3
TACR ANO FllSSIOh UNCE&T AIhTIES P'CJECTED TO 19R* SUN DATE = NOV lb,1977
MODI FIE IT
T AC^F
EM I S
SI ON S
t ^ILLlQKS
OF
TONS
t YEAR)
sec
(SCC UNITS)
MO V
HC
CO
PAPT
304007030
* 334W0Q.
+
0. 000
NEG
ME G
4-
.022
3344300.
-
0. 003
NFG
NEG
. 026
304007040
* 1955100.
+
. 00?
NEG
NE C-
+
.000
1955100.
-
. 007
KEG
NEG
. 0 03
30 4007930
* 8188400.
~
. 003
. 001
NE G
.0 06
818 8 t00 •
-
.011
. 004
NEG
. 0 05
304008000
~ 1 3 3 49 0 .
NEG
+
. 001
NFG
*
.000
133490.
NEG
-
. 00 3
NEG
.000
30*4008050
~ 125210.
NEG
~
. 001
NEG
«¦
. 0 00
129210.
NEG
-
.003
NEG
.0 00
3(juoo8oen
~ 33529.
NEG
NEG
NEG
+
. 0 oo
3 3 ?29.
NEG
NEG
NEG
. 0 50
301*009000
~ 2S7210.
NEG
NEG
+
.010
+¦
. 0 00
267310.
NEG
NEG
—
.00 2
. 0 00
304009 *90
* 267310.
NEG
NEG
+•
.010
+
. 0 00
Z 87310 .
NEG
NEG
-
.00 2
-
.003
304010000
~ 7 588.
NEG
MEG
~
.00 2
NEG
7*88.
NEG
NEG
—
.00 3
NEG
304010 <90
~ 7S88.
NEG
NEG
+
.002
NEG
7?88.
NEG
NEG
—
.00 0
NEG
304020000
~ 83200.
NEG
NEG
NEG
¥
. 0 00
83200.
NEG
NEG
NEG
—
. 0 00
304020040
* 83200.
NEG
MEG
NEG
4-
.0 00
83200.
NEG
NEG
NEG
—
.000
304050000
~ ^cio50.
NEG
~
.000
NEG
+
.000
<*91050.
NEG
. 001
NE G
•
. 000
304050010
~ ^91050.
NEG
«¦
. 000
NEG
4-
.000
491050.
NEG
-
. 001
NEG
-
.000
-------
Table 8-3-b. 1982 SECONDARY METALS UNCERTAINTIES (Continued)
INDUS TRIAL
PROCESS, SECONDARY METALS
PA
GE <~
TACR AND
EMISSIO K
UNCEFTAI MIES
PROJECTED TO 1982
RUN 9 ATE =
NOV 16,
1977
MOOIFIEO
TACSP
EH IS ?I ONS
fMILLIONS OP" TONS
/ YEAR)
see
(SCC UNITS!
NOX
HC
CO
PART
30 <»99 900 0
~
3370C00.
*¦ .001 ~
. 001
NEG
~
. 0 07
—
33 7 080Q•
- .002
. CO 2
NFG
«»
.0 0<*
30<»999990
~
3370600.
~ .001 ~
. 001
NEG
~
.007
-
3370500.
- .002
.002
MEG
-
.0 Q<+
-------
8. 2 SUMMARY
Data in Tables 8-2-a and 8-3-a show that the vast majority of
CO emissions (96 percent) from those processes grouped in the secondary
metals category are emitted from the cupola furnace process used in gray
iron production. Not only is the great majority of gray iron produced in the
cupola furnace, but it is the only type of gray iron furnace which emits sig-
nificant concentrations of CO. Other furnace types yield so little that CO
emission factors have not even been defined. CO emissions from cupola
furnaces can be controlled by afterburning. Reduction in CO emissions from
cupola furnaces by about a factor of two are projected over the next five
years.
More than half of the PART emissions from the secondary
metals category result from a variety of furnaces and processes involved in
a steel foundry, principally the open hearth oxygen lance process. Broader
applications of particulate control equipment are expected to reduce PART
emissions from steel foundaries by nearly a factor of three over the next
five years.
8. 3 PROCESSES EVALUATED
A total of 72 categories of secondary metal processes is listed
in the NEDS data bank. Thirty-seven of these categories contributed 500 or
more tons per year of at least one of the four emissions of interest. Although
the year of effectivity was between 1971 and 1973, these 37 industries were
considered potential contributors of significant quantities of pollution in 1977
and later. Thus the list of processes to be studied was formed. Metal for
secondary melting comes from scrap, pigs, machine shaving or foundry
returns, whereas primary metals come from ore. A brief description of
processes which were responsible for the most significant quantities of
emissions of CO and PART follows.
8. 3. 1 Gray Iron Foundries
The cupola, electric, and reverberatory furnaces are the
types most widely used in gray iron production. Although there are other
8-18
-------
sources of pollution in the iron foundry, the furnaces are responsible for
the preponderance of the CO and PART emissions. The cupola furnace is
used to melt most of the secondary iron being produced today because of its
adaptability to high production rates and moderate operating costs.
According to Ref. 8-1, as cupolas are being retired and where
production rates permit, it has been more advantageous to substitute reverber-
atory furnaces rather than install the control equipment necessary for cupolas.
The typical uncontrolled PART emission factors are, respectively, 17, 2, 5,
lb
and 1. 5 for cupolas, reverberatory, electric arc, and electric induction
furnaces. The electric furnaces are used primarily where special alloys
are made and where rapid and accurate heat control is needed.
In addition to PART matter, the cupola generates about 145
lb of CO per ton of metal produced. Afterburners are frequently installed in
cupola control systems. In addition to alleviating the CO pollution problem,
afterburners eliminate the explosive environment of the cupola and reduce
the concentration of combustible PART matter in the effluent.
A typical combustion gas analysis of a cupola before the after-
burner is 12 percent CO^, 11 percent CO, 1/2 percent Oand 76 percent
N£. Depending on dwell time, mixing effectiveness, and gas temperature,
the CO concentration can be brought to near zero at the afterburner exit.
The reverberatory furnace also generates CO, but, because
the products of combustion come in contact with molten metal, the CO is
virtually all converted to before leaving the furnace. Since no com-
bustion (except for oil-laden scrap) takes place in the electric furnaces, no
CO is generated here.
8. 3. 2 Secondary Aluminum Smelters
Secondary aluminum sources include (1) pigs or ingots, (2)
foundry returns and machining chips, and (3) scrap. The first two types
are relatively clean and can be dumped directly into the melting furnaces,
which are primarily comprised of crucibles and reverberatory furnaces.
The scrap metal, however, may be contaminated with foreign materials,
8-19
-------
including dirt, oil, paint, plastics, and other metals. Some of these con-
taminants can be removed by passing the scrap through a sweating furnace.
These sweating furnaces are open-flame reverberatory type. The furnace
operates at 1250 to 1400°F, which allows all aluminum to melt, combustibles
to burn, and higher melting materials like iron, brass, and dross to remain
intact. The aluminum flows into pig molds and is later remelted in one of
the main furnaces. The primary source of air pollution from the sweating
furnace includes the emissions from incomplete combustion of the organic
materials, stray pieces of magnesium, and other materials such as the
dross and skim.
According to Ref. 8-1, the main furnaces' fluxing is accom-
plished for one or more of the following reasons: (1) minimize aluminum
oxidation, (2) form nucleus for impurity removal with dross skimming, (3)
dissolve unwanted gases, and (4) reduce magnesium content. Pure aluminum
charge needs little flux, while dirty scrap may require the charge to consist
of as much as 1/3 flux. In addition to flux, magnesium content is reduced
by use of chlorine gas. Extra precautions must be taken because of the high
toxicity of the gas.
Both fluxing and chlorination cause particulate matter to be
emitted from the furnaces. Some of the particulate matter includes mag-
nesium and aluminum chlorides, fluorides, and oxides, along with various
salts. Any control systems used to collect the particles must also deal
with the toxic gases.
8. 4 EMISSIONS ANALYSIS
This section describes the assumptions, hypotheses, and
significant observations that were made in the course of defining the data
base with which the charge rates and emission rate calculations were made.
8. 4. 1 Gray Iron Foundaries
Reference 8-2 lists the total shipments (orders filled) as
13.6 million tons of gray and ductile iron for the 12-month period ending
August 1976. This value was used as the total production rate, i.e. , the
8-20
-------
combined charge rate of cupola, reverberatory, and electric furnaces. This
total charge rate was distributed among the three furnaces in the same pro-
portions noted in NEDS. The total charge rate uncertainty was established as
0.81x 10 ton/yr, which was the standard error of estimate based on several
consecutive years of production listed in Ref. 8-4.
The variations in gray iron production from year to year was
rather high according to data listed in Ref. 8-3. Therefore it was necessary
to resort to techniques other than that of obtaining an average slope from
actual production rate data. The slope of the production curve was set equal
to 1. 75 percent, which was the average rate of increase since 1967 in the
"Index of Industrial Production, " shown in Ref. 8-3, while the uncertainty
of the slope was set equal to the standard deviation of the annual increase.
The derived value was 6. 3 percent of the total charge rate.
The activities peripheral to metal melting (furnaces), such
as sand handling, grinding, casting, and fabrication, were defined in the
same proportions (of the total iron production) as noted in NEDS data.
Emission factors were extracted from Ref. 8-5 when avail-
able, otherwise one was derived by dividing the NEDS emissions by the
charge rate. Reference 8-6 data, when available, was used to substantiate
other data, but because of its age (1971 report, 1968 measurements) it was
not used as a primary source.
8,4.2 Secondary Aluminum Smelters
Unlike the gray iron foundries, the data for production in
secondary aluminum smelters were somewhat discrepant and consequently
were assigned larger uncertainties. Fortunately, Ref. 8-2 and 8-3 data,
since 1972, agreed favorably. For 1967 and 1972, Ref. 8-7 data sub-
stantiated Ref. 8-2 data quite well; therefore the charge rate analysis was
based on Ref. 8-2 data.
The crucible and reverberation furnaces combined charge
rates are considered to represent the total secondary aluminum production
(recovery from scrap) as listed in Ref. 8-2. The ratio of the charge rates
of the various process categories to the sum of the charge rates of these
8-21
-------
two furnaces was assumed to be the same for today's production rates
(Ref. 8-2) as for the values listed in NEDS.
The charge rate slopes were determined by least square fit
of the charge rate data, and the uncertainty of charge rate was determined
as the standard error of estimate. The slope uncertainties were set to
100 percent of the slope value.
Aluminum emission factor data were extracted from Ref.
8-5 when available; otherwise, a set of derived values was calculated from
NEDS data.
8.5 REFERENCES
8-1. Air Pollution Engineering Manual, 2nd Edition, AP-40
U. S. Environmental Protection Agency, Research Triangle
Park, North Carolina (May 1973); prepared by Los Angeles
Air Pollution Control District.
8-2. Survey of Current Business (October 1976).
8-3. Metal Statistics (1976).
8-4. Air Pollution Aspects of the Iron Foundry Industry, A. T.
Kearney (February 1971).
8-5. Compilation of Air Pollutant Emission Factors, AP-42.
2nd Edition (and supplements), U. S. Environmental
Protection Agency, Research Triangle Park, North
Carolina (April 1973).
8-6. Particulate Pollutant System Study. VI, Mass Emissions.
PB-203 522, Midwest Research Institute, U. S. Environ-
mental Protection Agency, Durham, North Carolina
(May 1971).
8-7. 1972 Census of Manufacturers, Department of Commerce,
Washington, D. C.
8-22
-------
SECTION IX
MINERAL PRODUCTS
9. 1 INTRODUCTION
The category of mineral products covers the processing of
non-metallic minerals from the quarry or mine to a condition of a saleable
product, typically, for the construction industry. The general types of
processes concerned include size reduction (crushing or grinding), sorting
(primarily screen operations, with some air classification steps), convey-
ing (loaders, trucks, or conveyor belts), and storage (open, bin, or silo).
For certain mineral products, there are important additional processes
involving change in physical or chemical state. Examples of the former
are blending, sintering, and pressing into desired shapes. The most
prevalent type of chemical process consists of heating (often in a rotary
kiln) to drive off water of hydration and/or to bring about a controlled
degree of thermal decomposition (generally referred to as calcining). This
latter process may be followed by additional sintering reactions which
yield new chemical species.
The principal emission in virtually every case is particulate
(PART) matter. Oxide of nitrogen (NO ) emissions are relatively low and
are primarily attributed to the fuel combustion processes involved. Hydro-
carbon (HC) and carbon monoxide (CO) emissions are not significant. The
PART, NO , HC and CO emissions assigned to the mineral products cat-
X
egory in the November 15, 1976 National Emissions Data System (NEDS)
summary report (prior to initiating this study) represented approximately
26, 2.4, 0.2, and 0.1 percent, respectively, of the total point source
9-1
-------
emissions of these pollutants. Among the NEDS major point source cat-
egories, the mineral products category was second only to utility boilers
in terms of the percentage contribution of PART emissions to the nation-
wide total.
Based on the present work, the indicated particulate emissions
from the mineral products category are substantially larger than indicated
by the NEDS data of November 15, 1976, and mineral products now represent
the largest source category of PART emissions.
Potentially large PART emissions may occur from each of
the process operations mentioned. In those operations involving heating,
PART emissions may also occur as a result of the fuel combustion process,
but these are usually not significant in comparison to the particulates gen-
erated from the mineral product being processed. The chemical species
involved in the PART emissions from the mineral products industry are
usually not considered to be toxic but are of concern because of the
high process tonnage rates and because of the small particle sizes (into
the submicron range), which are often included in the emissions. These
smaller particles may be transported long distances in the atmosphere
and, if inhaled, may represent health hazards because of their tendency to
bypass the natural body defenses against ingestion of foreign matter into
the lungs.
9. 2 SUMMARY
The categories of mineral products which were examined
in this study are delineated in Table 9-1. The charge rates and emissions
for each of the major process categories are listed in Tables 9-2-a and
9-3-a; the corresponding uncertainties of each of these parameters are
given in Tables 9-2-b and 9-3-b.
The total rate of PART emissions for the mineral products
industries is indicated as about 7. 8 megatons per year in 1977, with a
projected decrease by 1982 to about 6.2 megatons per year. This decrease
is due to the progressively greater stringency of PART emission control
standards at both the local and federal regulatory levels.
(Continued on page 9-25)
9-2
-------
Table 9-1. DEFINITION OF MINERAL PRODUCTS PROCESSES
MSCC
Source Category
Charge Rate Unit
305002000
Asphaltic Concrete
305002010
Rotary dryer
Tons produced
305002020
Other sources
Tons produced
305003000
Brick Manufacturing
305003010
Drying
Tons produced
305003020
Grinding
Tons produced
305003030
Storage
Tons produced
305003990
Miscellaneous processes
Tons produced
305005000
Castable Refractory
305005990
Other (not classified)
Tons feed material
305006000
Cement Manufacturing, Dry Process
305006010
Kilns, total
Tons cement produced
305006020
Dryers, grinder, etc,
Tons cement produced
305006030
Kilns, oil-fired
Tons cement produced
305006040
Kilns, gas-fired
Tons cement produced
305006050
Kilns, coal-fired
Tons cement produced
305006990
Miscellaneous processes
Tons cement produced
-------
Table 9-1. DEFINITION OF MINERAL PRODUCTS PROCESSES (Continued)
MSCC
Source Category-
Charge Rate Unit
305007000
Cement Manufacturing, Wet Process
305007010
Kilns, total
Tons cement produced
305007020
Dryers, grinder, etc.
Tons cement produced
305007030
Kilns, oil-fired
Tons cement produced
305007040
Kilns, gas-fired
Tons cement produced
305007050
Kilns, coal-fired
Tons cement produced
305007990
Miscellaneous processes
Tons cement produced
305008000
Ceramic Clay Manufacturing
305008010
Drying
Tons input to process
305008020
Grinding
Tons input to process
305008030
Storage
Tons input to process
305008990
Miscellaneous processes
Tons input to process
305009000
Clay /Fly Ash Sintering
305009030
Natural clay
Tons product
-------
Table 9-1. DEFINITION OF MINERAL PRODUCTS PROCESSES (Continued)
MSCC
Source Category
Charge Rate Unit
305010000
Coal Cleaning
305010010
Thermal drying, fluidized bed
Tons coal-dried
305010020
Thermal drying, flash
Tons coal-dried
305010030
Thermal drying, multilouvered
Tons coal-dried
305010990
Miscellaneous processes
Tons coal-dried
305014000
Glass Manufacturing
305014010
Soda lime
Tons glass produced
305015000
Gypsum Manufacturing
305015010
Dryer, raw material
Tons calcined gypsum
produced
305015020
Primary grinder
Tons calcined gypsum
produced
305015030
Calciner
Tons calcined gypsum
produced
305015040
Conveying
Tons calcined gypsum
produced
305015990
Miscellaneous processes
Tons calcined gypsum
produced
-------
Table 9-1. DEFINITION OF MINERAL PRODUCTS PROCESSES (Continued)
MSCC
Source Category-
Charge Rate Unit
305016000
Lime Manufacturing
305016010
Primary crushing
Tons lime produced
305016020
Secondary crushing
Tons lime produced
305016030
Calcining, vertical kiln
Tons lime produced
305016040
Calcining, rotary kiln
Tons lime produced
305016990
Miscellaneous processes
Tons lime produced
305018000
Per lite Manufacturing
305018990
Miscellaneous Processes
Tons processed
305020000
Stone Quarrying/Processing
305020010
Primary crushing
Tons raw material to
primary crusher
305020020
Secondary crushing
Tons raw material to
primary crusher
305020030
Tertiary crushing/screening
Tons raw material to
primary crusher
305020040
Recrushing screening
Tons raw material to
primary crusher
(Continued)
-------
Table 9-1. DEFINITION OF MINERAL PRODUCTS PROCESSES (Continued)
MSCC
Source Category-
Charge Rate Unit
305020000 (Continued)Stone Quarrying /Processing
305020050
Fines mill
Tons raw material to
primary crusher
305020060
S c r e ening / c onve y ing /hand ling
Tons raw material to
primary crusher
305020070
Open storage
Tons raw material to
primary crusher
305020080
Cut stone, general
Tons processed
305020090
Blasting, general
Tons processed
305020990
Miscellaneous processes
Tons processed
305022000
Potash Production
305022990
Miscellaneous processes
Tons processed
305024000
Mercury Carbonate
305024010
Mining/processing
Tons product
-------
Table 9-1. DEFINITION OF MINERAL PRODUCTS PROCESSES (Continued)
MSCC
Source Category
Charge Rate Unit
305025000
Sand and Gravel
305025010
C r us hing /sere ening
Tons product
305025991
Miscellaneous processes
Tons processed
305025992
Open storage
Tons product
305999990
Miscellaneous Processes
Tons processed
-------
Table 9-2-a. 1977 MINERAL PRODUCTS EMISSIONS AND CHARGE RATES
INDUSTRIAL
P3CCESS, MINERAL
PRODUCTS
PAG F 1
ANNUAL CHA ~
RATES ANt EMISSIONS PROJECTED TO 1977 -UN
Q ATE =
NOV 16,1977
*0niFIEC
S'lC
TACSF
CSCC UNITS)
EMISSION^
N0X
(MILLIONS OF
HC
TONS
CO
f YEAS)
PflPT
395002000
• 0^*6
. 001
. 00 4*
.634
30500 2010
305002020
236670000.
236670000.
. 042
. 013
. 001
MEG
.00 4
NEG
. 493
. li*l
305003000
NEG
NEG
NEG
. 459
305003010
305003020
305003030
3 05003 ^90
22600000.
22600000.
22600000.
23414000.
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
.170
. 185
.083
. 0 21
305005000
NEG
NEG
NEG
. 0 03
305005«90
11 €5 £0 0.
NEG
NEG
NEG
. C 03
305006000
. 061
NEG
NE G
.6 01
305006010
305006020
305006«90
331E400 0.
33154000.
78904000.
.0 37
.000
.024
NEG
NEG
NEG
NEG
NEG
NEG
.421
. 164
. 016
305007000
. 051
NFG
NEG
.548
305007010
305007020
305007990
39828000.
40 62 300 0.
27902000.
. 051
NEG
. 000
NEG
NEG
NEG
NEG
NEG
NEG
.U71
.067
.011
305008000
.003
NEG
.001
. 13?
305008010
305008020
305008030
305008990
10659000.
10658000.
10658000.
20700000.
.002
NEG
NEG
. 001
NEG
NEG
NEG
NEG
NEG
.001
NEG
NEG
.074
.0 68
.033
. 006
305009000
NEG
NEG
NEG
.020
305009030
3372700.
NEG
NEG
NEG
. 020
-------
Table 9-2-a.
1977 MINERAL PRODUCTS EMISSIONS AND CHARGE RATES
(Continued)
INDUSTRIAL
PROCESS, MINERAL
FROOUCTS
PAGE 2
ANNUAL CHA^G
E °ATES 0NC EMISSIONS PROJECTED TO 19 77
PUN
DATE =
NOV 16,1977
MOOIFIEC
see
TAC=?F
(SCC UMTS)
EMISSIONS
NOV
(MILLIONS OF
HC
TONS
CO
/ YEAR)
P A»T
305010000
. 006
NEG
.00 1
.097
3(15010010
305010020
305010030
305010 ego
48 8 5 9000*
19178000.
12036000.
80072000•
NEG
NEG
NEG
• 0 06
NEG
NEG
tEG
NEG
NEG
NEG
NFG
.001
. 053
. 018
.013
. 0 02
305014000
. 019
NEG
NEG
. 0 13
305014010
15423000.
.019
NEG
NEG
.013
305015000
. 002
NEG
NEG
. 081
305015010
305015020
305015030
305015040
30 5015«90
10820000.
10820000.
10820000.
10820000.
2164 000 0 .
NEG
NEG
. 001
NEG
. 002
NEG
NEG
NEG
NEG
NEG
NE G
NEG
NEG
NFG
NEG
. 024
. 0 01
.054
.000
.002
305016000
. 003
. 000
.002
. 388
305016010
305016020
305016030
3050160*10
3Q5016<90
20646000.
20646000.
2064600.
18602000.
20646000.
NEG
NEG
. 000
. 002
. 001
NEG
NEG
. 00 0
NEG
KEG
NEG
NEG
.002
NEG
NEG
. 004
.011
.003
.353
. 018
305018000
NEG
NEG
NEG
.002
305018990
2616600.
NEG
NEG
NEG
.002
305020000
• 0 53
. 002
.01 4
3.793
305020010
305020020
305020030
3050200^0
305020050
924220000.
924220000.
965500000.
965500000.
965500000.
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
. 107
. 221
1. Oil
.168
1.011
-------
Table 9-2-a. 1977 MINERAL, PRODUCTS EMISSIONS AND CHARGE RATES
(Continued)
I NOUS TP I Au ^RCGPSS, MINERAL PRODUCTS
ANNUAL CHA=?G- RATES ANC EMISSIONS P?0J£CTEC TO 19 77 'UN DATE =
MCniFIEC
SCC
305020060
SO£020070
3 05020030
305020090
3 05 020?90
305022000
3 05022 990
305021*000
30502*010
305025000
305025010
305025*90
305025991
305025992
TACRF
-------
Table 9-2-b. 1977 MINERAL PRODUCTS UNCERTAINTIES
INDUSTRIAL
TACfi AND EMISSION UNCEFT AIM IES
PROCESS, MINERAL FPODUCTS «>AGE 1
F3CJECTED TC 1977 RUN 0ATt = NOV 16,1977
modified
TACRF
EMISSIONS (MILLIONS
see
(SCC UNITS!
NOV
HC
CO
305002000
. 003
~
. 000
+ .001
—
. 0 3 9
-
. 000
- .00 1
305002010
7 D 16 EDO.
«¦
.009
+
. 000
+ • 00 1
7016600.
—
. 009
—
. 000
- .00 1
305002020
*¦
7016600.
«¦
. 001
NEG
NEG
7016600.
—
. 001
NFG
MEG
305003000
NEG
NEG
NEG
NEG
NEG
NEG
305003010
*¦
680(60.
NEG
NEG
NEG
-
6 £ 0 66 0 •
NEG
NEG
NEG
305003020
~
680 £60.
NEG
NEG
NEG
305003030
-
66 0 €60•
NEG
NFG
NEG
68 0 660.
NEG
NEG
NEG
680660.
NEG
NFG
NEG
305003 <90
¥
701050.
NEG
NEG
NEG
701050.
NEG
NEG
NEG
30 5005000
NEG
NEG
NEG
NEG
NEG
NEG
30 5005^90
*
57 764 •
NEG
NEG
NEG
—
57764.
NEG
NEG
NFG
305006000
+
• 008
NEG
NFG
.008
NEG
NEG
305006010
~
nee€00.
*
. 005
NEG
NEG
-
1188600.
. 005
NEG
NEG
305006020
~
i 18 8 €00 •
*
. 000
NEG
NEG
mt
1188 €00.
• 000
NEG
NEG
30500 6990
~
14907000.
4-
.007
NEG
NEC
-
14907000.
. 007
NEG
NFG
305007000
+
• 006
NEG
NEG
—
. Oil
NEG
NEG
TONS / YEAR*
PAPT
-------
Table 9-2-b. 1977 MINERAL PRODUCTS UNCERTAINTIES (Continued)
INDUSTRIAL
FFCCESS,
WIME^AL FPODUCTS
PAGE 2
TACR AND £"4
ISSION UNCERT AINTIES
PRCJEOTE
0 TO 197 7
RUN
0 ATE =
NOV 16,1977
HCOIFIED
TACSF
EMISSIONS (MLLICNS OF
TONS
/ YEA1?)
see
(SCC UMTS!
NO X
HP
CO
PART
305007010
*
1003600.
~
. 006
KEG
NE G
* .272
¦m
10 0 360 0 .
-
.011
MEG
NEG
- . 296
3050070*0
*
1023700.
NEG
KEG
NEG
+ . 034
-
10 2 3 70 0 .
NEG
KEG
NEG
- .038
"^0 5007990
562 040 Q.
~
.000
NEG
NEG
~ .006
•
5620400.
—
.000
NEG
NEG
- .0 07
305008000
~
. 000
NEG
+
. 00 0
4- .037
—
. 000
NEG
-
.00 0
- . C40
305008010
~
731820.
~
. 000
NEG
NEG
~ .026
-
731820.
-
. 000
NEG
NEG
- . 028
305008020
*¦
731820.
NEG
KEG
~
.00 0
* . D24
—
731820.
NEG
NEG
—
.000
- .026
305008030
f
731820.
NEG
NEG
NEG
+ .011
•
731S20.
NEG
NEG
NEG
- .012
3 0 500 8*90
~
1423500.
~
.003
NEG
NEG
«¦ .002
-
1423500.
—
. 000
NEG
NEG
- .0 03
30 500 9000
NEG
NEG
NEG
~ .004
NEG
NEG
NFG
- .004
305009030
~
311220.
NEG
NEG
NEG
+ .004
—
311220.
NEG
NEG
NEG
- . 0 Oh
305010000
~
.001
NEG
+
.000
4- . 024
—
. 001
NEG
.00 0
- .033
305010010
~
2397700.
NEG
NEG
NEG
~ .022
2397700.
NEG
NEG
NEG
- .030
30 5010020
~
944020.
NEG
NEG
NEG
~ .007
—
944020•
NEG
NEG
NEG
- .009
305010030
~
589860.
NEG
NEG
NEG
.0 07
—
5 89 £60.
NEG
NEG
NEG
- .0 09
305010 <90
~
3932600.
~
.001
NEG
~
.000
~ . 0 CI
-
3932600.
-
.001
NEG
-
.00 0
- .001
-------
Table 9-2-b. 1977 MINERAL PRODUCTS UNCERTAINTIES (Continued)
industrial
TACR A NO EMISSION UNCERTAINTIES
modified
SCC
T A C3P
TO 197^ P UN
EMISSIONS
NOX
(MILLIONS OF
Hn
DAG t i
DATE = NOV 16,1977
/ YEA1?)
TONS
CO
305014000
~
• 0 0 5
NEG
NEG
—
.535
NEG
NEG
305014010
t
15 4 9 50 0 •
~
. 015
NEG
NE G
-
1546500.
.035
NEG
NEG
305015000
+
.036
NEG
NEG
—
.001
NEG
NEG
305015010
219540.
NEG
NEG
NE G
-
219540.
NEG
NEG
NEG
305015020
~
219540.
NEG
NEG
NEG
sO
219540.
NEG
NEG
NEG
1
3050150 30
~
219540.
+
. 000
NEG
NEG
-
219540.
—
. 000
NEG
NEG
30 5015040
~
219540.
NEG
NEG
NEG
-
219540.
NEG
NEG
NE C
305015 *90
~
439C70.
~
• 036
NEG
NEG
-
439070.
—
. 001
NEG
NEG
305016000
~
.000
~
. 000
+
.00 13
—
.000
. 000
-
.00 0
305016010
~
507960.
NEG
NEG
NEG
—
507960.
NEG
NEG
NEG
305016020
~
507960.
NEG
NEG
NEG
-
507960.
NEG
NEG
NEG
305016030
~
100400.
*
. 000
~
. 000
~
.00 0
100*00.
-
. ooo
—
. 000
-
.000
305016040
*
457200.
+
• 000
NEG
NEG
4-57200.
—
.000
NEG
NEG
305016*90
~
507960.
~
.009
NEG
NE G
-
507960.
—
.000
NEG
NEG
305018000
NEG
NEG
NEG
NEG
NEG
NEG
PAPT
-------
Table 9-2-b. 19 77 MINERAL PRODUCTS UNCERTAINTIES (Continued)
INDUSTRIAL PRCCESS, MINLRAL PRODUCTS
PAG:
nO
I
U1
TACF AND EMISSION UNCtfTAINTIES
PPCJrCTEl TO 19
77
f* UN
DATE -
MODIFIES
TAC9F
EMISSIONS
(MILLIONS OF
TINS
see
(SCC LNITS)
NJOX
HC
CO
3(1 5018^90
¥
130930.
NEG
KEG
NEG
•
130930.
NEG
NEG
NEG
305020000
¦f
.012 ~
. 001
¦f
.004
—
.012
. noi
-
.004
305020010
f
27457000.
NEG
NEG
NEC-
-
27457000.
NEG
NEG
NEG
305020020
27457000.
NEG
NEG
NEG
-
27457000.
NEG
NEG
NEG
3 0 50 20030
f
19544000.
NEG
NEG
NEG
-
1954<»00a.
NEG
NEG
NEG
305020040
t
19544000.
NEG
NEG
NEG
-
19544000.
NEG
NEG
NEC
305020050
~
19544000.
NEG
NEG
NFG
-
19544000.
NEG
NEG
NEG
3050 20060
"f
19544000.
NEG
NEG
NEG
-
19544000.
MEG
NFG
NE C
305020070
~
19544000.
~
.002
NEG
NEG
-
19544000•
-
.002
NEG
NEG
305020080
2104200.
NEG
NEG
NEG
2104200.
NEG
NEG
NEG
305020090
~
9404700.
NEG
NEG
NEG
-
9404700.
NEG
NEG
NEG
305020990
~
28815000.
~
.012 ~
. 001
+
.004
«•
28815000.
-
.012
.001
—
.00 4
305022000
NEG
NEG
NEG
NEG
NEG
NEG
305022990
~
1157400.
NEG
NEG
NEG
-
1157400.
NEG
NEG
NEG
30 5024000
NEG
NEG
NEG
N£G
NEG
NEG
305024010
~
256420.
NEG
NEG
NEG
4*
256420.
NEG
MEG
NE G
/ YEA1?)
PART
-------
Table 9-2-b. 1977 MINERAL PRODUCTS UNCERTAINTIES (Continued)
INHUSTxIAL PROCESS* MINERAL PPODUCTS
TACR Al\D EMISSION UNCESTAI MIES P30JECTE0 TO 1977 RUN
EMISSIONS
MODI FIE C
SCC
30?02500fl
305025010
305025 *90
305025991
305025 <92
305999000
30 5999990
T AC 3P
CSCC UNITS)
~ 17^5 3000•
17^53000.
*¦ 20503000.
20503000.
~ 10760000.
10760000.
~ 17^53000.
17^53000.
4<*9QC00.
^90600.
NOX
. 007
. 007
NEG
NEG
. 007
. 007
.007
. 007
NEG
NEG
005
005
005
005
(MILLIONS
HC
KEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
003
003
00 3
003
PAGE 5
OATE = NOV 16,1977
/ YEA9)
OF TONS
CO
~ .00?
- .002
NEG
NEG
+ .002
- .00 2
~ .00 2
- .002
NEG
NEG
.006
.00 6
.08 6
.006
PAPT
-------
Table 9-3-a. 1982 MINERAL PRODUCTS EMISSIONS AND CHARGE RATES
INDUSTRIAL PROCESS, M INFRAL PRODUCTS
PAGE 1
ANNUAL Cf*A ?GF
''A TE S ANC EMISSIONS
P'OJECTEC TO
1952
RUN
DATE =
NOV 16,1977
MODIFIED
see
TACRP
CSCC INITS)
EMIS HONS
NO X
(MILLIONS OF
HC
TONS
CO
/ YE «R)
PART
305002000
. 044
. 001
.00 3
. 500
305002010
305002020
280020000.
280020000.
. 041
.003
. 001
NEG
. 00 3
NE G
.389
.111
305003000
NEG
NEG
NEG
.382
305003010
305003020
305003030
30500 3990
25100000.
25100000.
25100000.
25999000.
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NE G
NEG
NEG
. 1*2
. 154
.069
. 018
30 5005000
NEG
NEG
NEG
.0112
305005990
1326 €00.
NEG
NEG
NEG
.002
305006000
. 079
NEG
NEG
. 438
305006010
305006020
30 5006 990
46554000.
46554000.
110800000.
. 047
. 000
. 030
NEG
NEG
NEG
NEG
NEG
NEG
.307
.119
. 012
305007000
. 045
KEG
NE G
.272
305007010
305007020
305007990
360 6 8060.
38823000.
26667000.
.045
NEG
. 000
KEG
NEG
NEG
NEG
NEG
NEG
.23*
. 033
.13 05
305006000
. 003
NEG
.00 1
. 157
305008010
305008020
305008030
305008990
122 € 800 0.
12268000.
12268000.
23825000.
.002
NEG
NEG
. 001
NEG
NEG
NEG
NEG
NEG
.00 1
NEG
NEG
. (164
. 05 9
.029
. 0 05
305009000
NEG
NEG
NE G
.014
305009030
3821200.
NEG
NEG
NEG
. 0 1*
-------
Table 9-3-a. 1982 MINERAL PRODUCTS EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS, MINFRAL PRODUCTS PAGE 2
ANNUAL CHANGE 3ATES *N[ EMISSIONS PROJECTEC TO 19 32 RUN DATE = NOV 16,1977
MCDIFIEC
T ACfiF
EMISSIONS
(MILLIONS
OF TONS /
YEAR)
see
(SCC LNITS)
NQX
HC
CO
PA FT
305010000
.005
NEG
.0 00
. 069
305010010
51253000.
NEG
NEG
NEG
. ChI
305010020
20123000.
NEG
NEG
NEG
.013
305010030
12626000.
N£G
NEG
NEG
.013
305010990
84002000.
.005
NEG
.000
.002
305014000
. 0 2 t!
NEG
*4EG
. Oil
305014010
17513000.
• 020
MEG
NEG
.011
305015000
.002
NEG
NEG
. G68
305015010
12820000.
NEG
NEG
NEG
.020
305015020
12820000.
NEG
NEG
NEG
. C01
305015030
12820000.
. 001
NEG
NEG
. 0*6
30 5015040
12820000.
NEG
NEG
NEG
. 000
305015990
2564 0 00 0•
.001
NEG
NEG
.002
305016000
.004
. 000
.00 2
.307
305016010
231+36000.
NEG
NEG
NEG
.002
305016020
23436000.
NEG
NEG
NEG
.007
305016030
2343600.
. 001
. 000
.002
.002
305016040
21112000.
. 002
NEG
NEG
. 285
305016^90
23436000.
. 001
NEG
NEG
.011
305018000
NEG
NEG
NEG
.001
30 5018 <90
2971600.
NEG
NEG
NEG
.0C1
305020000
.058
. 00 2
.012
3.337
305020010
1096200000.
NEG
NEG
NEG
.089
305020020
1096200000.
NEG
NEG
NEG
.267
305020030
1143000000.
NEG
NEG
NEG
. 82?
305020040
1143000000.
NEG
NEG
NEG
.1 37
305020050
1143000000.
NEG
NEG
NEG
.322
-------
Table 9-3-a. 1982 MINERAL PRODUCTS EMISSIONS
AND CHARGE RATES (Continued)
INDUSTRIAL PRCCESS, MINERAL PRODUCTS
ANNUAL CHANGE RATES AND EMISSIONS PROJECTED TO 19 62 RUN 0ATE = NOV
nO
i
nO
MCOIFIEC
SCC
305020060
305020070
305020030
305020090
3 05 020 ^90
305022009
305022990
30502«»00n
30502<*010
305025000
305025010
305025930
3 05025S91
30 5025 *92
T ACRF
(SCC UNITS)
11^3000000.
11^3000000*
25611000.
57224000.
175610000.
26093000.
570*000.
1019900000.
16^6000000.
626100000.
1019900000.
NO*
PAGE 3
16,1977
EMISSIONS (MILLIONS OF TONS / YEAR)
"C
NEG
.010
NEG
NEG
. 0«*8
NEG
NEG
NEG
NEG
. 031
NEG
. 031
. 031
NEG
NEG
NEG
KEG
NEG
002
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
NEG
CO
NE C-
NEG
NEG
NEG
.312
NEG
NEG
NEG
NEG
.00 5
NEG
.00 8
.008
NEG
PART
• 3 5 U
.3<*0
. C94
. 190
.221
.0^0
.0^0
.008
.008
• 6 0
.106
.1*93
.195
.3 03
305999000
305 999 ?90
100980000.
.017
.017
. no9
. 009
.023
.023
. 187
.187
-------
Table 9-3-b. 1982 MINERAL PRODUCTS UNCERTAINTIES
IhOUS TRIAL
PRCCFSS,
MINERAL PPODUCTS
PAGE 1
TACR AND
EMISSION UNCEfTAIMIES
FRCJECTt
9 TC 198? ?UN
D ATE =
NOV 16*1977
MCDIFIEC
T AC5P
EM
IS SIONS (MILLIONS
OF
TONS
t YE AC)
see
(SCC UNITS)
NOX
HC
CO
PART
3 0 5002000
4-
. Oil
. 000
~
. 001
~ .359
—
.011
. (100
—
.000
. 40<*
305002010
12409000.
•f
.011
+ . 000
«-
. 00 1
~ . 3*5
305 0020 20
-
12409000.
-
. Oil
- . 000
-
.00 0
- .369
~
124 0 900 0.
f
. 001
KEG
NEG
+ . 099
-
12409000.
-
.000
fFG
NE G
- . Ill
305003000
NEG
NEG
NEG
+ .116
NEG
NEG
NEG
- . 145
305003010
~
1098100.
NEG
NEG
NFG
~ .074
-
1093100.
NEG
NEG
NEG
- . 093
305003020
~
1098100.
NEG
NEG
NEG
~ .081
—
1099100.
NEG
NEG
NEG
- .101
305003030
~
1098100.
NEG
NEG
NEG
~ . 036
-
1093100.
NEG
NEG
NEG
. 045
305003 <90
~
1133300.
NEG
NEG
NER
~ .010
—
112 330 0*
NEG
NEG
NEG
- .012
305005000
NEG
NEG
NEG
~ .001
NEG
NEG
NEG
- . 0 CI
305005 <90
«-
77455.
NEG
NEG
NEG
~ .001
—
77i«55.
NEG
NEG
NEG
- .001
305006000
~
. 012
NFG
NEG
~ . 32?
.012
f*EG
NEG
- .3 50
305006010
~
4763500.
•f
• 008
NEG
NEG
~ .301
—
<*763500.
. 006
NEG
NEG
- .3 07
305006020
~
4763500.
. 000
NEG
NFG
~ .113
«•
4763500.
.000
NEG
NEG
- .119
305006 <90
~
19655000.
~
. 009
NEG
NEG
~ .012
19655000.
.009
NEG
NEG
- .012
305007000
~
.010
NEG
NEG
~ .2 30
-
. 007
NFG
NEG
• 236
-------
Table 9-3-b. 1982 MINERAL PRODUCTS UNCERTAINTIES (Continued)
INDUSTRIAL
PR CC ESS t MINERAL
PRODUC TS
PAGE 2
TACR AND
EMISSION UNCERTAIMTIES
P90JECTET TO 1982 ?
UN
Q AT E =
NOV 16,1977
MODIFIED
TAC3F
EMISSIONS
(PILLIONS
OF
TONS
/ YEAR)
see
(SCC UNITS)
M0 X
HC
CO
PAPT
305007010
~
1173^00.
~
.010
NEG
NE G
+ . ?2<5
-
1173900.
-
.007
NEG
NEG
- ,Z3<»
305007020
1197000.
NEG
fEG
NFG
.031
-
1197000.
NEG
NEG
NEG
- .033
3 0 5007^90
~
56^2200.
~
.008
NFG
NEG
+ . 0 05
-
56^2200.
—
.000
NFG
NEG
- .005
305008000
. 000
NEG
+
.00 0
* .0^3
—
.003
NEG
-
.00 0
- . 061
305008010
t
820270.
4-
. ooa
NEG
NEG
~ . 03*
-
820270.
-
.050
NEG
NEG
- . QU2
305008020
«•
82 0 270.
NEG
NEG
+
.000
* . 031
-
820270.
NEG
NEG
-
. 00 0
- . 039
305008030
~
820270.
NEG
NEG
NEG
* . T15
-
820270.
NEG
NEG
NEG
- .019
305008990
~
159<»400.
~
.000
NEG
NEG
~ .003
-
159<^Q0.
-
.009
NEG
NEG
- .004
305009000
NEG
NEG
NEG
~ . 005
NEG
NEG
NEG
- .005
3050090 30
~
3^7210.
NEG
NEG
NEG
* . 005
—
3^7210.
NEG
NEG
NEG
- . 0 05
305010000
>
. 001
NEG
*
.000
+ . 028
•
.001
KEG
.00 0
- . 0i» 1
305010010
~
2^82200.
NEG
NEG
NEG
*¦ . 026
-
2^62200.
NEG
NEG
NEG
- . 0 33
305010020
~
977300.
MEG
NEG
NEG
+ .0 03
-
977200.
NEG
NEG
NEG
- .012
3050100 30
~
610290.
NEG
NEG
NEG
~ . 0 08
—
610290.
NEG
NEG
NEG
- .012
305010 <90
~
<~071100.
~
. 001
NEG
+
.000
+ .001
-
*~071100.
-
. 001
NEG
-
.00 0
- .002
-------
Table 9-3-b. 1982 MINERAL PRODUCTS UNCERTAINTIES (Continued)
INDUSTRIAL PROCESS, MINFRAL PRODUCTS PAGE 3
TACfi ANO E^ISSIOf UNCEFT A I NTTES FRCJ ECTE1 TO 118? PUN 0 AT t = NOV 16,1977
MODIFIED
TACfiF
EMISSIONS
< MILLIONS
OF
TONS /
— - — » / — ' ¦
YE AR>
see
CSCC UNITS)
NOX
CO
PART
305014000
+
. 006
NEG
NEG
~ .cos
. 016
NEG
NEG
- .0 03
3 05 014 010
~
1701Z03.
4-
. 006
NEG
NE G
+ .0 03
—
17nic09.
—
• 0 06
NEG
NEG
- . 003
3 0 5015000
~
. 042
NEG
NEG
~ .041
-
. 000
NEG
NEG
- .050
305015010
509210.
NEG
NEG
NEG
~ .0 17
-
509 310.
NEG
NEG
NEG
- .020
305015020
~
509210.
NEG
NEG
NEG
+ . 000
—
509210.
NEG
hEG
NEG
- .001
305015030
~
509310.
~
.000
NEG
NEG
~ .037
-
509310.
-
. 000
NEG
NEG
- . 0*»6
30 5015040
~
509310.
NEG
NEG
NEG
«• .000
—
509210.
NEG
NEG
NEG
- .000
305015990
~
1018 600.
~
. 042
tEG
NEG
~ .001
-
1018600.
—
. 000
NEG
NEG
- . 002
305016000
4-
.031
«•
. 000
~
.001
~ . 237
—
. 000
—
. 000
-
.001
- . 285
305016010
#•
819740.
NEG
NEG
NEG
* .002
—
819740.
NEG
NEG
NEG
- .0 02
305016020
+
819740.
NEG
NEG
NEG
+ . 0 05
-
819740.
NEG
NEG
NEG
- .0 05
305016030
119250.
~
. 000
~
.000
~
.001
.001
-
119250.
-
.000
-
. 000
-
.00 1
- . 001
305016040
~
738690.
~
. 001
fEG
NEG
* . 237
-
738690.
-
.000
NEG
NEG
- .285
305016 <90
f
819740.
~
. 009
NEG
NEG
~ • .008
—
819740.
—
. 000
NEG
NEG
- .0 09
305018000
NEG
NEG
NEG
+ .001
NEG
NEG
NEG
- .001
-------
Table 9-3-b. 1982 MINERAL PRODUCTS UNCERTAINTIES (Continued)
INDUSTRIAL ACCESS, MlNFRAL PcOr>UCTS
PAGE
TACR AND EMISSION UNCERTAINTIES
P'CJFCTED TO 1982
PUN
D ATF =
MOOIFIE C
TACR F
EVIS 51 0NS
(fILLlONS CF
TONS
see
CSCC UNITS)
M0 X
H C
CO
305018°9Q ~
17 6 2^1.
NEG
NEG
NLG
—
176240.
NEG
NEG
NEG
3050?0000
~
. 0 1** ~ •
. 001
¦f
.007
—
.010
. 001
m
. 00 t
305020011 ~
4812<»00 0 .
NEG
NEG
NEG
4812400 0.
NEG
NEG
NE C
305020020 ~
4812^000.
NEG
MEG
NEG
+8124000.
NEG
NEG
NEG
305020030 *¦
4522700 0.
NEG
KEG
NEG
45227000.
NEG
NEG
NE C
305020040 ~
45227000.
NEG
NEG
NEG
4522700 0.
NEG
NEG
NEG
305020050 «•
45227000.
NEG
NEG
NEG
45227000.
NEG
NEG
NEG
305020060 ~
45227000.
NEG
NEG
NEG
4522700 0.
NEG
NEG
NEG
305020070 ~
45 227000.
~
.002
^G
NEG
45227000.
—
. 0 02
NEG
NEG
305020050 *
2312 EDO.
NEG
KEG
NE C
2312600.
NEG
NEG
NEG
305020090 ~
96A1C00.
NEG
NEG
NEG
9641900.
NEG
NEG
NEG
30 5020S90 «¦
29557000.
*
.014 ~
. 001
+
.00 7
—
29557000.
—
.010
. 001
—
. 00 U
305022000
NEG
NEG
NEG
NEG
NEG
NEG
3050 22 ^90 ~
1564200.
NEG
NEG
NEG
—
1564200.
NEG
KEG
NEG
30S024000
NEG
NEG
NE G
NEG
NEG
NEG
305024010 ~
347020.
NEG
MEG
NEG
-
347020.
NEG
KEG
NE G
PAPT
00?
0 0?
-------
Table 9-3-b. 1982 MINERAL PRODUCTS UNCERTAINTIES (Continued)
I NOUS TRIAL PROCESS, MINERAL PRODUCTS
T ACR AND EMISSION UNCEPTAIMIES PROJECTED TO 19B2
EMISSIONS
SUN OATE=
MODIFIEC
SCC
305025000
305025010 *
30 ?025?90 *¦
30 502 5 *91
30 5025 992 ~
TACRF
(SCC UNITS)
<40387000.
<~0367000.
^73ct,000.
<~73^000.
2
-------
Those industries which are the main sources of PART
emissions are listed in Table 9-4 in the order of decreasing PART emissions
rate for 1977. The projected level of PART emissions for 198Z are in-
cluded for comparison. Table 9-4 shows that the major contributor to PART
emissions is the stone quarrying and processing industry, which accounts
for approximately half of the total PART emissions shown for all mineral
products industries. PART emissions are high in this category for several
reasons: (1) the high PART emissions factor; (E) the large process tonnage
involved; and (3) the somewhat low level of PART emissions control in
relation to most of the other mineral products categories. The numerical
value of the uncontrolled emission factors for stone processing is, however,
more questionable than for some of the other mineral product categories.
The significance of each of these factors is treated in Section 9.4.
Other major sources of particulate emissions are cement
manufacturing (both wet and dry processes), sand and gravel processing,
asphaltic concrete production, brick and clay manufacturing (combined in
Table 9-4 due to the basic similarity of the unit operations involved), and
lime manufacturing. Sand and gravel processing is the only industry cat-
egory showing a projected increase in PART emissions between 1977
and 1982. This results from the projected increase in process rate plus
the assumption that one of the major emission sources (open storage) will
be subjected to little additional control by 1982. Details on this and other
factors underlying the above data are discussed in Section 9-4.
NO^ emissions for all mineral products industries are
relatively low, about 0.29 megatons per year in 1977, with about 0. 31
megatons per year projected for 1982. HC and CO emissions are not
significant.
9. 3 APPROACH
This section describes the basic approach used to gather
and analyze the data upon which the emission inventory data shown in the
preceding subsection were based. Data acquisition and interpretation
focused on three main areas: (1) charge rate information {present and
9-25
-------
Table 9-4.
MSCC
305-XXX-000
020
006+007
002
003+008
025
016
010
015
Subtotal
999
Source Category
Stone processing
Cement
Asphaltic concrete
Brick and clay
Sand and gravel
Lime
Coal cleaning
Gypsum
Miscellaneous
Totals
PARTICULATE EMISSIONS
1977
10 tons/yr % of Total
1982
10 tons/yr % of Total
3. 834
49. 32
3. 337
53. 43
1. 125
14.47
0.710
11. 37
0. 652
8. 39
0.500
8. 01
0. 645
8. 30
0. 589
00
1/1
0.604
9. 67
0.400
5. 15
0. 307
4. 92
0. 102
1. 31
0.068
1. 09
0. 083
1. 07
0. 068
1. 09
7.430
95. 59
5. 982
95. 79
0.247
3. 18
0. 187
2. 99
7. 677
98. 76
6. 169
98. 78
-------
projected levels); (2) uncontrolled emission factors; and (3) present and
projected levels of technology and application of PART control equipment.
The primary data sources for charge rate information were
three series of publications by the Bureau of Mines, U. S. Department of
the Interior. These were the Minerals Yearbook (past annual issues and
the most recent preprints of selected chapters), Mineral Industry Surveys
(monthly, annual advance summaries and preliminary summaries by
industry), and Mineral Facts and Problems, 1975 edition. These sources
provided a complete and internally consistent set of statistics for historical,
current, and projected production and/or process rates for most of the
process categories of interest. Useful sources of supporting information
were current and back issues of Rock Products magazine and Pit and Quarry
magazine (both published in Chicago, Illinois). Trade associations such as
the Portland Cement Association and the National Asphalt Pavement Associ-
ation also provided useful information and statistics on production rates
and projected growth rates.
The main source for uncontrolled emission factors was the
EPA compilation of Air Pollutant Emission Factors, AP-42 (Ref. 9-1).
Cognizant EPA personnel at Durham, North Carolina, were contacted to
ensure that the most recent information was used for each process cat-
egory.
The most difficult aspect of data acquisition and analysis
concerned the assessment of the PART control technology and the extent
of application of that technology to each process category. All of the data
sources mentioned were utilized for this purpose. EPA standards support
documents were useful for those industries for which new source perform-
ance standards have been promulgated or proposed. Appendix IV-D of
Ref. 9-2 provided helpful guidelines concerning the PART emission con-
trol standards in use by the different states. Reference 9-3, prepared
by the Los Angeles Air Pollution Control District, provided detailed
information on those process categories which are in operation in the Los
Angeles area. A literature search of relevant technical journals, partic-
ularly Chemical Engineering, Journal of the Air Pollution Control
9-27
-------
Association, and Environmental Science and Technology, also provided
useful inputs. For each process category, a best judgment selection was
made from all of the inputs from these sources of current and projected
pollution control equipment efficiency and application.
The existing NEDS data base (Ref. 9-4) was examined for
each process category in terms of each of the three main areas of data
acquisition (charge rate, uncontrolled emission factors, and application
and efficiency of control techniques). The NEDS charge rate data were,
in general, substantially lower than the corresponding Bureau of Mines
data. The NEDS charge rate data were only utilized for some of the -099
"other(not classified)" categories, which could not be reasonably assigned
to identifiable processes or unit operations. Uncontrolled PART emission
factors for these unidentified processes were derived from the NEDS data.
The detailed printouts of the NEDS data which showed the generic type of
control equipment in use, and its extent, were useful in that they per-
mitted estimates to be made of PART emission control equipment appli-
cation and the effectiveness for each process. This information formed a
valid input to the final selection of present and projected values for these
parameters. The NEDS data were also the main source of the relatively
small uncontrolled emission factors for NOx, HC, and CO. These para-
meters were, in general, not covered in Ref. 9-1.
9.4 DISCUSSION
The key aspect of the mineral products industrial classi-
fication, from the viewpoint of this study, is clearly PART emissions.
This section is accordingly restricted to a discussion of the more important
individual factors which are influential on the final computed value of partic-
ulate emissions summarized in Section 9.2.
The indicated emissions from the stone quarrying and
processing industry (MSCC 305020000) are of overriding magnitude. It
is important to note that the uncontrolled emission factors for the sub-
categories -010 thru -060 are based on PART emissions measurements
9-28
-------
performed on one occasion at one stone crushing plant (Refs. 9-5 and 9-6).
Moreover, the emission factors for these subcategories were all expressed
in terms of pounds of emissions per pound of rock input to the primary
crusher. This forces one to make the assumption that the ratio of process
rock to the other subcategories (such as tertiary crushing/screening, -030,
and fines mill, -050) which prevailed during this test is representative
of the industry-wide average. An error in this assumption could be highly
significant because, as shown in Tables 9-2-a and 9-3-a, these two sub-
categories (-030 and -050) account for approximately half the indicated
emissions for all of the stone processing industry (MSCC 305020000), which
in turn accounts for approximately half of all indicated PART emissions for
the entire mineral products industrial classification.
If the magnitude of the indicated PART emissions from the
stone processing industry is judged to be of significant concern, it would
appear that a necessary first course of action would be to expand the data
base from which these uncontrolled emission factors were derived.
Another interesting subcategory of stone processing is -070,
Open Storage. Reference 9-7 describes a careful series of measurements
performed on a sand and gravel processing plant, the results of which
have been incorporated by EPA (Ref. 9-1) into the AP-42 emission factors
for stone processing. This emission factor is expressed as
p = 0- 33
/PE \ 2 (9-1)
\100/
where PE is a precipitation-evaporation index, numerical values of which
are given by geographical location in AP-42. From the AP-42 geographical
presentation, this study estimated an average value of PE for each state
and applied the resulting emission factor to the charge rate of stone
quarrying/processing for that state (as given in the Bureau of Mines Min-
eral Yearbook). Total PART emissions were then summed over all the
states and divided by the national charge rate to yield a nationwide average
estimate for the uncontrolled emission factor for open storage of 0. 61
9-29
-------
lb /ton of material stored. It was assumed that all crushed stone pro-
duction is subject to open storage at some stage of its processing. It is
interesting to note that the value of 0. 61 lb/ton is approximately 16 times
smaller than the former AP-42 value of 10 lb/ton, which was apparently-
based on an estimate, unsupported by measurement (Ref. 9-5).
The next largest source of PART emissions in the mineral
products category is cement manufacturing (wet and dry processes com-
bined). This was the first industry in the mineral products category to be
subjected to EPA new source performance standards and, consequently,
is expected to be in an advanced state of control by 1982. It should be
noted that MSCC process categories 305006010 and 305007010 represent
all kiln operations (for the dry and wet processes, respectively) for all
types of fuel. NEDS further provides categories (-030, -040, and -050)
corresponding to oil-, gas-, and coal-fired kilns, respectively, for both
305006000 and 305007000. AP-42 PART emission factors are identical
for all these kiln operations, however, regardless of the fuel. That is,
MSCC 305006010, -030, -040, and -050 all have the same emission factor,
while the charge rate for process 305006010 equals the sum of the charge
rates for processes -030, -040, and -050. Similar remarks apply to
MSCC 305007010, -030, -040, and -050. Computations have been per-
formed during this study for each of these -030, -040, and -050 categories
by fuel type (current and projected to 1982) and are available on request.
They are not listed in the printouts of Section 9.2, however, as they pro-
vide no additional information on total particulates generated (all of which
are accounted for in the -010 category). Moreover, their inclusion in the
computer data base, in accordance with existing NEDS format, would
result in an erroneous double counting of emissions for kiln operations.
A new process subcategory was added to sand and gravel
processing (MSCC 305025000) in that open storage was included as a
source of PART emissions and is listed as MSCC 305025992. The value
of 0. 61 lb/ton, as determined for MSCC 305020070, was used. Neither
NEDS nor AP-42 lists such a category for sand and gravel, but this study
9-30
-------
considered it appropriate to do so in view of the prevalence of open
storage in sand and gravel operations. As noted, the revised AP-42
emission factor for open storage of crushed stone was based on measure-
ments performed at a sand and gravel plant. This new process category
is a major contributor to the indicated PART emissions from sand and
gravel plants, as shown in Tables 9-2-a and 9-3-a.
Finally, it should be noted that the primary and secondary
crushing operations of limestone attributed to lime production {MSCC
305016010 and -020) also represent a portion of the charge rate for the
corresponding MSCC 305020010 and -020 categories for stone quarrying/
processing. It was considered more appropriate to include these emissions
in the inventory of lime production. The charge rates for processes
MSCC 305020010 and -020 have therefore been decreased by the tonnage
of limestone which is crushed for the purpose of lime production. The
uncontrolled emission factors used for lime production represent revised
values released by EPA in Supplement 7 of AP-42 {April 1977).
9. 5 REFERENCES
9-1. Compilation of Air Pollutant Emission Factors, AP-42
2nd ed. (and supplements}, U. S. Environmental Protection
Agency, Research Triangle Park, North Carolina
(April 1973).
9-2. T. G. Hopper, et al, Impact of New Source Performance
Standards on 1985 National Emissions from Stationary
Sources, U. S. Environmental Protection Agency, Office
of Air Quality Planning and Standards, Research Triangle
Park, North Carolina (October 1975); prepared by The
Research Corporation of New England, Wethersfield,
Connecticut.
9-3. Air Pollution Engineering Manual, 2nd Edition, AP-40,
U. S. Environmental Protection Agency, Research
Triangle Park, North Carolina (May 1973); prepared by
Air Pollution Control District, County of Los Angeles.
9-4. Nationwide Emissions Summary, National Emissions Data
System, U. S. Environmental Protection Agency, Research
Triangle Park, North Carolina (November 15, 1976).
9-31
-------
Air Pollution Emission Factors, PB-206 924, TRW
Systems Group, National Air Pollution Control Admin-
istration, Washington, D. C. (April 1970).
Source Inventory and Emission Factor Analysis, NTIS
PB-247743, PEDCO-Environmental Specialists, Inc.
(September 1974).
C. Cowhered, et al. , Development of Emission Factors
for Fugitive Dust Sources, NTIS PB-238 262. U. S.
Environmental Protection Agency, Research Triangle
Park, North Carolina (June 1974); prepared by Midwest
Research Institute, Kansas City, Missouri.
9-32
-------
SECTION X
WOOD PRODUCTS
10. 1 INTRODUCTION
This section presents the results of the inventory of
emissions from wood processing operations involved in the conversion of
raw wood to various intermediate or finished products. The major
processes of the wood industry are those involved in the manufacture of
pulp, paper, plywood, and pulpboard. Wood waste energy conversion
processes are normally classified under the "External Combustion in
Boilers" category. However, emissions from this source were so small,
compared to other boiler sub-categories, that they are not included any-
where in this report.
A National Emissions Data System (NEDS) computer tape
and other sources of data on production histories and emission rates were
used to select the specific processes and air pollutants which are signifi-
cant compared to the emissions of these air pollutants from other stationary
point sources. Table 10-1 shows those processes selected for further
study. These categories are generally as described in Ref. 10-1, with the
NEDS Source Classification Codes (SCCs) modified slightly (MSCCs) to
allow for a more detailed breakdown of some of the categories (see Section
1.4. 3 for further discussion of the MSCC coding system).
10.2 SUMMARY
The charge rates and emissions of each of the categories
listed in Table 10-1 are presented in Tables 10-2-a and 10-3-a, and the
corresponding uncertainties of each of these parameters in Tables 10-2-b
and 10-3-b.
(Continued on page 10-11)
10-1
-------
Table 10-1. Definition of Wood Products Processes
MSCC
Source Category
Charge Rate Unit
307001000
307001030
307001040
307001050
307001060
307001090
307001990
Kraft (sulfate) Pulping
Multiple effects
Recovery boiler/direct contact
evaporator
Smelt dissolving tank
Lime kilns
Liquor oxidation tower
Other (not classified)
Air dry tons unbleached
Air dry tons unbleached
Air dry tons unbleached
Air dry tons unbleached
Air dry tons unbleached
Air dry tons unbleached
N. A.
307002000
307002010
307002040
307002990
Sulfite Pulping
Liquor recovery
Smelt tank
Other (not classified)
Air dry tons unbleached
Air dry tons unbleached
Air dry tons unbleached
N. A.
307004000
307004020
307004990
Paperboard - General
Fiberboard
Other (not classified)
Tons of finished product
Tons of finished product
N. A.
307006000
307006010
Tall Oil/Rosin
General
Tons of product
Tons of product
307007000
307007010
307007020
307007990
Plywood/Particleboard
Veneer drying
Sanding
Other (not classified)
Tons of product
Tons of product
Tons of product
N. A.
307008000
307008990
Sawmill Operations
Other (not classified)
Tons processed
N. A.
307020000
307020990
Furniture Manufacturing
Other (not classified)
Tons processed
N. A.
307999990
Other (not classified)
N. A.
10-2
-------
Table 10-2-a. 19 77 WOOD PRODUCTS EMISSIONS AND CHARGE RATES
INDUSTRIAL PROCESS, fcOOO P-COUCTS PAGE 1
ANNUAL CHA^GT *AT£S ANC EMISSIONS PROJECTEC TO 1977 *UN DATE = NOV 16,1977
MODIFIED
see
T ACtP
ISCC tMTSI
E*!
no*
IS SI ONS ( PILLIONS
HC
OF TONS
CO
/ YEAS)
PACT
307001000
.005
. 005
.637
. 27 3
307001030
3 07 001040
3 07 001050
307001060
307001090
307 001*90
379^5000.
3796 5 00 0.
3796 5 CO 0 •
37965000.
37965000.
37965C00.
1. 000
.003
NEG
.002
NEG
NEG
NFG
. 005
NEG
0 . 000
0 . 000
NEG
.00 1
.513
.02 l
.100
NFG
NEG
3. 0C0
.195
. 0*»7
. 025
NEG
.003
307002000
. 000
NFG
.025
. 007
3 07 002010
307002040
307002 <90
1651100.
536370.
183*»<«0a.
1. 000
1. 000
.000
0. 00 0
NEG
NEG
.02 5
0.0 0 0
ME G
. 0 07
.000
.000
307004000
11132000.
NEG
. 009
NEG
.001
307004020
30 7004990
7125000.
39^7000.
NEG
NEG
. 005
. 004
0.000
NEG
. 0 CO
.000
307006000
4A 700 0.
NEG
. 001
NEG
NEG
307006010
41*7000.
NEG
. 001
NEG
NEG
307007000
62520000.
. 003
. 0t56
.00 1
. 0 <^2
307007010
307007020
307007990
10520000 .
13900000.
38100000.
.002
0. 000
.002
. 004
0. 000
. 002
o .o n o
0.000
.00 1
.0 01
. 0 CO
.021
307008000
161900000.
NEG
. 001
.00 1
. 021
307008990
161900000.
NEG
. 001
.001
.021
3 0 7020000
2525000.
NEG
. 004
NEC
.007
307020 *90
2525000.
NEG
. 004
NFG
. C07
-------
Table 10-2-a. 1977 WOOD PRODUCTS EMISSIONS AND CHARGE RATES (Continued)
INDUSTRIAL PROCESS, WOOD PRODUCTS PAGE ?
ANNUAL CHA SATES ANC EMISSIONS PR 0 JEC T E 0 TO 1977 PUN 3 ATE = NOV 16,1977
MCDIFIEt TACRF EMISSIONS (VILLIONS OF TOMS / YEAR1
SCC (SCC UNITS) N9X HC CO PART
307999000 0. 0.010 0.000 0.000 0.000
3079C9S90 0. 0.000 0.000 0.000 0.000
0
1
•£»
-------
Table 10-2-b. 1977 WOOD PRODUCTS UNCERTAINTIES
I NO-JS TRIAL PROCESS, WOOH P-ODUCTS PAGE 1
TACF A MO EMISSION UNCERTAINTIES PROJECTED TO 1977 ft UK OAT E = NOV 16,1977
MODIFIED TAC'F EMISSIONS MILLIONS OF TONS / YEAC)
see
(SCC UNITS)
N0X
HC
CO
PAPT
30 7001000
~
. 0 38
+¦
. 001
+
.39 7
+ .172
-
.003
—
. Hf)l
.39 7
- .2 01
3 0 700 10 30
+
35COOOO.
4-
0. 009
NEG
+
.00 1
4- 0.003
-
3500000.
-
0. 003
NPG
.001
- 0.0 00
30700l0
-------
Table 10-2-b. 1977 WOOD PRODUCTS UNCERTAINTIES (Continued)
I NDtJST^lA L PROCESS, WOO 0 PRODUCTS PAGE 7
TACR ANT EMISSION UN CE FT fil MIES F'.CJEOTET TO 1977 9 UN DAT E = NOV 16,1977
MODIFIED TACRF EMISSIONS (MILLIONS OP TONS f YEAS)
sec.
CSCC UNITS)
NOX
HC
CO
PAFT
307006010
~ 50062.
NEG
4-
. 000
NEG
NEG
50062.
NEG
-
.coo
NEG
NEG
307 00 700(1
~ 218 630»
+
. 000
*
. "00
«¦
.oor
~
.003
21S 63 0«
—
.0 00
-
. 000
-
.0 0 0.
-
.0 C3
507007010
~ 100000.
4-
. 000
4-
. coo
~
0.00 0
4-
. 000
307007020
100000.
-
.000
-
. (00
_
0.00 0
m
.0 00
~ 101980.
4-
0.000
~
0. 000
«•
0.00 0
4-
.000
307007 <90
101980.
—
9. 000
—
0 . 00 0
_
0.000
-
. 0 00
~ 165530.
4-
.000
4-
. 000
*
.00 0
~
.0 03
165530.
.000
—
.000
-
.00 0
-
.003
307005000
»• 0.
NEG
f
0. 000
~
0.00 0
+
0. OOO
0.
NEG
—
o. noo
-
0.00 0
-
.0 17
307008 <90
* 0.
NEG
*
0. 000
+
0.00 0
*
0.000
0.
NEG
—
0 . 000
-
0.000
-
.017
307020000
* 200000.
NEG
4-
. 000
NEG
4-
. 0 CI
200000.
NEG
-
. 000
NEG
-
.001
307020 <90
~ 200000.
NEG
~
. noo
NEG
~
.on
200000.
NEG
—
. 000
NEG
-
. oot
307999000
~ 0.
+
0.000
~
o .noo
~
0.000
+
0.003
0.
0.000
—
0 .000
-
0.00 0
-
0 . 000
307999
-------
Table 10-3-a. 1982 WOOD PRODUCTS EMISSIONS AND CHARGE RATES
INDUSTRIAL PROCESS, W CO Q PRODUCTS "AG? 1
ANNUAL CHARGE «ATES PNC EMISSIONS PROJECTED TO 19^2 FUN 3 AT E = NOV 16,1977
MODIFIED
see
T AC3F
(SCC UITS)
EMISSIONS
NO X
(PILLIONS
HC
OF TONS /
CO
YEA9)
PART
3 07001000
NEG
NEG
.375
• 25 5
307001030
3 0 7001040
307001050
307001060
307001090
307001990
44130000.
44130000.
44130000.
44130000.
4413QGOO.
44130000.
0. 000
0.003
NEG
0.000
NEG
MEG
NEG
0. 000
NEG
0. 000
o. noo
NEG
0.000
.265
0 .00 0
.110
N£G
NEG
0.000
. 197
. 055
. 0 30
NLG
. n 14
307002000
.000
NEG
.021
.0 05
307002010
307002040
307002990
1374100.
441570.
1495700.
0. 000
0. 000
. 000
o.ono
NEG
NEG
.021
0.000
NEG
.006
.000
. 0 00
307001*000
13297000.
NEG
. 007
NEG
.001
30700U020
30 7004 <90
8800000•
4497000.
NEG
NEG
. 004
. 00 3
0.00 0
NEG
. 001
. 0 CO
307006000
3 9200 0 •
NEG
. 001
NEG
NEG
307006010
392000.
NEG
. 001
NEG
NEG
307007000
70520000.
.002
. n04
.001
. 0 23
307007010
307007020
307007990
12520000.
16400000.
41600000.
.002
0. 000
0. 000
• PQ 3
0.000
.000
0.000
0.000
.00 1
.001
. COO
. 022
307008000
162400000.
NEG
. 001
.00 1
.021
307008990
162400000.
NEG
. 001
.00 1
. Udl
307020000
2 650000.
NEG
. 004
NEG
. 0 04
307020 cqn
2650000,
NEG
. 004
NEG
.00 +
-------
Table 10-3-a. 1982 WOOD PRODUCTS EMISSIONS AND CHARGE RATES
(Continued)
INDUSTRIAL PROCESS, WOOH PFODUCTS PAGE :
ANNUAL r,FA-iGE ?A TES ANC EMISSIONS PROJECT EH 70 198? &UN DATE- NOV 16,1977
MODIFIED T ACS f EMISSIONS (MILLIONS CF TONS / YEAR)
SCC (SCO UNITS) NO X HC CO PA»T
307999000 0. 0.000 0.000 0.000 O.COO
3079^9990 0. 0.000 0.000 0.000 3.003
0
1
00
-------
Table 10-3-b. 1982 WOOD PRODUCTS UNCERTAINTIES
INDUSTRIAL 3R0SESS, WCOH cR0 DUCT S PAGE 1
TACF ANO E"4ISSI0h UNCEFTAINTIES FSCJECTE} TC 198? 'UN DAT F= NOV 16,1977
MODI FIEC
T ACS F
EMISSIONS
( MILLIONS
OF
TONS /
YE AR)
see
(SCC UMTS)
NO*
h r
CO
P A c T
3 07 00100(1
NEG
NEG
+
.46P
~ .170
NEG
NEG
—
.2 87
- . 202
30700 10 30
~
7 000000.
+
0. 000
NEG
~
0.00 o
+ 0. 0 00
-
7 000000.
-
0. 000
NEG
-
C. 00 0
- o. ono
3070010 **0
~
7000000.
+
0. 000
~
o. noo
+
.45?
~ . 16*
-
7000000.
-
n. noo
-
o. coo
-
.26?
- .197
307001050
~
7000000.
NEG
NEG
+
0.00 0
*¦ .0 46
-
7000000.
NEG
NFG
0.00 0
• • 0 4 6
307001060
~
7000000.
+
0. 000
*
0. 00 0
+
.123
~ .005
-
7000000.
—
0. 000
-
0. 00 0
-
.110
- .005
307001090
~
7000000.
NEG
~
0. 00 0
NEG
NEG
-
7000000.
NEG
-
0. 00 0
NE C
NEG
307001990
~
7000000.
NEG
NEG
MEG
~ .001
7 000000.
NEG
NEG
NEG
- .001
307002000
~
. 000
NEG
+
.00 c
~ . 001
—
. 000
hEG
-
.00 5
- . CC1
307002010
«¦
348E50.
~
0. 000
«•
0. 00 0
4-
.00 5
~ .0 01
-
348350.
0. 000
-
0. 000
•
.00 E
- .0 01
307002040
~
139010.
~
3. 000
fEG
+
a. ooo
~ .003
128010.
-
0. 009
NEG
-
0.000
- . 0 00
3 0 700 2 *90
~
66023.
•f
. 000
NEG
NEG
+ . ono
86023.
—
.000
NEG
NEG
- .000
307004000
+
387260.
NEG
~
. noo
NEG
~ . 00(1
-
387260.
NEG
-
. 00 0
NEG
- . 0 00
307004021
+
363140.
NEG
4-
. 000
~
0.000
~ . 0 00
-
363140.
NEG
-
. QOO
-
0.00 0
- .003
307 0 04990
~
134540.
NEG
~
. 000
NEG
~ . 0 DO
-
134540.
NEG
—
. noo
NEG
- . 0 00
307006000
f
59249.
NEG
•f
. 00 0
NEG
NEG
-
50249.
NEG
-
. ooo
ME G
NEG
-------
Table 10-3-b. 1982 WOOD PRODUCTS UNCERTAINTIES (Continued)
INDUSTRIAL
PROCESS,
wooc
PRODUCTS
p
AGE
TftCR AND E"
ISSION UNCEFTAI MIES
PR0J rCTET
TO 198? 3UN
DATE =
NOV 16,
1977
MCOIFIEC
TACRF
EMISSIONS
t MILLIONS
CF
TONS
/ YE *R)
see
CSCC LNITSI
NO X
hr,
CO
PART
307006010
~ 50249.
NEG
~
. 000
NEG
NEG
50249.
NEG
—
. coo
NEG
NrG
507007000
~ 34 048 0*
~
. 000
~
. 000
+
.00 0
~
. fl04
340480.
—
• 000
—
. Q00
-
.00 0
-
.004
30 70 07010
~ 136010.
~
• 000
4-
. 000
0. 000
~
.0 00
136010.
—
• 003
-
. OOQ
—
0. 00 0
. 000
307007020
~ 122070.
~
0. 000
«¦
0. 000
~
0. 00 0
~
. 009
30 7007 <90
122070.
—
0.000
—
0. 00 0
•
0.00 0
. 0 00
~ 287270.
~
0. 000
*
. 000
«¦
. 000
~
. 0 04
287270.
—
0. 000
-
. (00
-
.00 0
-
. 0 04
307008000
~ 0.
NEG
~
0. 000
~
0.00 0
0.000
0.
NEG
o. noo
—
0.00 0
-
.017
307008 «90
~ 0.
NEG
4-
o.ooo
+
0.000
+
0. 000
0.
NEG
•
0. GOO
-
0.00 0
-
.017
307020000
* 200000.
NEG
~
. 000
NEG
f
. 0 00
200000.
NEG
-
. 00 0
NEG
-
.000
307020 *90
~ 200000.
NEG
~
. 00 0
NEG
~
. coo
200000.
NEG
-
. 000
NEG
-
. 0 00
307999000
~ 0.
~
0. 000
~
0 . 000
•f
0.000
+
0.000
0.
—
0. 000
—
0. coo
-
0.00 0
-
0. 000
307999*90
~ 0.
V
0. 000
~
0. 000
~
0.000
~
0. 000
0.
—
0. 000
-
0.000
-
0.000
-
0. 009
-------
The most significant air pollution emissions in this category
are particulates (PARTS), primarily from the Kraft pulping process. Total
carbon monoxide (CO) emissions are also relatively high, but there are
currently no required controls on these emissions. All CO emissions re-
ported in NEDS are based on estimates rather than on measured values or
on well-founded emission factors.
Total PART emissions from the entire wood products cat-
egory are estimated to be 1. 87 percent of those from all stationary point
sources, with about 96 percent of these emissions resulting from the Kraft
pulping process. Similarly, 2. 11 percent of the CO emissions from all
stationary point sources results from all sources defined within the wood
products industry, with 82 percent of these from the Kraft pulping process.
Although PART and CO emissions result from several subprocesses in the
overall Kraft (sulfate) pulping process, the predominant source of these
emissions is a combustion process in the recovery furnace. Here, the
inorganic cooking chemicals, used to dissolve the lignin in the wood, are
recovered essentially by burning off the organic content.
Emission controls for both PART and CO are being imple-
mented in Kraft mills. Although a 16 percent increase in output from the
Kraft mills is projected over the next five years, only a 4 percent rise in
PART emissions and a 41 percent decrease in CO emissions are projected
over the same period.
Although sulfur compounds are the most significant emissions
from the wood products category of stationary sources, they are not within
the defined scope of this inventory.
i°. 3 PROCESSES EVALUATED
A survey of the NEDS data base (Ref. 10-1) was conducted
to determine which of the point sources contributed significantly to the
inventory. The criteria of selection was based on the annual charge rate
of significant emissions. The selected processes are discussed in the
following paragraphs.
10-11
-------
10.3.1 Pulp and Paper Manufacturing
The chemical pulping process, which frees the wood fibers
by dissolving the binding material (lignin) in chemical solutions, was found
to be the only portion of the pulp and paper manufacturing process that
required detailed study (Ref. 10-2). Furthermore, only the Kraft (sulfate)
process and the sulfite process were emphasized.
In June 1971, Kraft (sulfate) pulping accounted for 67 per-
cent of all wood pulp produced (Ref. 10-3). By 1976, this production had
grown to 72 percent. This process involves a chemical recovery cycle to
reclaim the liquor. The spent sodium sulfite is converted to sodium sul-
fate, subsequently reduced to sodium sulfide, and concentrated by evapor-
ation. PART and CO emissions primarily result from this liquor recovery
cycle. The spent liquor passes through five serial phases in the recovery
process, and each of these phases has the potential of producing some air
pollutant emissions. Separate emission factors are listed for each of
these phases, but all are based on the same process charge rate, the
amount of pulp (air-dried, unbleached) produced by the plant.
The five phases in the chemical recovery cycle are as
follows:
a. Multiple Effects Evaporation. The multiple effects
evaporation phase concentrates the weak "black
liquor" in order to facilitate combustion of the
dissolved organic material.
b. Recovery Furnace System. This phase is used to
recover the chemicals from the black liquor. The
concentrated black liquor is sprayed into the lower
part of the furnace, and essentially all of the recovered
chemicals are removed from the bottom of the furnace
as molten smelt, consisting principally of sodium
sulfide and sodium carbonate.
c. Liquor Oxidation Towers. In this phase, the sulfide
present in the black liquor is oxidized to thiosulfate,
which does not react with the acidic gases in the
recovery furnace flue gases. This prevents their
stripping in the form of hydrogen sulfide.
10-12
-------
d. Smelt Dissolving Tanks. The smelt dissolver is a
large tank into which the molten sodium carbonate
and sodium sulfide that accumulate on the floor of
the recovery furnace are dissolved in water to form
"green liquor. " It is equipped with an agitator to
assist dissolution and a steam or liquid shatterjet
system to break up the smelt stream before it enters
the solution.
e. Lime Kiln. The lime kiln is the final phase in the
closed-loop recovery system. In this phase, the
green liquor is converted to "white liquor" for reuse.
The kiln supplies calcium oxide, which is wetted by
the water in the green liquor solution to form calcium
hydroxide.
PART emissions from the entire process occur primarily
from the recovery furnace, the smelt dissolving tank, and the lime kiln.
Major sources of CO emissions are the recovery furnace and lime kiln.
The major cause of CO emissions is operation of the recovery furnace well
above rated capacity. Under these conditions, it becomes impossible to
maintain a sufficiently high air /organic-material ratio (oxidizing conditions).
PART control is provided on recovery furnaces in a variety
of ways. In mills where either a cyclonic scrubber or cascade evaporator
serves as the direct contact evaporator, further control is necessary be-
cause these devices are generally only 2 0 to 50 percent efficient in PART
removal. Generally, an electrostatic precipitator (ESP) is employed
after the direct contact evaporator to provide an overall PART control
efficiency of 85 to better than 99 percent. In a few mills, however, a
venturi scrubber is utilized as the direct contact evaporator, simultaneously
providing 80 to 90 percent PART control. In either case, auxiliary scrubbers
may be included after the precipitator or the venturi scrubber to provide
additional control of PART.
PART control on lime kilns is generally accomplished by
scrubbers. Smelt-dissolving tanks are commonly controlled by mesh pads
but employ scrubbers when further control is needed.
Several new mills have incorporated recovery systems that
eliminate the conventional direct contact evaporators. In one system, pre-
heated combustion air, rather than flue gases, provides direct contact evap-
oration. In the other, the multiple-effect evaporator system is extended to
10-13
-------
include and replace the direct contact evaporator. In both of these systems,
emissions of sulfur compounds from the recovery furnace and direct con-
tact evaporator reportedly can be reduced by more than 95 percent from
conventional uncontrolled systems (Ref. 10-4).
10.3.2 Sulfite Pulping
Sulfite pulp is generally made from soft wood. The prin-
cipal products of pulp are high-grade book and bond papers and tissues.
The pulp can also be combined with other pulp to produce cellophane, rayon,
acetate, films, and related products. Sulfite pulp was once the major pulp
used in all grades of paper other than paperboard, coarse paper, and news-
print. It has steadily been losing ground to bleached and semibleached
Kraft pulp in these traditional end uses. Production has been steadily
declining since 1966 (Ref. 10-2).
The emissions from the sulfite processing are again a
result of the liquor recovery process. Sulfur compounds are the most
important air pollution emission from this process, but sulfur emissions
are not within the scope of this study. The only significant PART source
in the sulfite pulping process is the absorption system handling the recovery
furnace exhaust.
10.3.3 Other Processes
The other activities of the wood industry which contribute
to the emissions inventory deal mainly with the sanding operations of the
plywood, pulp board, and furniture industries.
10.4 DATA ANALYSIS
The production rates of the various categories within the
wood industry were gathered from Survey of Current Business (Ref. 10-5)
and the Marketing Guide to the Paper and Pulp Industry (Ref. 10-3). Pro-
duction rates from these sources were consistent and consistent, also,
with rates used in other studies, such as the Particulate Pollutant System
Study (Ref. 10-6). In the paper processing categories, annual charge rates
(air-dried, unbleached pulp production rates) derived from the NEDS data
must be properly interpreted. The method of reporting the data may tend
10-14
-------
to generate production rates much higher than the actual rates. This is
because the emissions and emission factors from and for the serial pro-
cesses in the chemical recovery cycle are reported separately, as indiv-
idual processes with different source classification codes (SCCs), despite
the fact that all are related or keyed to the same pulp production rate.
Further, it is the chemical treatment liquor, rather than the pulp, which
is the primary fluid being treated by these processes. In plants where a
single pulp production rate is supported by multiple chemical treatment
liquor recovery systems or by multiple units of a given process operating
in parallel (for example, multiple recovery furnaces), the assumed
relations between pulp production rates, emission factors, and emissions
may be grossly in error. In the emissions data shown in Tables 10-2 and
10-3, the pulp charge rates are shown and are identical for each of the
recovery process categories (MSCCs), but they are not summed in any
subsequent summary level. While the sums of the emissions in these
summary levels are correct, the sums of the pulp production rates would
be high by as much as 500 percent.
Emission factors for this category were, for the most part,
taken from Particulate Pollutant System Study (Ref. 10-6) and Compilation
of Air Pollutants Emission Factors, AP-42 (Ref. 10-4). Emission factors
not available through these publications were generated from measured
emissions and production rates recorded in the NEDS data base.
10.5 REFERENCES
10-1. 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. En-
vironmental Protection Agency, Washington, D.C.
(July 1974).
10-2. Atmospheric Emissions from the Pulp and Paper Manu-
facturing Industry, EPA-450 /I -73-002, U. S. Environ -
mental Protection Agency, Office of Air Quality Planning
and Standards, Research Triangle Park, North Carolina
(September 1973).
10-3. Marketing Guide to the Paper and Pulp Industry (October
1973).
10-15
-------
10-4. Compilation oi Air Pollutant Emission Factors, AP-42
2nd ed. (and supplements), U. S. Environmental Protection
Agency, Research Triangle Park, North Carolina (April
1973).
10-5. Survey of Current Business, U. S. Department of
Commerce, Washington, D. C. (February 1976).
10-6. Particulate Pollutant System Study, Volume III,
Handbook of Emissions Properties, PB-203 522, Mid-
west Research Institute, U. S. Environmental Protection
Agency, Durham, North Carolina (May 1971).
10-16
-------
APPENDIX A
CONVERSION FACTORS
To Convert From
To
Multiply By
Barrel (42 gallons)
Cubic meters
1. 590 x 10"1
British thermal unit
Joules
1.055 x 103
Fahrenheit (temperature)
Kelvin
Tk =|(Tf + 459.67)
F oot
Meters
- la
3.048 X 10
Gallon (U. S. liquid)
Cubic meters
3. 785 X 10"3
tt (rrr, ft-lbs\
Horsepower (550 —1
W atts
7. 457 X 102
Inch
Meters
2.54 X 10~2
Lbj (pound force)
Newtons
4. 448
Lb^ (pound mass)
Kilograms
4. 536 x 10"1
Ton (short, 2000 pounds)
Kilograms
9.072 x 10"2
Lbm per gallon
Kilogram per cubic meters
1. 198 x 102
Cubic feet
Cubic meters
2.832 x 10"2
Lb per cubic foot
m
Kilograms per cubic meter
1.602 X 101
Btu per ton
Joules per kilogram
1. 163
Btu per gallon
Joules per cubic meter
2.787 X 105
Btu per cubic foot
Joules per cubic meter
3.726 X 104
aExact,
A-i
-------
ACR
API
bhp
BTX
CO
EEI
EPA
H2
HC
IC
KPPH
MMBtu/hr
MSCC
N
NEC
NEDS
nm
nh3
NO
x
APPENDIX B
GLOSSARY
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 -1
-------
PART particulate matter
PPM parts per million
SCC source classification code (NEDS)
SIC standard industrial classification
SO^ sulfur dioxide
TACRP total annual charge rate projected
Tp temperature, degree Fahrenheit
T, temperature, Kelvin
B-2
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
1. REPORT MO.
EPA-600/7-78-100
4. TITLE AND SUBTITLE
Inventory o
E Combustion-Related
Emissions from Stationary Sources (Second Update)
5. report date
June 1978
6. PERFORMING ORGANIZATION CODE
3. RECIPIENT'S ACCESSION' NO.
7. AUTHOR(S)
Vernon E. Kemp and Owen W. Dykema
8. PERFORMING ORGANIZATION REPORT NO.
ATR-78(7613)-1
9. PERFORMING ORGANIZATION NAME AND ADDRESS
The Aerospace Corporation
Environment and Energy Conservation Division
El Segundo, California 90245
10. PROGRAM ELEMENT NO.
EHE624A
11. CONTRACT/GRANT NO.
Grant R803283
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
Phase: 7/74-4/78
14. SPONSORING AGENCY CODE
EPA/600/13
'5,su«, ™N°™sJ9oRL:;RTP project officer is Robert E. Hall. Mail Drop 65, 919/
541-2477. EPA-600/2-77-066a was previous report in this seri&s.
16. abstract rep0rt describes the full period of a study covering the combustion-
related emissions phase of a 3-year program on the analysis of NOx control in sta-
tionary sources. The study was aimed at helping to establish priorities for detailed
studies of techniques for controlling combustion-related emissions from stationary
sources. The inventory includes emissions of NOx, HC, CO, and particulates from
stationary sources, not only primarily involving combustion but also where combus-
tion plays a secondary role. During each of the 3 years of the study, emissions were
inventoried for selected industries or processes: (1st year) boilers, stationary IC
engines, chemical manufacturing, and petroleum refining; (2nd year) primary metals
and HC evaporation; (3rd year) secondary metals and mineral and wood products.
The report identifies 91-98% of the stationary sources of the four air pollutants.
Charge rates, emissions, and uncertainties in all data are projected into the future
and, in this report, are shown for the years 1977 and 1982.
17.
KEY WORDS AND DOCUMENT ANALYSIS
a. DESCRIPTORS
b. 1DENTI F1ERS/OPEN ENDED TERMS
c. cosati Field/Group
Air Pollution Dust
Combustion Boilers
Emission Internal Combustion
Inventories Engines
Nitrogen Oxides Chemical Industry
Hydrocarbons Metal Industry
Carbon Monoxide Wood Products
Air Pollution Control
Stationary Sources
Particulates
Emissions Inventory
Mineral Products
Primary Metals
Secondary Metals
13B 11G
2 IB 13A
14B
21G
07B 07A
07C 11F
UL
13. DISTRIBUTION STATEMENT
Unlimited
19. SECURITY CLASS (This Report)
Unclassified
21. NO. OF PAGES
383
20. SECURITY CLASS (This page)
Unclassified
22. PRICE
EPA Form 2220-1 (9-73) B_3
------- |